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176-069
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 7, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-10 PRUDHOE BAY UNIT NGI-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/07/2024 NGI-10 50-029-20229-00-00 176-069-0 G SPT 7276 1760690 1819 3420 3420 3422 3425 0 0 0 0 4YRTST P Austin McLeod 2/4/2024 MITIA. Test ran to 75 min. Fought temp swings. Pad right next to compressor plant. 75 min checks as follows; Tubing 3425; IA 2154; OA 0. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT NGI-10 Inspection Date: Tubing OA Packer Depth 493 2126 2136 2157IA 3425 0 45 Min 2165 3424 0 60 Min 2165 Rel Insp Num: Insp Num:mitSAM240205184246 BBL Pumped:1.5 BBL Returned:1.8 Thursday, March 7, 2024 Page 1 of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:176-069 6.50-029-20229-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9990 9831 8437 8323 none none 7279 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 31 - 111 31 - 111 1530 520 Surface 2783 13-3/8" 29 - 2812 29 - 2812 5380 2670 Intermediate 6475 9-5/8" 27 -8815 27 - 7660 6870 4760 Perforation Depth: Measured depth: 9265 - 9824 feet True vertical depth:8017 -8432 feet Tubing (size, grade, measured and true vertical depth) 7-5/8" x 7" 29# /26# L-80 25 - 8498 25 - 7413 8323 7279Packers and SSSV (type, measured and true vertical depth) 7" HES TNT Liner 1463 7" 8524 - 9987 7434 - 8554 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8556 Sundry Number or N/A if C.O. Exempt: 321-162 7 Camco WRDP-2 SSV 2185 2185 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Water Wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028302 PBU NGI-10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Meredith Guhl at 11:11 am, May 13, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.13 10:39:48 -08'00' Bo York DSR-5/13/21 x RBDMS HEW 5/13/2021 SFD 5/13/2021MGR26JUL2021 ACTIVITYDATE SUMMARY 4/18/2021 Gas Injector Perf Pickle (TUBING WASH/PICKLE) Pumped 10 bbls 60/40 meth, 50 bbls 140* DSL and 416 bbls FW w/ F-103 down Tbg. Let soak for 2 hours. Pumped 180 bbls FW w/ F-103 and 15 bbls 60/40 meth down Tbg after soak. DSO notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG Daily Report of Well Operations PBU NGI-10 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:176-069 6.API Number:50-029-20229-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: Property Designation (Lease Number): 10. 8. PBU NGI-10 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTOR WAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9990 Effective Depth MD: 29# L-80 / 26# L-80 11. 4-15-2021 Commission Representative: 15. Suspended Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 7 Camco WRDP-2 SSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8556 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8323, 7279 2185, 2185 Date: Liner 1463 7"8524 - 9987 7434 - 8554 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 29 - 2812 29 - 2812 14. Estimated Date for Commencing Operations: BOP Sketch 31 - 111 Structural Proposal Summary 13. Well Class after proposed work: 7" HES TNT 9265 - 9824 8017 - 8432 7-5/8" x 7"25 - 8498 Intermediate 9831 8437 none none 31 - 111 520 13-3/8" Contact Phone:907.564.4672 Date: 4-5-2021 80 153020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2783 5380 6475 9-5/8" 27 - 8815 27 - 7660 6870 4760 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 55Water Wash ADL 028302 By Samantha Carlisle at 1:14 pm, Apr 05, 2021 321-162 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.05 12:50:35 -08'00' Bo York 3,393 10-404 MGR05APR21 SFD 4/5/2021 DSR-4/5/21 Yesn Required? Comm 4/6/21 dts 4/6/2021 JLC 4/6/2021 RBDMS HEW 4/6/2021 Well Work Prognosis Well Name:NGI-10 API Number:50-029-20229-00 Current Status:Gas Injector Leg: Estimated Start Date:April 15th, 2021 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:1760690 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Ryan Thompson Office: 907-564-5280 Cell: 907-301-1240 Gas Injection Rate: 213,662 Mscf/Day Injection Pressure: 3,393 psi Reservoir Pressure (Estimate): 3500 psi Program Objective(s): NGI-10 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2017. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggkn DATE: Thursday, February 13, 2020 P.I. Supervisor t (/G- L'(ZI SUBJECT: Mechanical Integrity Tests ( i BP Exploration (Alaska) Inc. NGI-10 FROM: Guy Cook PRUDHOE BAY UNIT NGI-10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 2EP._ NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-10 API Well Number 50-029-20229-00-00 Inspector Name: Guy Cook Insp Num: mi[GDC200213143104 Permit Number: 176-069-0 Inspection Date: 2/13/2020 - Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-10 'type 111] 'TVD i376 Tubing 33N0 3381 3380 3380 - 3371 PTD 1760'7690 Type Test saT Test psi isi9 IAn 1 2201 - 2135. 2106 BBL Pumped: F 2.2 ' BBL Returned: 2.2 OA 0 o 0 0 — ——, Interval avRrsr __]P/F__ P Notes: The MIT was performed with a Little Red Services pump truck and calibrated gauges. Thursday, February 13, 2020 Page 1 of I • STATE OF ALASKA • • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate I! Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Water Wash I 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 176-069 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20229-00-00 7. Property Designation(Lease Number): ADL 0028302 8. Well Name and Number PBU NGI-10 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9990 feet Plugs measured feet RECEIVED true vertical 8556 feet Junk measured feet Effective Depth: measured 9831 feet Packer measured 8323 feet SEP 1 3 2017 true vertical 8437 feet Packer true vertical 7278.86 feet ACC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 31-111 31-111 1530 520 Surface 2783 13-3/8"72#MN-80 29-2812 29-2812 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 6475 9-5/8"47#MN-80 2340-8815 2340-7660 6870 4760 Liner 1463 7"29#L-80 8524-9987 7434-8554 8160 7020 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet SCANNED DEC 1 42W, Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 7 Camco WRDP-2 SSSV 2185 2185 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9265'-9824'. Treatment descriptions including volumes used and final pressure: 20 Bbls 50/50 Methanol/Water,213 Bbls diesel/Xylene,586 Bbls 1%KCL w/F-103 Surfactant,1460 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -193549 320 3332 Subsequent to operation: -156623 150 3165 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations C>j Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ® SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-316 Authorized Name: Oestgaard,Finn Contact Name: Stone,Christopher Authorized Title: Production Engineer Challenger Contact Email: Christopher.Stone@bp.com Authorized Signature: _ 1 ;.44.VDate: 9•IV- 17 Contact Phone: +1 907 564 5518 Form 10-404 Revised 04/2017 , 4, V 77-- l 6 1171 1 7 RB DMS �L SE.P 2 5 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED RE: BP Exploration (Alaska), Inc. SEP 1 3 2017 Report of Sundry Well Operations Summary AOGCC September 7, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Water Wash Stimulation of Well NGI-10, PTD # 176-069 covered under Sundry Approval # 317-316. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • d • o• 0 0 0 0 0 0 0 0 _O O O O N- 0 CO CO O N 6) 6) - 00 CO N- O N- N- O V' N d• N- r (V C N U') V' V' N U7 C0 r CO U N 0 0 0 0 0 0 0 0 0 0 0 0 0 L CO CO r` IC) r` r` (0 V' 6) V O) 'V NI- 3 CC) co Co - co co - N CO N CO N r-- N- `N- U) CO 00 (0 CO CO N- CO N- (.O 1- h N CO N •- O V' CO N- O CO V CO CO U7 N- CO CO - r CO - CO CO M CO CO U7 N N V' CO N N N N- N C0N- I- CO N O V M r-- - 0) -O N c- V' V M CP) N- CO CO c- N M N N M M M d• N N = ‘- N M N N N N- N N r- r- (1) N CO N CO U7N- CO N- CO N- U7 r r c- co r- co co co O Cb co co 00 co 6) N N U7 CO N N N CO CO 6) N N CO CO CO C.) 0 Q - 6) N- V N Cf) r- coCp co00 coM co a/ U MNNMMM10 (N - '- NM = Z N N N CO N N CO CO n co CD LO Cb CD CO 00 Co CO O CC?ZO Z Z O O J O J O J Q CO 00 CO CO J __ d = % *k C/) J J J J *k •(n N *k *k *k rn *k rn *k (/) _ V' V' 6) CO (Ni CO N CO CO 6) ao _ _ N N _ N _ C C,.) 6) LoU7 r U7 17 M LN-O 0 co J N N (.O 0 c- N CO N W W W < < _< Z O SOH DDDR N U www U U D W CC CCD Z Z Z Z Z Z Z CCW W W O W 00 CO CO CO CO CO ODHHHDD U (/) 0_ :_71 F- I— . • • a) N m• M OD N I"- N- O a) co N „ CO - M N a) iCO M co U0 a) N 00 a) o CO M N O CA CO O p_ O Nv- CO CO U0 00 CO V cD co M O N- N a> CO CD o V LU LU O M N CD O O V co O 0 0 65 0 r- y- r V- V- 00 N N co co co 00 CD OO CO 00 CO 00 OO OD CO CO OD 00 OD 00 OO I- O. 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LL e — / ƒ / co 2 2 \ / & / « E L.0 / / § / k O C). f -' X § < \ % $ ± H O , -00.- 2 � k m 2 ± CU 2= 0 7 = 2 — % o4a7man ° \ / \ & o ± 2 I o U o / 2 0 \ $ II \ , C \ r / 6w � / \ a & r m n / \ ga5g � 52 \ >< -1 �� a= = = = 2cI U E \ co co \ - / > 2 $ / A o $ / ƒ \ / c'' L \ N. / COo \ 0 3 ® / \ \ < Tat 6-3/8"CNV 0 VVELLFEAD= (RAY SAFETY NOTES: WELL REQUIRES AN SSSV.." ACTUATOR= BAKER C N G '-1 O CHROME NIPPLES*" ORIG.KB.ELEV= 47' ORIG. BF.ELEV= I Max Angle= 45"@ 9661' 20"CONDUCTOR — 106' ; ` ® tf 2182' —i 7"SLB DS 6 NP(9-CR),D=6.00" Datum MHD= 10379' 94#, 40. 1i• : 2268' H9-5/8"FES ES C E VB IIH3 Datum TVD= 8800'SS D=19.124" '� 2289' —I 9-518"BIUR ECP PKR D=8.670"—I 9-5/8"CSG,47#,L-80 HYD 563,ID=8.681" —I_ 2314' 14 Aj 9-5/8"BOWEN CSG PATCH — 2314' x � 236T1H 9-5/8"FO CE BJTER 9-5/8"CSG,47#,S0095 XO TO MIN-80 BUTT — 2340' j 2487' H9-5/8" T32 FO CEMENTER 133I8"CSG,72#,MN-80 BUTT,D=12.347" H 2811' I---, —. Minimum ID =5.600" @ 8355' 7" HES RN NIPPLE 7-5/8"TBG,29.7#,L-80 VAM TOP HC(PC), — 8230' 8230' H 7-5/8"X 7"XO,D=6.276" .0459 bpf,ID=6.875" 8247' H 7"HES RNP(9-CR),ID=5.963" Z 8320' H 9-5/8"X 7"FES TNT F R,I)=5.900" 8356" H7"HES RN NIP(9-CR),D=5.500" 7"TBG,26#,L-80-KA,.0383 bpf,D=6276" H 8498' IL8498' —j 7"WT EG,D=6.276" TOP OF 7"LNR H 8523' HELM)TT NOT LOGGED 9-5/8"CSG,47#,N-80,D=8.681" —I 8815' 11 PERFORATION SUMMARY REF LOG:BRCS ON 11/14/1976 IL ANGLE AT TOP FERE:38"@ 9265' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ ' 2-7/8" 4 9265-9293 0 06/11/77 I 3-3/8" 4 9300-9448 0 07/04/90 3-3/8" 6 9452-9482 0 09/10/14 ' 3-3/8" 4 9452 9492 0 07/04/90 3-3/8" 6 9482 9492 0 09/10/14 ' 3-3/8" 6 9515-9540 0 09/09/14 III 4 9515-9540 0 06/11/77 3-3/8" 6 9564-9589 0 09/09/14 ' 3-3/8" 4 9564-9589 0 06/11/77 3-3/8' 6 9610-9640 0 09/09/14 ' 3-3/8" 4 9610-9644 0 06/11/77 I 3-3/8" 4 9676-9696 0 06/11/77 3-3/8" 4 9713-9748 0 06/11/77 3-3/8" 4 9799 9$24 0 06/11/77 \ 9831' —TOP OF SALT RUG(01/16/12) NI uAAuA♦ TD 9990' 7"LNR,29#,N-80 BUTT,.0371 bpf,ID=6.184" — 9986' DATE REV BY COMMENTS DATE REV BY COMMENT'S PRUDHOE BAY UNIT 11/23/76:halg IR5'ORIGINAL COMPLETION 01/05/12 SMVJMD DRLG DRAFT CORRECTIONS WELL: NGI-10 03/22/83 NI ES RWO 01/06/12 PJC 13-3/8"CSG CORRECTION PERMT No: 12/27/11 D16 RVVO 01/10/12 GJB/PJC PULL FRN PLUG(01/08/12) API No: 50-029-20229-00 07/19/01 RNVTP CORRECTIONS 01/19/12 RRW/JMC REM'D SALT RUG(01/16/12) SEC 1,Tl 1N,R14E, 137'FSL&916'FWL 11/12/11 DMS/PJC SALT FILL(11/03/11) 09/10/14 DHS/PJC RE/ADFERFS(09/09-09/10/14) — 01/05/12 SMVJMD PRN RUG(12/26/11) BP Exploration(Alaska) OF Tit • • 4,1014 I//7;.. A THE STATE Alaska Oil and Gas F�,:_ , of T LcAS Conservation Commission A 2 _ 333 West Seventh Avenue '1 r!— " /. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF 44.1.., Fax: 907.276.7542 www.aogcc.alaska.gov Christopher Stone DS 2 and 18 PE BP Exploration (Alaska), Inc. SCANNED JUL 2 0 2017 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU NGI-10 Permit to Drill Number: 176-069 Sundry Number: 317-316 Dear Mr. Stone: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of July, 2017. RBDMS 1),,JUL 1 3 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPRO 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 • Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ Other Water Wash 0 • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 176-069 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic ❑ Service 0. 6. API Number: 50-029-20229-00-00 • 7. If perforating: 8. Well Name and Num EC E I V E What Regulation or Conservation Order governs well spacing in this pool? C Will planned perforations require a spacing exception? Yes 0 No 0 PBU NGI-10 . JUL1 9. Property Designation(Lease Number): 10. Field/Pools: L 1 0 20171/ ADL 0028302 PRUDHOE BAY,PRUDHOE OIL 0:6 124/7 11. PRESENT WELL CONDITION SUMMARY ///11CC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 9990 . 8556 . 9831 8437 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"94#H-40 31-111 31 -111 1530 520 Surface 2783 13-3/8"72#MN-80 29-2812 29-2812 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 6475 9-5/8"47#MN-80 2340-8815 2340-7660 6870 4760 Liner 1463 7"29#L-80 8524-9987 7434-8554 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment 7 Camco WRDP-2 SSSV 2185, 2185 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0• 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 • Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Stone,Christopher be deviated from without prior written approval. Contact Email: Christopher.Stone@bp.com Authorized Name: Stone,Christopher Contact Phone: +1 907 564 5518 Authorized Title: DS 2 PE Authorized Signature: 04.0IL_ Date: --7/lily /'�^ � COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31-7— t (-- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes 0 No Ire Subsequent Form Required: t o __4,c,4 APPROVED BYTHE `� 1 Approved by: COMMISSIONER COMMISSION Date: 't 111- 1'1 4,1,0 ORIGINAL RBDMS JUL 1 3 2017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from t e d e of approval. Attachments in Duplicate tA`SZ 7�t Z7f *& /SS -7,1 c /7 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue RECEIVED Anchorage, AK 99501-3572 JUL 10 2017 AOGCC RE: BP Exploration (Alaska), Inc. Report of Sundry Approvals (10-403) July 7, 2017 To Whom it May Concern: Attached please find the Sundry Application for a Water Wash on Well NGI-10, PTD # 176-069. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR, LHD,EAZ, BPG 10/12/15) General Information Well Name: NGI-10 Well Type: Gas Injection Well API Number: 50-029-20229-00 Well Activity Conventional 4 Classification: Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: TREAMENTS Estimated Cost, $K: AWGRS Job Scope: TUBING WASH/PICKLE Other regulatory None requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Well Intervention Engineer: Jamin Laplante Contact numbers: 907-365-9140 907-564-4137 Lead Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Date Created: June 28. 2017 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 6/26/2017 202.046 3,390 Current Status: Operable Flowing Inclination>70°at Depth(ft) N/A — Recent H2S (date,ppm) NA 0 ppm Maximum Deviation(Angle and 45° 9,757' MD Depth) Datum depth,ft TVDss 8 800'TVDss Dogleg Severity(Angle and Depth) 7° 9.875' MD Reservoir pressure(date, 7/26/2011 3.383 psi Minimum ID and Depth 5.500" 8.355' MD psig) Reservoir Temp, F 176° F Shut-in Wellhead Pressure Est. 2525 psi Known mech. integrity None problems(specifics) Last downhole operation(date, operation) 2/18/2016 Set 7"Al SSSV at 2182.' Most recent TD tag(date, depth, 9/2/2014 9827'SLM/ 20'x 3-3/8"dummy guns&2.5"SB(Report has 2 numbers toolstring OD) 9727'SLM for TD tag noted on report) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, NGI-10 is a gas injector that was originally drilled and completed in October 1976. In December 2011. a background information, RWO was performed to mitigate IAxOA communication, replacing the 7"tubing as well as the upper 9-5/8" etc: casing with premium thread casing cemented on the backside to surface. 120'of reperfs were shot 9/10/14. resulting in a 40 mmscfpd increase in gas injection rate. The last water wash was pumped 8/22/10 and did - not see an increase in injection rates. The job pumped 48 bbls 70 F diesel/xylene. 584 bbls 100 F fresh water w/0.02%F-103 surfactant. Recently the performance of this injector has started to degrade. prompting the need to perform a water wash. This wash will use DIX at a reduced concentration of 60/40 in an attempt to see if positive results can be achieved. • • • Well Intervention Details Please contact the SOR author ifs 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total costas soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Reduced iniectivtty due to depositions Specific Intervention or Well Objectives: 1 Pump diesel/xylene water wash to restore injectivity by cleaning perfs and tubing. 2 I 3 Key risks,critical issues: Mitigation plan: 1 High pressure pumping Use pressure cross check checklist Use extreme caution and ensure all personal on 2 Gas Injection Well location are aware of pressure sources and well barriers. Follow well entry gas pad wellwork section 3.8 Reducing the ratio from 50/50 pumped on previous II water wash jobs to 60/40 D/X for 2017 water wash 3 !Increased diesel/xylene ratio optimization and economic study. Results will be evaluated and water wash strategy updated.Accept risk of potentially less effective water wash Review MSDS pre-job, discuss safety precautions/gear. 4 Working with Xylene how to handle spills, how to handle contact to personal to ensure personal know how to respond Summary Service Line Activity Step# 1 FB Pump diesel/xylene water wash as per attached pumping template. 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 FB Pump diesel/xylene water wash as per attached pumping template. 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Post water wash return well to gas injection service. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Cu • o• 0 0 co 0 0 0 0 co 0 0 o co R N r- Co co CO CO N r 6) r 6) r CO O ti O V t7 V N N VLO ti to d LO U 17, 0000000000000 CO CO N- LU r- CO t rn cr rn v v • 10 Cr) CO r co CO r N CO N CO N I- m LC) CO CO CO CO CO I- CO N- CO N- N CIO N r 0 'cr (-or— Q (0 V r r r d- CO CO Lo r-- 00 CO r r CO r CO CO CO CO CO N N CO N N N N- N- co N N I- N- N- • e / 1 1 1 1 1 H CO N O <Zt Cr) r-- r-- c' CO LO I,- CO CO r N CO N N C'7 CO CO d' N N r r- N C') N N N N- N N N- I-- 02) N CO N CO CO ti co r— (7 r CO rr r r CO I- CO CO CO O 6) r CO co C`') CIO CO 67 N r r N Ln Cr) r N N N Co co CA N N CO CO CO V RS 0 E Q , I N(A r-- (0 CD CD N CC7 I� CO CO CO Cp 0)VnC`7 N N C7 C7 CO «) N N r r CV C) Z N N N CO N N CO CO C9 O CO CO CO CO 0 ZCOOZZOOJOJOO 2 J 0 00 co co co J It.� •N � � � � NNCAN N � N O C N CO - N U O `0 ti Ch OLON- N r O 6) CT M r Cn CC) C!) I- CO co ca co C co co N N 't V r co 0 C) N N CO (N CO r N O N W W W ct < < < 0 0 co 0 N 0 UQIII O UJ U Rp22D 0000 0 CD 00WCLCrCY_ ocCZZZZZZ Z W W W O W CC] CO CCl m I CO ODHHHCCZDDDDDD UU) Z Z Z - CL HHHH • ca c'1 co N N- t` CO CA V CO N d. 00 CD N- C) N 00 CO CO LO C) (\Itb O) O 00 Cr) N C) C) CO o CA N T CO 00 Cn 00 OO 4 c, co V' T co co 0_ N co co O Cr) O 4 co CL) CO co N CO O O 4 M co D O C C) T T T T T T co N N C) CO CO co OD CO CO CO OO 00 CD 00 00 00 OO Cb OD 00 00 F 0- 0 CC) 00 CbN- ti CO C D C D 00 N TCO I's C� 00 D NOD CO N CL) CD N CO CD O OD N- O CO C) CO CT CT r 4 N T CO Cb LO • OO d' O CO O T CON M CU �- 4 CC) O CD O ct CC) CO CO 00 O cr Ns O N CC) T W 0 0 0 0 O T T T T T T CV N N M 01 00 4 co p0 CO OD OD CO 00 00 CO 00 00 00 CO 00 OD CO 00 OD 0 F- W CC 0 W O O OLIJ W 0 N gg 0 0 ° > 0 0 w Y Y F « CO C) CC) O O d' 4 co O N N O CZ C) V' CO Cb ti J J J Q C C/J W ++ CL CD T OD CO 00 M cr NY CO 00 CD '4' 00 V V CA 4 NQ Q Q W m N co co CO CO V d r 4 d' 4a Cn CO CO CO N- 00 CD _0 0_ Z 0_ J W W o O CA CT O CD O C7 0CD CD CD CD CD CA CD CD CA O) CD CD Z Z 0 o o d Q Q Q 0 0 0 W Z ~° Z cn C 2 2 . 0 co cc, ¢ m (n t) mrt Q /� 8- V O F- C Z L CC) O O CC) O O d' ct N O N CC) V O O CO CO CD OO- CO O CO4 CC c- CO CO 00 ) CO co T CO T N- T V cn d N co CO CO co co 4 4- V v 4 Cn Cn CO CO CD N- N- ,:: 0 CD CA CD CT CD CD CT CA C5) cn CD co CA CA CD CO CA CD Via ; U 0 (/) cc i 2 O c i cc/ a) a) va) a) CL 0 0 0 C cr u_ u_ u_ Q' LL LL LL LL W W u_ CL' ry waWWCLwCLaCLo- aaaWWww taQ0_ QO. QCL000QQQQa. CL0_ a CL 0 CL d ~ CTI r o ti o ti o ti o '4' v v d v v N- N- N o O O C 6) CD O (A C� O °) 0 0 o T CD CD CD W J Z \ r- \ r \ V- \ V- N N N o O O o \ \ ` Z U d W V 11.1 N W T O O O _� T T T 0 d LU C7 J L 0 W (L -LI LU LL LL1 a) CO QD QD C D C D C D (� O CD CD CO CO CO Q 0 0 J D J 0 QQ 0_ 0 m 0 CY 0 W J -1 O Q 0 W W m a cnn W u) O CY E o 0 o O O o 0 C) o O O o O o 0 0 0 0 T T T T T T T T T T T T T T T T T T 1 I II II I I 63UC`) UCDCDCDCD0007CDCDCDCDCDCDCDCD mit a s °U WO C11 w a ZZ Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z < < m m W I m co 0_ cc 0 • Packers and SSSV's Attachment PBU NGI-10 SW Name Type MD TVD Depscription NGI-10 SSSV 2185 2184.92 7 Camco WRDP-2 SSSV NGI-10 PACKER 2293.05 2292.97 9-5/8" BOT External CSG PKR NGI-10 TBG PACKER 8322.96 7278.86 7" HES TNT Packer TREE= 6-3/8"CM/ - %ELLIfAD= GRAY411 N G I 0SA NIOPTES: WELL REQUIRES AN SSSV"" ACTUATOR= BAKER C °RIG.KB.ED/= 47' OR1G BF ELEV= KOP= 3405' Max Angle= 45'@ 9661' 20'Co4Dt1GT(1R — 106' , ' 2182' —17'SLB D8-6 NP(9-CR),D=6.00" Datum MD= 10379' 94#,1i-40. ;� �: 2268' H9-5/8"FES ES CEMENTER TT2 Datum TVD= 8800'SS D=19.124" cA ►,1 2289' --i 9-518"BM ECP PKR D=8.670" 19-5/8"CSG,47#,L-80 HYD 563,ID=8.681" — 2314' • I. 9-5/8"BOVVHV CSG PATCH H 2314' 2361' --{9-518"FO CBvHdTHR 9-5/8"CSG,47#,50095 XO TO MN-80 BLJTT — 2340' A 111 _ 2487' H9-5/8"FO CEMENTER 13-3/8"CSG,72#,1144-80 BUTT, D= 12-347" H 2811' t - Minimum ID =6.600" @ 8365' 7" HES RN NIPPLE 7-5/8"TBG,29.7#,L-80 VAM TOP HC(PC), l— 8230' I 8230' H 7-5/8"X 7'XO,13=6.276" .0459 bpf,ID=6-875' 8247' H 7-HES R NP(9-CR),D=5-963" ►ZM 171 8320' _—9-5/8"X 7'HES TNT Fi(R D 00" 5.9 ' 8356' —7"HES RN NP(9-CR),D=5.500" 7"TBG,26#,L-80 TC/ 0383 bpf = 76' I 7'VVLEG D=6.276" I p ,D 6.2 � 849W / 8498' H , TOP OF 7'LIR —I 8523' HELM)ELM)TT NOT LOGGED 9-5/8"CSG,47#,N-80,D=8.681" H 8815' II PERFORATION SUMMARY i i REF LOG-8I-CS ON 11/14/1976 ANGLE AT TOP F$2F:38"@ 9265' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 4 9265-9293 0 06/11/77 3-3/8" 4 9300 9448 0 07/04/90 3-3/8" 6 9452-9482 0 09/10/14 3-3/8" 4 9452-9492 0 07/04/90. 3-3/8' 6 9482-9492 0 09/10/14 I 3-3/8' 6 9515-9540 0 09/09/14; ' 3-3/8" 4 9515-9540 0 06/11/771 • 3-3/8" 6 9564-9589 0 09/09/141 3-318" 4 9564-9589 0 06/11/77 3-318" 6 X9610-9640 0 09/09/141 1 3-3/8" 4 19610-9644 0 06/11/771 3-3/8" 4 9676-9696 0 06/11/771 3-3/8" 4 9713-9748 0 06/11/771 • 3-3/T 4 9799 9824 0 06/11/77 r9831' TOP OF SALT PLUG(01/16/12) I I ,«F�;•tT;•,��1 I M 7'L ,29#,N-80 BUTT, .0371 bpf,ID=6.184" — 9986' TD 9990' I DATE REV BY COMMENTS r DATE REV BY COJ ENTS FRU7HOE BAY UNIT 11/23/763ha1g R5'ORIGINAL COMPLETION 01/05/12] SM/JMD DRLG DRAFTCORRECTIONS WELL 1491-10103/22/83 N1ES RWO 01/06/12 PJC 13-3/8"CSG CORRECTION FERMI No '1760690 112/27/111 I D16 RWO 01/10/12 GJBI PJC RILL PRN RUG(01/08/12) API No. 50-029-20229-00 107/19/01 RI YTP CORRECTIONS 01/19/12 fRRVV/JMC REM/D SALT PLUG(01/16/12) SEC 1,T11I,R14E 137'FSL&916'FW._ 11/12/11 IDMS/PJC SALT PILL(11/03/11) 09/10/14 DHS/PJC RE/ADPERFS(09/09-09/10/14) X01/05/12, SMWJMD PRN PLUG(12/26/11) 1 j BP Exploration(Alaska) • • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, May 19, 2016 7:31 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; 'jim.regg@alaska.gov'; Morrison, Spencer; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington, Aras J Subject: OPERABLE:Injector NGI-10 (PTD #1760690) Attachments: Injector NGI-10 (PTD #1760690) TIO Plot 2016-05-19.docx All, Injector NGI-10 (PTD#1760690) was originally placed Under Evaluation on 04/10/2016, due to anomalous IA pressure that started after a passing MIT-IA to 2200 psi on 02/27/16. Ambient temperature changes, and swings in injection rate and temperature, during the initial 28 day evaluation period rendered that time frame insufficient to determine whether or not TxIA communication was indicated. On 05/08/16, the evaluation period was extended for an additional 14 days. The IA was bled to 0 psi and a nitrogen cap installed on 05/10/16, and the well was subsequently monitored for 9 days. It is evident that the previously-observed anomalous IA pressures resulted from thermal effects and injection rate swings.The well is reclassified as Operable. Work Completed: 1. Downhole Diagnostics: Bleed IA pressure while injector is online—DONE 05/10/16 2. Downhole Diagnostics: Install N2 cap—DONE 05/10/16 3. Wellhead: Perform tubing packoff test—PASSED 05/16/16 4. Downhole Diagnostics: Monitor TIO for remainder of Under Evaluation clock—DONE 05/19/16 A copy of the injection and TIO plot have been included for reference. Thanks, Adrienne McVey SCANNED 2016 Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) Office: (907)659-5102 Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, May 08, 2Ot6-6:49..AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility O FL AK OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, D&C Well Services Operations perintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; 1 • • Injector NGI-10 (PTD#1760690) TIO Plot 2016/05/19 Wei..110 tro 3410 +4b -0-IA - Oat �Oft 1400 Y OL15'fs 4111515 00416 1:01116 OMSK 4125,11 PM. Ot06M .15,4 MN06 OG]S'1B b915,16 651116 Injection Plot MO M.10 MO OK IMO KO 1.0410 60D {{{{ 300GOO no 000 W0 240 1 ,r 240000 � ,�`� Y 2.24 000 ->OV t 180D yZap VC 1KO r000 —41 1. I lraa` -a 1100 141.00E Ica ( lmwc 1.Mk 410 rood Mn rah w ax0 xwo 0216113 107115 0420➢5 maws 412615 01.13 :.- 42015 102115 1114 15 101511 01.2511 OL26110 102115 551516 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, May 08, 2016 6:19 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers,Jessica; Dickerman, Eric; 'jim.regg@alaska.gov'; Munk, Corey; Odom, Kristine; Holt, Ryan P; AK, D&C Well Integrity Coordinator Subject: UNDER EVALUATION:Injector NGI-10 (PTD #1760690)Inner Annulus Repressurization All, Injector NGI-10 (PTD#1760690) had begun to exhibit anomalous inner annulus (IA) pressure on April 10, 2016 following a passing MIT-IA to 2200 psi obtained on February 27, 2016. The well had been reclassified as Under Evaluation for diagnostics. The Under Evaluation period has not been satisfactory to fully investigate the anomalous IA pressure due to ambient temperature changes, intermittent injection, unstable injection rates, and injection temperature swings. The IA is fluid packed with no signs of gas. The well will remain on injection as Under Evaluation for up to an additional 14 days for further diagnostics. Plan Forward: 1. Downhole Diagnostics: Bleed IA pressure while injector is online. 2. Downhole Diagnostics: Install N2 cap 3. Downhole Diagnostics: Monitor TIO for remainder of Under Evaluation clock 4. Well Integrity Engineer: Additional diagnostics as needed A copy of the injection and TIO plot have been included for reference. Please call with any questions or concerns. Thank you, Jack Lau (Alternate:)Adrienne McVev BP Alaska-Well Integrity Superintendent G W: 907.564.5102 C: 907.943.0296 H: x2376 From: AK, D&C Well Integrity Coordinator Sent: Sunday, April 10, 2016 9:24 PM 1 • • • • Injector NGI-10 (PTD#1760690) TIO Plot May 8, 2016 Well NGI-10 3 ,. Tbp lA 2000 -+-CIA 40A -T-000A On 1 WC. 020816 0215'16 0222.16 022961E 6362'16 031416 6321,15 032'315 040415 041116 64161E 97615 050.2 15 Injection Plot May 8, 2016 Well NGI-10 3600 ' 260.000 3.100 240.000 3200 3.000 210.000 2800 100 000 2600 180.000 2.400 ONIIP 2200 160000 900 2000 140.000 -FW t goo ; ao 1.600 120.1390 -GI 1 100 100.000 Olbee On 1200 80.000 1 000. • 800. 60000 600' 40.000 400 20000 200 02108160 021516 0272116 0212916 0101!16 03114'16 0311/16 133/2816 049416 0411!16 00816 0415'16 0543116 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Sunday, April 10, 2016 9:24 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; 'jim.regg@alaska.gov'; Munk, Corey; Odom, Kristine; Pettus, Whitney Subject: UNDER EVALUATION:Injector NGI-10 (PTD #1760690)Inner Annulus Repressurization Attachments: Injector NGI-10 (PTD #1760690) TIO and Injection Plot.docx All, Injector NGI-10(PTD#1760690) has begun to exhibit anomalous inner annulus (IA) pressure following a passing MIT-IA to 2200 psi obtained on February 27, 2016. The well has been reclassified as Under Evaluation for further diagnostics and may remain online for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: Bleed IA to 200 psi 2. Downhole Diagnostics: Monitor TIO for 5 to 7 days 3. Well Integrity Engineer: Additional diagnostics as needed A copy of the injection and TIO plot have been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED APR 2 12016 (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator V Y V WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com 1 Mk 4. • • Injector NGI-10 (PTD#1760690) TIO Plot April 10, 2016 1011.110110 I I Ta I i i h.....11•.1 DMA o,.,. 0.'6 02,,,,,, 02414 0001. 0200,11 .,.,m 011110 OM. 011711 014016 Injection Plot 2. .....Mk _.. 2100 n------ `---------. .0% fir M, 40 Mt 120. rXOp • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ) Regg DATE: Wednesday,March 09,2016 P.I.Supervisor qe?//(' SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. NGI-10 FROM: Lou Grimaldi PRUDHOE BAY UNIT NGI-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-10 API Well Number 50-029-20229-00-00 Inspector Name: Lou Grimaldi Permit Number: 176-069-0 Inspection Date: 2/27/2016 Insp Num: mitLG160228070623 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-10 < Type Inj G "TVD 7276 Tubing 3297 - 3298 3298 - 3299 PTD 1760690 - Type Test SPT Test psi 1819 " IA 3 2191 . 2176 - 2176 - Interval 4YRTST P/F P / OA 0 0 _ 0 0 Notes: 2.0 bbl's diesel pumped and returned.Good solid test.All required paperwork supplied prior to test. SCANNED SEP 2 6 2016 Wednesday,March 09,2016 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Repair Well LJ Plug Perforations Perforate ✓ Other Performed: Alter Casing Pull Tubing[] Stimulate - Frac [] Waiver [] Time Extension[] Change Approved Program [] Operat. Shutdown[] Stimulate - Other [] Re-enter Suspended Well[] 2. Operator BP Exploration (Alaska), Inc 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development[] Stratigraphic[] Exploratory [] Service 7 176-069-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20229-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028302 PBU NGI-10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: - �J RE- Total Depth measured 9990 feet Plugs measured None feet OCT 0 6 2014 true vertical 8555.75 feet Junk measured None feet Effective Depth measured 9831 feet Packer ((�� measured 8320 feet �®G%jV true vertical 8437.11 feet true vertical 7276.59 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 28-108 35-110 1530 520 Surface 2779 13-3/8" 72# MN -80 32-2811 8352.11 - 8352.94 5380 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 1463 7' 29# N-80 8523-9986 8063.48 - 8508.86 8160 7020 Perforation depth Measured depth See Attachment feet SEAyJW NOV �. � Z�i� True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 7" Top Packer 8320 7276.59 Packer 7" Camco DB Nipple 2182 2181.92 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratoro Development p ❑ Service Stratigraphic [] Daily Report of Well Operations X 16. Well Status after work: Oil El Gas 0 WDSP GSTOR [] WINJ [] WAG ❑ GINJ [] SUSP ❑ SPLUG[:] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays@bg.com Printed Name Nita Summerhays Title Petrotechnical Data Engineer r Signatu Phone 564-4035 Date 10/3/2014 Form 10-404 Revised 10/2012 ,oaf /may/y RSCMS OCT -1 7 2011, Submit Original Only Daily Report of Well Operations ADL0028302 DRIFTED TBG TO Al- INJECTION AT 2,166' SLM (2,182'1; RING (no obstruction) PULLED A1- INJECTION VALVE (BWS-138, 3.50" 'A SLM (2,182' MD) DRIFTED TBG W/ 20'x 3-3/8" DMY GUNS & 2.5'S. , (see log for details, no sample recovered) ***CONTINUE ON 9/2/2014*** RIG DOWN SWCP 4519 9/3/2014 ***JOB COMPLETE, WELL LEFT SHUT IN, PAD OP NOTIFIED*** T/1/0=2582/27/1 Temp.= S/I Assist E line 10 bbls of 60/40 meth spear followed by 725 Pumped 22 bbls of 2%akcl down TBG. ***W; vvLLL VI Iv I nv VIV /-%RRI VML kOLD CLING: - rr-mrVtV11 w4u) INITIAL T/I/O = 2500/0/0 PSI RUN 1: RIH WITH HEAD (11X3) / ERS / GR / CCL / 30' X 3-3/8" POWERJET NOVA, 6 SPF, 60 DEG PHASE PERFORATE INTERVAL = 9610'- 9640' (CCL TO TOP SHOT 5.0' CCL STOP DEPTH = 9606) RUN 2: RIH WITH HEAD (11X3) / ERS / GR / CCL / 25'X 3-3/8" POWERJET NOVA, 6 SPF, 60 DEG PHASE PERFORATE INTERVAL= 9564'- 9589' �I(CCL TO TOP SHOT = 5', CCL STOP DEPTH = 9559') RUN 3: RIH WITH HEAD (11X3) / ERS / GR f CCL t 25'X 3-3/8" POWERJET NOVA, 6 SPF, 60 DEG PHASE `�' PERFORATE INTERVAL= 9515'- 9540' �' %(CCL TO TOP SHOT = 5', CCL STOP DEPTH= 9510') -�� CORRELATED TO SLB BOREHOLE COMPENSATED SONIC L DATED 14-NOV 197611 r ***JOB CONTINU7=bbN 10 -SEP -2014", " 1 PERFORATING) RUN 4. RIH WITH HEAD (11X3) / ERS / GR / POWERJET NOVA, 6 SPF, 60 DEG PHASE PERFORATION INTERVAL = 9482'- 9492' SHOT = 4.2', CGL TO STOP DEPTH = 9477.E RUN 5. RIH WITH HEAD (11X3) / ERS / GR 1 POWERJET NOVA, 6 SPF, 60 DEG PHASE PERFORATION INTERVAL = 9452'- 9482' . SHOT = 5', CCL STOP DEPTH = 9447 WELL SHUT IN UPON DEPARTURE. DS FINAL TWO = 50/0/0 PSI k**JOB COMPLETE**** / ,,, T,, -,i . . ---vvbK contlnuea Trom UP3114 --- Assist L-Ilne (pertorawWrw ° 1 ' bbls 2% kcl Down TBG. to assist E -line, Pumped 115 bbls 60/40methanol down TBG to FP. Hung FP tag on wing valve. RDMO. E -line in control of 9/10/2014 well upon LRS departure. FWHP's = 100/21/3 FLUIDS PUMPED BELS 725 1% KCL 125 60/40 METH 452 2% KCL 3 DIESEL 1305 TOTAL MD MDr+rvuvrvMU MIK Perforation Attachment APF ADD PERF MIS MECHANICAL ISOLATED BPP ADL0028302 MLK MECHANICAL LEAK BPS SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base NGI-10 1/16/2012 SPR 9265 9293 8017.25 8039.33 NGI-10 1/16/2012 SPR 9300 9310 8044.83 8052.68 NGI-10 1/16/2012 SPR 9310 9335 8052.68 8072.2 NGI-10 1/16/2012 SPR 9335 9360 8072.2 8091.57 NGI-10 1/16/2012 SPR 9360 9380 8091.57 8106.97 NGI-10 1/16/2012 SPR 9380 9434 8106.97 8148.26 NGI-10 1/16/2012 SPR 9434 9444 8148.26 8155.89 NGI-10 1/16/2012 SPR 9444 9448 8155.89 8158.94 NGI-10 9/10/2014 APF 9452 9460 8161.99 8168.08 NGI-10 9/10/2014 APF 9460 9482 8168.08 8184.82 NGI-10 9/10/2014 APF 9482 9492 8184.82 8192.4 NGI-10 9/9/2014 APF 9515 9540 8209.71 8228.33 NGI-10 9/9/2014 APF 9564 9589 8246.03 8264.29 NGI-10 9/9/2014 APF 9610 9640 8279.51 8301.07 NGI-10 9/9/2014 SPR 9640 9644 8301.07 8303.93 NGI-10 1/16/2012 SPR 9676 9696 8326.68 8340.87 NGI-10 1/16/2012 SPR 9713 9748 1 8352.92 8377.7 NGI-10 1/16/2012 SPR 9799 9824 1 8413.99 8432.03 MD MDr+rvuvrvMU MIK MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing / Tubing Attachment ADL0028302 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 28 - 108 35 - 110 1530 520 LINER 1463 7" 29# N-80 8523 - 9986 8063.48 - 8508.86 8160 7020 NIPPLE 1 7" R Nipple 8247 - 8248 8365.35 - 9114.64 NIPPLE 1 7" RN Nipple 8356 - 8357 2087.91 - 2088.91 PRODUCTION 2288 9-5/8" 47# L-80 26 - 2314 8199.15 - 8199.99 6870 4760 PRODUCTION 26 9-5/8" 47# SOO-95 2314 - 2340 8236.98 - 8237.82 8150 5080 PRODUCTION 6475 9-5/8" 47# MN -80 2340 - 8815 8323.89 - 8324.72 6870 4760 SURFACE 2779 13-3/8" 72# MN -80 32 - 2811 8352.11 - 8352.94 5380 2670 TUBING 8207 7-5/8" 29.7# L-80 23 - 8230 8370.3 - 8371.13 6890 4790 TUBING 268 7" 26# L-80 8230 - 8498 33 - 8485.37 7240 5410 I Packers and SSV's Attachment SW Name Type MD TVD Depscription NGI-10 SSSV 2182 2134.92 7" Camco DB Nipple NGI-10 PACKER 8320 7229.59 7" Top Packer 3: WELL REMURES AN SSSV ■��NIN fr ITopo"* Lw ........_. ....- 1"CIA WI «v Minimum ! #! t# 7" HES RN NIPPLE PGWORATM W * :! •* t „ .0459 i = .: 3: WELL REMURES AN SSSV Ugam '�!3"}rt31EL#3L+►Z 91:112 -,L ,1)=6.276"*7*�f}=6 ■��NIN fr ITopo"* Lw ........_. Ugam '�!3"}rt31EL#3L+►Z 91:112 -,L ,1)=6.276"*7*�f}=6 fr ITopo"* Lw ........_. ....- PGWORATM W FdF E 1111411976 AtNME AT TOP PEW: 36" @ 92W %fer to F*ion DB for tDr" pari data SIZE SPF AL T SOZ 2-W 4 3 0 11177 3-3W 4 0 07/04190 3-3W 6 9462-9482 0 10114 3-3Ar 4 9452-9492 0 G7/04/90 3 6 9482-9492 0 09110114 3 6 9515-9540 0 OWWI4 3 4 9515-9540 0 OSMIT7 3 6 0 09M14 3 4 C? 11 3-30 6 9610-9640 0 14 3-3V 4 9610-9644 U 1117% 3 4 6- 006/11/777 3-W 4 9713-9748 0 0611lf777 3-31T 4 9799-9824 0 OStlIf777 1* IMOF SALTP (01l iT 7"LW 29k N-80 W", .0371 bpf, 9 = 6.164" 99W F%JMMBAY AS No- 504Y29-2=9-00 IIII s • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, March 15, 2012 TO: Jim Regg �®� ?� i ( 1.z� P.I. Supervisor `� - I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -10 FROM: Matt Herrera PRUDHOE BAY UNIT NGI -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supra NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI -10 API Well Number: 50- 029 - 20229 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH120312134258 Permit Number: 176 -069 -0 Inspection Date: 3/12/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI -10 Type Inj. G TVD 7276 - IA 250 3910 3905 [ 3905 - PTD 1760690 ' TypeTest SPT Test psi 3900 - OA o 0 0 o Interva RE P/F P - Tubing 3370 3360 3360 3360 Notes: AIO 4E.006, MITIA every 4 years - '' A y 2,t r Thursday, March 15, 2012 Page 1 of 1 \-tG-0G'11 31 -JAN -2012 -z\ -L44 Schlumbeirger 5885 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01-24A BINC-00093 INJECTION PROFILE 15 -Jan -12 1 1 01-25 BBSK-00105 INJECTION PROFILE 9 -Jan -12 1 1 14-44A BUTT -00054 MEMORY LEAK DETECT LOG 28 -Dec -11 1 1 01-02 BVYC-00024 CROSSFLOW CHECK 30 -Dec -11 1 1 V-212 BAUJ-00106 MEMORY INJECTION PROFILE 26 -Dec -11 1 1 S-110 BX69-00018 USIT 7 -Jan -12 1 1 01-02 BYS4-00015 CROSSFLOW CHECK 4 -Jan -12 1 1 R-16 BG41-1-00106 SBHPS 23 -Dec -11 1 1 01-30 BD88-00189 MEMORY INJECTION PROFILE 19 -Dec -11 1 1 15-47 BG41-1-00105 CEMENT BOND LOG SCMT 20 -Dec -11 1 1 13-12A BVYC-00018 ISOLATION SCANNER 30 -Nov -11 1 1 MPI -18 BG41-1-00107 ISOLATION SCANNER 25 -Dec -11 1 1 NGI-10 BBSK-00102 USIT 16 -Dec -11 1 1 Z-116 BBSK-00104 ISOLATION SCANNER 22 -Dec -11 1 1 V-222 BUTT -00051 MEMORY INJECTION PROFILE 26 -Dec -11 1 1 V -106A BCRJ-00108 FSI 15 -Aug -1 I 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING UNE cvrY tAL;H I U: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. (�(ANNFT) NOV 1 4 2uiAnchorage, AK 99503-2838 11 STATE OF ALASKA ALASIllkIL AND GAS CONSERVATION COMMINCN ` REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well IS Alter Casing 0 Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory - 176 - 069 3. Address: ® Service ❑ Stratigraphic 6. API Number P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 - 029 - 20229 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 028302 PBU NGI -10 9. Field / Pool(s): ,_ Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 9990' feet Plugs (measured) None feet true vertical 8556' feet Junk (measured) None feet Effective depth: measured 9904' feet Packer: (measured) 8320' feet true vertical 8491' feet Packer: (true vertical) 7277' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 2310' 13 -3/8" 2810' 2810' 5380 2670 Intermediate Production 8815' 9 -5/8" 8815' 7660' 6870 4760 Liner 9163' 7" 8523' - 9986' 7433' - 8553' 8160 7020 Perforation Depth: Measured Depth: 9265' - 9824' True Vertical Depth: 8017' - 8432' Tubing (size, grade, measured and true vertical depth): 7 - 5/8 ", 29.7# x 7 ", 26# L - 8498' 7413' Packers and SSSV (type, measured and true vertical depth): 9 - 5/8" x 7" HES 'TNT packer � . : 7277' WE I 11. Stimulation or cement squeeze summary: JAN 2 4 2012 Intervals treated (measured): :I2. a thl & Gas Cans_ CammissiniT Treatment description including volumes used and final pressure: `e: ',"1;-" Pump salt plug to cover perfs. Dump 16 gallons Class 'G' cement cap on top of salt plug. Cut and pull tubing, mill up and retrieve packer. Cut and pull 9 -5/8" casing from 2310'. Run 9 -5/8" tieback to surface and cement w/ 153 Bbls Class 'G' (Yield 1.17). Clean out cement and salt plug to 9108'. Run new completion. Post Rig: Clean out salt plug to 9831'. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory ❑ Development -r 0 Service ❑ Stratigraphic 0 Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: IS GINJ ❑ Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Wilmer Hoffman, 564 -4592 311 - 174 Printed Name Terrie Hubble Title Drilling Technologist Si nature I M ii, Phone 564 - 4628 Date 0'/ Prepared Bye 56 - 462 g `�L� " f ,�(� ' ��Z. T errie Hubble, 564 4628 Form 10-404 Revised 10/2010 RBDMS JAN 28 2012 (, k f,i, i • �1 I . 0., ,, ,A7 Submit Original Only (L t • • NGI -10, Well History (Pre Rig Workover) Date Summary 07/12/11 T /I /O= SSV /500/0 Temp =Sl PPPOT-T (PASS) PPPOT -IC (PASS) (Pre RWO) PPPOT -T : RU 1 HP BT onto THA 50 psi to 0 psi. Pressured to 5000 psi for 30 minute test, 4900/ 15 min, 4900/ 30 min, bled void to 0 psi. RD test equipment re installed Alemite cap. Cycle and torque LDS "Standard" all were in good working and visual condition. PPPOT -IC : RU 2 HP BT onto IC test void 50 psi to 0 psi. Flushed void until clean returns achieved, pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled IC void to 0 psi, RD test equipment re installed Alemite cap. Cycle and torque LDS (1) LDS @ 3:00 top flange is bent left out "Standard" all were in good working and visual condition. 07/25/11 WELL S/I ON ARRIVAL (Secure). MIRU TO PULL SSSV, SET TT PLUG FOR SECURE. 07/26/11 WELL S/I ON ARRIVAL (Secure). TAG SSSV 2146' SLM WITH 6.05" G -RING. PULL MCX (BPX- 722) SSSV FROM 2173' MD. TAG BTM AT 9804' ELM W/ 3.25" CENT, S.BAILER. 20' OF FILL, SAMPLE OF SCHMOO. PERFORM SBHPS AS PER MODIFIED PROGRAM. LRS LOADING TBG W/ 1% KCL PRIOR TO RUNNING TT PLUG. 07/27/11 SET 5 1/2" PXN PLUG © 8370' MD. SET 7" OTIS DSSSV C© 2149' SLM. LRS PERFORMED MIT -T 3000# - PASS. WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON STATUS. 09/12/11 T /I /O= 100/400/400 TEMP= SI RG 2401 (SURFACE CASING CORR MITIGATION) PJSM. SET UP HYDRO VAC AND JOB SITE. START AND COMPLETE EXCAVATION ON WELL CELLAR. RDMO. VOID = SEALED CONDUCTOR, NO TREAT. 10/31/11 WELL S/I ON ARRIVAL. RIG UP. PULL 7" OTIS DSSSV FROM SSSV -NIP AT 2149' SLM / 2173' MD. PULL 5 -1/2" PXN PLUG & EQ -PRONG FROM 5 -1/2" XN -NIP C© 8360' SLM / 8370' MD. PERFORM SLB SBHPS PER PROGRAM (good data). WELL S/I ON DEPARTURE, DSO NOTIFIED. 11/02/11 MIRU Pump & batch mixer. 11/03/11 Pumped the following fluids to load and kill well then place salt pill across perforations. 7 bbl spear of 60/40 methanol, 498 bbls of 2% KCL, 25 bbls of 9.9 ppg NaCI saturated brine high viscosity spacer, 106 bbls salt pill in saturated NaCI brine (20,000 Ibs) © 12.2 ppg, 18 bbls of 9.9 ppg NaCI saturated brine high viscosity spacer, 146 bbls of 3% KCL, 83 bbls of 60/40 methanol at this point started to see WHP response from 237 psi up to 532 psi slowed rate to .7 bpm attempting to build pressure. Shut down C© 93 bbls of 60/40 for a total of 368 bbls = leading edge of salt pill at bottom of perforations. Shut down and waited 80 minutes to give salt a chance of bridging /settling out. Brought pump on line at .7 bpm and pressured up to 1100 psi in 4.2 bbls. Pressure fell off slowly and seem to hold at 940 psi. Then fell very slowly with hesitations. RD and let remaining salt fall out for 12 hrs then Slickline can find top of salt plug. Job Complete. 11/06/11 WELL S/I ON ARRIVAL. TAG TT C© 8381' SLM/ (22' CORRECTION 8403' ELMD) W/3.75" CENT /5 -1/2" TEL/2" S -BLR. TAG SOFT TD C© 9068' SLM / 9090' ELMD (window = 8600 - 9200'). DUMP 8.25 gal OF 15.80 ppg CLASS 'G' CEMENT C© 9,050' SLM / 9,072' MD W /10x3.0" DUMP BAILER, K -JAR & 2.76 CENT. 11/07/11 DUMP 7.75 additional gal, FOR A TOTAL OF 16 GALLONS OF 15.80 ppg CLASS 'G' CEMENT © 9,050' SLM / 9,072' MD. SET 7" OTIS DUMMY SSSV (4.65" ID, two sets w/ oversize packing sandwiches). RAN 4.40" CENT, PASS THRU DSSSV & RAN OUT TT, NO PROBLEMS. WELL S/I ON DEPARTURE, DSO NOTIFIED. Page 1 of 2 • • NGI -10, Well History (Pre Rig Workover) Date Summary 11/11/11 T /I /0= 10/323/0 MIT -T PASSED to 1500 psi, MIT -IA PASSED to 4000 psi (Pre RWO) Pumped 8.5 bbls 60/40 meth down the Tbg to pressure up to 1500 psi for MIT -T. The TBG lost 44 psi in the 1st 15 min and 20 psi in the 2nd 15 min for a total pressure loss of 64 psi in 30 min test. Pumped 25.47 bbls 60/40 down IA to achieve test pressure of 4000 psi for MIT -IA. IA lost 32 psi in the 1st 15 min and lost 15 psi in the 2nd 15 min for a total pressure loss of 47 psi in 30 min test. Bled IA to 300 psi. DSO notified. 11/15/11 WELL SHUT IN ON ARRIVAL. (ELINE TUBING CUT) INITIAL T /I /0= 1500/300/450 RIH WITH PEK- B13 -3/8" EQF /CAL- B /2XSHOCK MANDRELS CENTERED WITH 2X 5" GEMCOS /FH/4.15. JET CUT CUT TUBING AT 8367' CCL TO CUT DEPTH = 8.13', CCL STOP DEPTH = 8358.87'. VISUAL CONFORMATION OF SHOT FIRED. LEFT 710 PSI DIFFERENTIAL BETWEEN TxIA, DHD WILL MONITOR DIFFERENTIAL IN AM. FINIAL T /I /O= 200/910/400. WELL LEFT SHUT IN. PE NOTIFIED OF DEPARTURE. JOB COMPLETE. 11/16/11 T /I /0= 14/836/780 Temp =Sl Establish Communication from Tbg to IA Post Tbg Cut (Pre -RWO). Pumped 3.25 bbls 60/40 meth down Tbg to establish communication through the jet cut to the IA. Positive communication established. FWP= 700/205/640. 11/17/11 T /I /0= 800/240/440. Circ well to 9.8 ppg Brine (Pre -RWO). Pumped down Tbg thru Tbg cut up the IA to open top tanks with 5 bbl neat spear followed by 376 bbls of 9.8 ppg brine, then 5 bbl meth spacer followed by 157 bbls diesel. U -tube TxIA. 11/18/11 CMIT -TxIA PASSED to 500 psi (RWO Prep) CMIT -TxIA in progress. T /IA lost 3 psi in the 1st 15 min and lost 5 psi in the 2nd 15 min for total pressure loss of 8 psi in 30 min test. Bled W HP's to 0 psi. F W H P's= 0/0/0. 11/27/11 T /I /O = 0 /0 /0 Conduct PJSM. Verify barriers. Rig up lubricator and test to 300 psi low and 3500 psi high. Set 6" Gray K BPV © 114" w/ 1 -18" ext. Installed new 3" HWO gate valves on backside I/A and O /A. Set VR plugs and removed fronside I/A and O/A valves. Left frontside with VR plugs and blind flanges installed. All flanges and valves were tested to 2500 psi. Page 2 of 2 • • North America - ALASKA - BP Page 1 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/3/2011 06:00 - 12:00 6.00 MOB P PRE PJSM - STRING DRILLING LINE INTO RIG FLOOR - SPLICE NEW DRILLING LINE TO OLD -HANG BLOCKS, REMOVE DEADMAN WRAPS 12:00 - 15:00 3.00 MOB P PRE PJSM - SLIP 1650' NEW DRILLING LINE - TUBOSCOPE COMPLETE - CATIII INSPECTION ON DEADMAN 15:00 - 19:00 4.00 MOB P PRE BRIDAL UP FOR LAYING DERRICK OVER - READY RIG FLOOR - LOWER CATTLE CHUTE - PJSM -LOWER DERRICK 19:00 - 22:00 3.00 MOB P -_ PRE PULL RIG OFF WELL AND STAGE ON PAD - CLEAN AND SECURE AROUND DS1 -11 22:00 00:00 2.00 MOB P ■- PRE CRADLE BOPE A D REMOVE FROM CELLAR - INSTALL REAR BOOSTERS - CLEAN AROUND DS1 -11 12/4/2011 00:00 - 01:30 1.50 MOB P -_ PRE PJSM - MOVE RIG AROUND TO FRONT OF PAD DS1 01:30 - 12:00 10.50 MOB N WAIT _ PRE WAIT ON WEATHER - GENERAL HOUSEKEEPING / MAINT. 12:00 - 21:00 9.00 MOB N WAIT PRE WAIT WEATHER - COMPLPL COMPLETE WORKORDERS - HOUSKEEPING 21:00 - 00:00 3.00 MOB P ._ PRE START RIG MOVE TO NGI-10 - HAUL EQUIPMENT TO NGI 12/5/2011 00:00 - 02:30 2.50 MOB P PRE CONTINUE MOVE RIG TO NGI PAD 02:30 - 03:30 1.00 MOB P ._ PRE REMOVE REAR BOOSTERS - REMOVE BOPE FROM CRADLE 03:30 12:00 8.50 MOB P ■- PRE PJSM - RECONFIGURE BOP STACK TO 4 RAM PREVENTER 12:00 - 15:30 3.50 RIGU P PRE LAY DOWN RIG MATS, HERCULITE AROUND WELL - SPOT RIG OVER WELL - CLOSE DOORS AND CHINK CELLAR - INSPECT AND CLEAR DERRICK FOR EXCESS SNOW / ICE BUILDUP 15:30 19:00 3.50 RIGU P ■- PRE RAISE AND SECURE DERRICK -RAISE TUGGERS, CATTLE CHUTE ✓ - SPOT MUD PUMP #2 AND GENERATOR #3 19:00 - 00:00 5.00 RIGU P PRE BRIDAL DOWN - SECURE RIG FLOOR - BRING ON 290 BBLS 9.8PPG BRINE @ 100 DEGREE AT 21:30 - SECURE CELLAR - RU SQUEEZE MANIFOLD - RU SECOND IA VALVE AND CIRCULATING LINES 12/6/2011 00:00 - 01:00 1.00 RIGU P ._ PRE CREW CHANGE AND PJSM'S CONTINUE TO RU CIRCULATING LINES 01:00 - 01:30 0.50 RIGU P -_ PRE LOAD DSM HYDRAULIC LUBRICATOR BRING LUBRICATOR TO RIG FLOOR Printed 1/16/2012 11:12:19AM 4110Notth America - ALASKA - BP • Page 2 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 02:00 0.50 RIGU P PRE CALL MAN DOWN IN CELLAR DRILL WHICH LEAD TO H2S / RIG EVAC DRILL - PULLED DRILLER FROM THE FLOOR AND ASKED HIM TO ACCOMPANY ME TO THE CELLAR TO CALL THE DRILL. - RIG CREW MADE A GOOD EFFORT TO RESPOND AND THEN MUSTER IN THE PRIMARY SAFE AREA. - "LOST' A FEW FIRST RESPONDERS TO H2S IN CELLAR PRIOR TO GAS DETECTOR GETTING THERE - ALL THIRD PARTY PERSONAL ON LOCATION RESPONDED TO THE DRILL AND SHUT DOWN THERE VEHICLES AS WELL. - AAR TO DISCUSS HOW THE CREW DID WITHOUT THE DRILLER PRESENT AND TO REVIEW THERE DDI PROCEDURES. - GREAT DRILL 02:00 - 03:30 1.50 WHSUR P DECOMP PULL TREE CAP RU DSM LUBRICATOR TO TREE WITH MASTER AND SSV VALVES CLOSED IA = 0 PSI 03:30 - 05:30 2.00 WHSUR P DECOMP PRESSURE TEST LUBRICATOR AGAINST CLOSED MASTER VALVE PRESSURE TEST TO 250 PSI LOW AND 4,000 PSI HIGH FOR 5 CHARTED MIN 05:30 - 07:00 1.50 WHSUR P DECOMP PULL BPV WITH DSM LUBRICATOR WHP= 0 PSI 07:00 - 08:00 1.00 WHSUR P DECOMP RD DSM AND STAND BACK RD BPV FROM PULLING TOOLS 08:00 - 10:00 2.00 WHSUR P DECOMP RU CIRCULATING HEAD TO WELL HEAD PT CIRCULATING LINES TO 4,000 PSI 10:00 - 10:30 0.50 WHSUR P DECOMP FUNCTION TEST ESD SYSTEM, ALL GOOD. 10:30 - 11:00 0.50 KILLW P DECOMP PJSM. OPEN WELL TO CIRC OUT FREEZE PROTECT. - PUMP DOWN VA, AFTER (6) BBLS PUMPED, STARTING TO PRESSURE UP. - NO RETURNS UP TUBING, SUSPECT SUB SURFACE SAFETY VALVE. 11:00 - 11:30 0.50 KILLW P DECOMP BREAK LINES, VERIFY NO ICE PLUGS OR RESTRICTIONS. 11:30 - 17:30 6.00 KILLW P DECOMP PJSM. LINE UP AND PUMP DOWN TUBING. - 4 BPM / 1700 PSI ..., FULL RETURNS, (DIESEL). ✓ - CIRCULATE SFC TO SFC TO CIRCULATE OUT DIESEL FP FLUIDS - CHECK FOR FLOW WELL IS STATIC - OA PRESSURED UP TO 1500 PSI / BLEED OA TO 0 PSI 17:30 - 22:00 4.50 WHSUR P DECOMP RU DSM LUBRICATOR AND TEST TO 4,000 PSI - DSM CREW CHANGE AND PJSM - SET BPV - TEST BPV FROM BELOW TO 1,000 PSI FOR 30 CHARTED MIN - RD DSM - ALSO HELD RIG EVAC DRILL WITH A CREW SO BOTH CREWS HAVE NOW HAD A RIG EVAC DRILL Printed 1/16/2012 11:12:19AM 4110North America - ALASKA - BP Page 3 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TN0 -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:00 1.00 WHSUR P DECOMP CAMERON HANDS BLEED DOWN VOIDS TO ZERO - REMOVED SIDE MANDERAL JEWLERY - BLEED DOWN AND CAPPED CONTROLL LINES - INSTALLED SIDE MANDERAL BLINDS 23:00 - 00:00 1.00 WHSUR P DECOMP PJSM - BREAK OUT THROUGH BOLTS ON TREE ADAPTOR FLANGE 12/7/2011 00:00 - 02:30 2.50 WHSUR P DECOMP CREW CHANGE AND PJSM'S - CONTINUE TO ND TREE AND ADAPTOR FLANGE - PULL TREE AND LAY DOWN - PULL ADAPTOR FLANGE AND LAY DOWN - INSTALL K PLUG TEST DART 02:30 - 06:00 3.50 BOPSUR P DECOMP PJSM /NU BOPE - PU BOP STACK FROM TRANSPORT STUMP - MU STACK TO WELL HEAD 06:00 - 09:00 3.00 BOPSUR P DECOMP PJSM, INSPECT EMPTY BOP RAM CAVITIES - INSTALL 7" RAMS IN THE TOP. - INSTALL BLIND SHEAR RAMS. - INSTALL 3 1/2" X 6" VBR IN BOTTOM. 09:00 - 11:00 2.00 BOPSUR P DECOMP RU TO TEST BOPE 11:00 - 15:00 4.00 BOPSUR N RREP DECOMP REPLACE OTECO FITTING ON KILL LINE AT BOP -TAKE HUB ASSEMBLY TO API FOR INSPECTION AND CERTIFICATION INSPECT DERRICK WHILE WAITING ON PARTS 15:00 - 21:00 6.00 BOPSUR P DECOMP TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS - RAMS TESTED TO 250 PSI LOW AND 4,000 PSI HIGH. - HYDRILL TESTED TO 250 PSI LOW AND n b c 3,500 PSI HIGH - TEST USING 7" AND 4" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. - ALL TEST WITNESSED BY BP WSL / DDI TP. - ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT -AK -10-45 - HAD 2 FAIL / PASS - CHOKE VALVE # 7 REQUIRED GREASED / CYCLING THEN PASSED. - 2" OTECO HUB ASSEMBLY ON KILL SIDE. REQUIRED REBUILD & TUBOSCOPE MPI TEST, REINSTALLED & PASSED TEST AS MISC. TEST WITNESS WAIVED BY JOHN CRISP OF AOGCC 21:00 - 22:00 1.00 BOPSUR P DECOMP FUNCTION TEST BOPE: KOOMEY DRAW DOWN TEST: -2850 PSI DRAWN DOWN TO 1700 PSI -200 PSI INCREASE IN 18 SECONDS. -FULL PRESSURE IN 87 SECONDS. -5 N2 BOTTLES @ 2000 PSI. CLOSING TIME OF BOP PREVENTERS: - ANNULAR - 17 SEC AT 1450 PSI -7 "RAMS -10 SEC AT1450PSI - VRB RAMS - 8 SEC AT 1450 PSI - BLINDS - 18 SEC AT 800 PSI Printed 1/16/2012 11:12:19AM Worth America - ALASKA - BP Page 4 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TN0 -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11:10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 03:28 BOPSUR P -_ DECOMP RD BOPS TEST EQUIPMENT BLOW DOWN ALL SURFACE EQUIPMENT 22:30 - 00:00 1.50 BOPSUR P -_ DECOMP RU DUTCH RISER RU DSM LUBRICATOR WITH QUICK TEST SUB 12/8/2011 00:00 - 01:30 1.50 BOPSUR P DECOMP CREW CHANGE, PJSM PT DSM LUBRICATOR AGAINST TEST DART TO 250/3,500 PSI FOR 5 MIN EACH BREAK OF DSM LUBRICATOR AT Q/T SUB 01:30 - 02:00 0.50 BOPSUR P -_ DECOMP SUCK OUT BOP STACK PULL TEST DART 02:00 - 03:00 1.00 BOPSUR P ■- DECOMP DSM LUBRICATOR AT QUICK TEST SUB TEST BREAK EAK S AT QT SUB TO O 3 3, ,500 PSI PULL BPV 03:00 - 03:30 0.50 BOPSUR P ■- DECOMP RD DSM LUBRICATOR PULL DUTCH RISER CLEAR TOOLS FROM RIG FLOOR 03:30 - 05:00 1.50 PULL P DECOMP RU TO PULL 7" COMPLETION RU ECKEL TONGS MU SAFETY JOINT AND CROSS OVERS MU FLOOR SAFETY VALVE AND CROSS OVERS BRING IN BAKER FISHING TOOLS MU ELEVATORS PJSM FOR PULLING TUBING 05:00 - 05:30 0.50 PULL P -_ DECOMP MU 6.22" SPEAR GRAPPLE WITH PACK OFF ASSEMBLY 05:30 - 06:30 1.00 PULL P DECOMP SPEAR ASSEMBLY PACK OFF IS TORN WHEN COVER WAS REMOVED BREAK DOWN TOOLS TO REMOVE PACKOFF CHANGE OUT PACK OFF AND MU TOOLS AGAIN 06:30 - 07:00 0.50 PULL P DECOMP PUMP OUT BOP STACK -RIH HOLE WITH 6.20" SPEAR 33' -NO -GO AT 22' - ENGAGE SPEAR AND M/U TOP DRIVE. 07:00 - 07:30 0.50 PULL P -_ DECOMP CAMERON REP BOLDS -WSL VERIFY IA IS STATIC. 07:30 - 08:00 0.50 PULL P ■- DECOMP PJSM, PULL TBG HANGER OFF SEAT AT 285 -PULL TO RIG FLOOR 300 - 360 K PUW. 08:00 - 10:30 2.50 PULL P DECOMP PJSM, CIRCULATE SURFACE TO SURFACE THROUGH THE GAS BUSTER. -6 BPM / 670 PSI -SPR #1 30 SPM /100 PSI, 40 SPM 190 PSI -NO LOSS / NO GAIN. -NO DEBRIS AT SHAKER. 10:30 - 11:00 0.50 PULL P -_ DECOMP MONITOR WELL, STATIC -PJSM ON BRAKE OUT SPEAR. 11:00 11:30 0.50 PULL P ■- DECOMP DISENGAGE SPEAR FROM TBG Y -BR OU -BREAK OUT AND UD SPEAR ASSEMBLY WITH BAKER REP. 11:30 - 12:00 0.50 PULL P DECOMP BLOW DOWN TOP DRIVE, KILL & CHOKE LINES. -L /D TBG HANGER - TBG HANGER LOOKS GOOD. 12:00 - 13:30 1.50 PULL P ■- DECOMP PJSM PERFORM K SERVICE PRE-TOUR CHECKS R/U SHLUMBERGER SPOOLER Printed 1/16/2012 11:12:19AM *North America - ALASKA - BP Page 5 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TN0 -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11:10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 19:00 5.50 PULL P DECOMP RIG UP 200 TON 7" ELEVATORS LD 20 JTS 7" IJ4S TUBING (RECOVERED 8 CLAMPS) 300 -400K PUW, WORK EACH JT. OUT OF HOLE SOW 150K LOSE CONTROL LINE AND CLAMPS AFTER 11 JTS OUT ESTIMATE OF —440 FEET OF DUAL CONTROL LINE RECOVERED AFTER JT. 17 WELL BORE PACKING OFF WITH DEBRIS ON JT.20 STOPPED TO FILL TUBING STOP AT JOINT # 22 TO CALL TOWN 19:00 - 20:00 1.00 PULL P DECOMP CALL TOWN TO ADVISE OF CURRENT CONDITIONS AND POSSIBLE PLANS 20:00 - 22:30 2.50 PULL P DECOMP_ CONTINUE TO PULL TUBING FROM JOINT #22 -PULL TUBING WITH ABOUT 115 K OVER PULL LIMIT AND WORK PIPE UP AND DOWN -PIPE IS MOVING FREELY DOWN MOST OF THE TIME -AT JOINT # 28 ADD 10 GAL OF SAFE LUBE AT THE RIG FLOOR - REFILL TUBING AT JOINT #30 TO MAINTAIN TRIP SHEET -SAFE LUBE APPEARS TO BE HELPING A LITTLE -LD JOINT #31 FOR 10 JTS IN 2.5 HRS OR 4 JTS /HR 22:30 - 00:00 1.50 PULL P DECOMP CONTINUE TO LAY DOWN 7" TUBING FROM JOINT #32 TO JOINT #42 -SUCK OUT STACK AT JOINT #33 TO BE ABLE TO SEE CONTROL LINE -ADD ANOTHER 10 GAL OF SAFE LUBE TO WORK IN 12/9/2011 00:00 - 03:00 3.00 PULL P DECOMP LAY DOWN 7" IJ4S TUBING FROM JNT #43 - TUBING STILL PULLING HARD, UP TO 125K OVER - WORK PIPE UNTIL FREE BEFORE SETTING SLIPS - JOINT #53 CAN BE PULLED OUT OF HOLE - TAGGING UP HARD AT 350 K WITHOUT MAKING ANY FOOTAGE WITH JNT 53 + 5 FT 03:00 - 03:45 0.75 PULL P DECOMP RIH TO MID JOINT 53 SET SLIPS AND ROTATE 1/2 TURN - WORK PIPE AND GAIN MINIMAL FOOTAGE - SET SLIPS AGAIN AND ROTATE 2 TURNS - WORK PIPE AND LAY DOWN JOINT 53 - CONTINUE TO WORK PIPE UP HOLE - WORK SSSV ASSEMBLY OUT OF HOLE WITHOUT ANY CONTROL LINE AT SURFACE LAID OUT A TOTAL OF 53 FULL JOINTS AND ONE 30 FT SPACE OUT PUP (PUP WAS COUNTED AS JNT #1 SO WE HAD A COUNT OF 54 JOINTS OF 7" IJ4S TUBING ) - RECOVERED 13 RUBBER CONTROL LINE CLAMPS Printed 1/16/2012 11:12:19AM •Narth America - ALASKA - BP Page 6 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TN0 -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:45 - 06:00 2.25 PULL P DECOMP - CHANGE OUT DIES IN ECKELS FOR 8 RD COLLARS - CHANGE OVER CROSS OVER ON FLOOR SAFETY VALVE - LAY DOWN SSSV ASSEMBLY - CONTINUE TO LAY DOWN 7" 8 RD TUBING WITH JNT # 55 - CONTINUE TO STOP AND FILL TUBING EVERY 5 JOINTS WITH 9.8 PPG BRINE 06:00 - 09:00 3.00 PULL P DECOMP CONTINUE TO PULL AND LAY DOWN 7" 8 RD TBG FROM JNT# 56 TO #75. - CONTINUE TO STOP AND FILL TUBING EVERY 5 JOINTS WITH 9.8 PPG BRINE - MONITOR BOP STACK FOR ANY DEBRIS. 09:00 09:30 0.50 PULL P ■- DECOMP WEEKLY CREW CHANGE -PJSM AND PERFORM PRETOUR CHECKS - PERFORM RIG SERVICE. 09:30 - 10:30 1.00 PULL P DECOMP DENALI CRANE INSPECTOR PERFORMED PULL TESTING AND INSPECTION ON -MAN RIDER TUGGER -RIG FLOOR TUGGERS -BOPE CRANES 10:30 - 17:30 7.00 PULL P DECOMP CONTINUE POH F/ JNT# 75 TO 5 1/2" TUBING CUT JOINT - CONTINUE TO STOP AND FILL TUBING EVERY 5 JOINTS WITH 9.8 PPG BRINE -NO LOSS / NO GAINS -207 TOTAL JOINTS OF 7" TUBING LAID DOWN -5 1/2" CUT JOINT = 8.80 FT , FLARE DIAMETER = 6.25" 17:30 - 19:30 2.00 PULL P DECOMP RD FROM PULLING LINER CLEAR AND CLEAN RIG FLOOR BRING IN BAKER TOOLS DISCUSS PLAN FORWARD WITH TOWN 19:30 - 00:00 4.50 FISH P DECOMP PJSM & MAKE UP ROPE SPEAR TO ONE JOINT OF 4" DP - FISH CONTROL LINE OUT OF BOP STACK - CONTROL LINE IS PACKED INTO LOWER PIPE RAM CAVITY - LINE IS VERY BRITTLE AND BREAKS APART EASY BUT IS ALSO PACKED IN TIGHT - SPEAR BREAKS THROUGH LINE EASY BUT ONLY BRINGS OUT SMALL PIECES - BIGGEST PIECE MAY BE ABOUT 3 FOOT LONG Printed 1/16/2012 11:12:19AM •North America - ALASKA - BP Page of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11:10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/10/2011 00:00 - 04:00 4.00 FISH P DECOMP CREW CHANGE WITH C CREW COMING IN FOR FIRST NIGHT BACK - LAY DOWN ROPE SPEAR AND PU MULE SHOE CROSS OVER - PICK AT DEBRIS PILE IN LOWER PIPE RAMS - PUMP THROUGH MULE SHOE AT 10 BPM TO CLEAN OUT SMALL DEBRIS - USE MULE SHOE TO WORK WIRE OUT OF RAMS SOME MORE - PU SPEAR AND ATTEMPT TO PULL CONTROL LINE - RECOVER SOME BUT BREAK UP AND NOCK DOWN MOST OF IT - ALSO USE SMALL HOOK WITH ROPE TO GRAB SMALL PIECES FROM THE TOP OF PILE WHEN ABLE - NO GAINS OR LOSSES WHEN PUMPING GOT LOWER PIPE RAMS CLEARED NOW WORK ON PILE IN SPACER SPOOL 04:00 - 05:00 1.00 FISH P DECOMP CONTINUE TO WORK WITH ROPE SPEAR AND SMALL HAND HOOK MORE OF THE SAME - RECOVERING SMALL BRITTLE PIECES ONLY 05:00 - 07:30 2.50 FISH P DECOMP PU STACK RINSING TOOL AND RIH TO FILL AND FLUSH -FLUSH KILL AND CHOKE LINES. - VACUUM OUT STACK. 07:30 - 08:30 1.00 WHSUR P DECOMP PJSM. M/U TBG HANGER ON LANDING JT. REDRESSED BY CAMERON REP. - LAND AND RILDS. 08:30 - 09:00 0.50 BOPSUR P DECOMP INSTALL DUTCH RISER SYSTEM 09:00 - 10:30 1.50 WHSUR P DECOMP M/U DSM LUBRICATOR - INSTALL BPV [K -PLUG] - 1,000 PSI TEST FROM BELOW F /30 CHARTED MIN. GOOD TEST. 10:30 - 11:00 0.50 WHSUR P DECOMP R/D DSM LUBRICATOR - INSTALL TEST DART - UD DUTCH RISER SYSTEM 11:00 - 15:30 4.50 BOPSUR P DECOMP OPEN TOP BOP DOORS INSPECT AND CHANGE RAMS TO 2 7/8" X 5" VBR. - OPEN AND INSPECT BLIND SHEAR AND LOWER PIPE RAMS. 15:30 - 19:00 3.50 BOPSUR P DECOMP RU AND SHELL TEST BOP'S AND UPPER PIPE RAMS -TEST TO 250 LOW /4000 PSI HIGH FOR 5 MIN -HAD TO PULL AND CHANGE SEALS ON K PLUG TEST DART TO GET GOOD TEST -RD TEST EQUIPMENT 19:00 - 21:30 2.50 WHSUR P DECOMP DRAIN STACK -PULL TEST DART -RU DUTCH RISER AND DSM LUBRICATOR - PULL BPV WITH IA VALVES OPEN AND NO PRESSURE BELOW - RD DUTCH RISER AND DSM - BACK OUT LDS AND PULL TUBING HANGER TO RIG FLOOR 21:30 - 22:30 1.00 BOPSUR P DECOMP - CLEAR AND CLEAN RIG FLOOR OF TUBIUNG HANGER AND DSM TOOLS - BRING IN BAKER TOOLS Printed 1/16/2012 11:12:19AM Narth America - ALASKA - BP Page 8 of 27 • Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11:10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 00:00 1.50 FISH P DECOMP PJSM/ MU 8 -1/2" FLAT BOTTOM SHOEIWASH PIPE BHA - MU BHA WITH MOUSE HOLE - TORQUE BOTTOM JOINT BEFORE CREW CHANGE 12/11/2011 00:00 - 00:30 0.50 FISH P DECOMP CREW CHANGE AND PJSM FOR MU OF BHA - DURING CREW CHANGE ONCOMING CREW FOUND IA VALVE LEFT OPEN AND LEAKING INTO BUCKET. APROXIMATELY 2 GAL LEAKED ONTO THE MATT BOARDS/HERCULITE IN A 6 FT X 3 FT SURFACE AREA. NOTIFIED5700, RWO SUPERINTENDENT, AND PAD OPERATOR. 00:30 - 01:00 0.50 FISH P DECOMP CONTINUE TO MU / TORQUE WASH PIPE BHA TAG -UP AT 35 FT AT — REVERSE JUNK BASKET -WE DID NOT PUT ANY EXTRA WEIGHT, OR TRY TO HARD TO GET THIS BHA IN HOLE AS WE STILL HADE UN- TORQUED CONNECTIONS OVER HEAD FROM BEING MADE UP IN MOUSE HOLE . 01:00 - 02:15 1.25 FISH P ■- DECOMP /LAY DOWN TOOLS AND RECONFIGURE WITHOUT WASH PIPE EXTENSIONS OR JARS AND BUMPER SUB 02:15 - 04:15 2.00 FISH P 112.00 DECOMP RIH AND TAG JUNK AT 59 FT PU AND GET PARAMETERS OF: 6 BPM = 1130 PSI & 50 RPM = 1.5 FT /LBS WASH DOWN WITH 1- 3 K WOB AND TQ= 1 TO 2 K PU FREQUENTLY IWITH CLEAN PU'S WASH DOWN ONE STAND TO 112 FT 04:15 - 06:00 1.75 FISH P DECOMP STAND BACK ONE STAND OF 4" DP -PULL BHA AND CHECK BOTTOM -FULL OF CONTROL LINE PIECES -CLEAR OUT REVERSE CIRCULATING JUNK BASKET AND FLAT BOTTOM SHOE - RECOVERED ABOUT 10 GAL OF SMASHED CONTROL LINE, CLAMPS, AND SCALE. -PU JARS, BUMPER SUB, AND ONE MORE 5 FT SECTION OF WASH PIPE 06:00 - 06:30 0.50 FISH P - 169.00 DECOMP RIH WASH F/112' T/169' MD 6 BPM / 1120 PSI, 50 RPM, 1K TQ. 06:30 - 07:30 1.00 FISH P 422.00 DECOMP CONTINUE RIH (P /U FROM PIPE SHED 1X1) PUMPS OFF F/169' T/390' 6 BPM / 1090 PSI 50 RPM TQ 1K 07:30 - 08:30 1.00 FISH P -_ DECOMP POH F/422' TO SURFACE. RECOVER 2.5 GAL. CONTROL LINE. 08:30 09:30 1.00 FISH P ■- DECOMP P/U AND ADD TO BHA - PU ALL 4 SECTIONS OF WASH PIPE EXTENSIONS 09:30 - 10:30 1.00 FISH P DECOMP P/U 9 EA. 6 1/4" DC'S 1X1 FROM PIPE SHED. Printed 1/16/2012 11:12:19AM North America - ALASKA - BP Page 9 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11:10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 12:00 1.50 FISH P 1,481.00 DECOMP RIH T/422' T/620' (1X1FROM PIPE SHED) START TO TAKE WEIGHT MP #1 3 BPM /200 PSI. 4 BPM / 450 PSI MP #2 3 /BPM / 260 PSI 4 BPM / 500 PSI. CONTINUE TO RIH T/ 1481' PUW 74K, SOW 70K. 12:00 - 13:30 1.50 FISH P DECOMP CIRCULATE & RECIPROCATE AT 1,481' 5 BPM / 1500 PSI, 10 RPM, 2.5K TQ PUW 74K, SOW 75K BLOW DOWN TOP DRIVE. 13:30 - 15:00 1.50 FISH P DECOMP RIH F/1481' T/2524 (1X1 FROM PIPE SHED) ESTABLISH SPR #1 30SPM =500 PSI, 40SPM =770 PSI, #2 30SPM =660 PSI, 40SPM =755 PSI HELD SURPRISE D-1 DRILL WITH THE RELIEF DRILLER ON THE BREAK AND DERRICK MAN OFF LOCATION. AAR: ADW SUPERINTENDENT & WSL PRESENT. 15:00 - 18:00 3.00 FISH P DECOMP RIH F/2524 T/3662 -EST. SPR #1 30SPM =1300 PSI, 40 SPM =2070 PSI, PRESSURES WERE SIGNIFICANTLY HIGHER THAN PREVIOUS, ASSUME PLUGGED JETS, DECIDE TO POOH -DROP BALL AND OPEN CIRC SUB, PUMP DRY JOB, BLOW DOWN TOP DRIVE 18:00 - 20:30 2.50 FISH P DECOMP POOH F/3662 TO BHA 20:30 - 22:30 2.00 FISH P DECOMP BREAK DOWN BHA - RECOVERED 1 GAL OF CONTROL LINE ENCAPSULATION DEBRIS AND 1 PC 3" X 6" METAL FROM JET BASKET -FOUND 2 OF 3 JET NOZZLE CLOGGED WITH CONTROL LINE DEBRIS ACCOUNTING FOR THE PRESSURE INCREASE, REMOVED SAME -CLEAR CLEAN RIG FLOOR 22:30 - 00:00 1.50 FISH P DECOMP M/U SAME BHA AND COLLARS -RIH TO 343' 12/12/2011 00:00 - 07:00 7.00 FISH P DECOMP RIH WITH REVERSE CIRCULATING JUNK BASKET (RCJB) -FROM 343' TO 3662' FROM DERRICK -CONT. PICK UP DP 1X1 F/3662' T/8340 07:00 - 09:30 2.50 FISH P DECOMP PUWT =165K, SOWT =145K, ROTW =155K, 60 RPM =5K TORQUE, 4 BPM =370 PSI -TAG JUNK AT 8325' MD - ROTATE AND WORK DOWN OVER JUNK -TAG TOP OF STUMP AT 8355' MD WITH 8K WOB -DROP RCJB BALL TO SEAT AND WORK FROM 8320' TO 8355'. 6 BPM =1670 PSI -WORK DOWN OVER STUMP FROM 8355 TO 8380' (RCJB SHOE DEPTH) Printed 1/16/2012 11:12:19AM North America - ALASKA - BP Page 10 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 10:00 0.50 FISH P DECOMP ATTEMPT TO PULL WITH NO ROTATION -PIPE STUCK TRYING TO COME OFF TOP OF STUMP - ATTEMPT TO JAR OFF 5X WITH 75K OVER PULLS - ROTATED, PUMPED AND WORKED PIPE IN FREE SPOT AND PULLED OFF STUMP - WORKED RCJB FROM 8315' TO 8355' 3X, 7.5 BPM =2250 PSI -TURN PUMPS OFF AND ROTARY OFF AND ATTEMPT TO STATIC TAG TOP OF STUMP AT 8355', DID NOT SEE TOP OF STUMP, SLACKED OFF 5' CLEAN TO 8360, PULL TO 8350' WITH NO OVERPULL NOTIFY TOWN RWO ENGR. OF OPS. 10:00 - 11:30 1.50 FISH P DECOMP DROP DART AND OPEN CIRCULATING SUB - ROTATE AND RECIPROCATE PIPE -PUMP SWEEP SURFACE TO SURFACE, 11 BPM =1490 PSI 11:30 - 17:00 5.50 FISH P DECOMP MONITOR WELL -POOH FROM 8355' MD TO BHA - MONITOR WELL 10 MINUTES -STAND BACK COLLARS 17:00 - 23:30 6.50 FISH P DECOMP UD BHA -BREAK DOWN REVERSE CIRCULATING JUNK BASKET - RECOVERED PIECE OF 5 1/2 TUBING STUB = 13.28', TUBING SNAPPED OFF JUST BELOW THE COLLAR IMMEDIATELY BELOW THE "XN" NIPPLE, BREAK LOOKS CLEAN - RECOVERED 17 GAL OF CONTROL LINE DEBRIS FROM WASH PIPE - CLEAR/CLEAN RIG FLOOR NOTIFY TOWN RWO ENGR. OF OPS, DISCUSS PLAN FORWARD 23:30 - 00:00 0.50 FISH P DECOMP PJSM, M/U BHA #7 ASSEMBLY WITH: -CUT LIP GUIDE, HOLLOW /DRESS OFF MILL, OVERSHOT 12/13/2011 00:00 - 01:00 1.00 FISH P DECOMP CONTINUE TO M/U BHA #7, OVERSHOT ASSEMBLY WITH: -CUT LIP GUIDE, HOLLOW MILL, AND OVERSHOT GRAPPLE - MU COLLARS TO 323' MD 01:00 - 04:00 3.00 FISH P DECOMP TIH WITH DRILL PIPE FROM DERRICK GET PARAMETERS AND SPR'S PUMP 1 = 2 BPM / 70 PSI & 4 BPM / 240 PSI PUMP 2 = 2 BPM / 60 PSI & 4 BPM / 240 PSI UP WT = 167 K AND WASH DOWN AT 3 BPM / 140 PSI 04:00 - 06:00 2.00 FISH P DECOMP TAG UP AT 8379 FT -5 FT SWALLOW MAKES TOP OF STUMP AT 8374 FT -SET DOWN 8 K WOB TWICE - STRAIGHT PULL 225 K - NO LUCK - START TO JAR AT 250 K - 12 JAR LICKS AND PIPE IS FREE PU AND FLOW CHECK WELL FOR 10 MIN Printed 1/16/2012 11:12:19AM North America - ALASKA - BP Page 11 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 06:30 0.50 FISH P ■- DECOMP PERFORM POST JARRING DERRICK INSPECTION. MONITOR WELL STATIC. 06:30 - 10:00 3.50 FISH P DECOMP POH F/8379' T/ 323' MD NO DRAG NOTED. 24 HOUR NOTICE OF WEEKLY BOPE TEST TO AOGCC AT 07:30. MATT HERRERA WAIVED WITNESS. 10:00 - 10:30 0.50 FISH P DECOMP RACK BACK DC'S BREAK OUT BHA UD FISH. RECOVERED CUT OFF PUP. 5.07" PUP, TBG COLLAR WITH PIN IN IT. SNAPPED OFF AT LAST THREAD OF PIN 10:30 - 11:30 1.00 FISH P DECOMP NOTIFY TOWN RWO ENGR. OF OPS, DISCUSS PLAN FORWARD CLEAN AND CLEAR FLOOR. MOBILZE AND THAW TOOLS. 11:30 - 13:30 2.00 FISH P - DECOMP M/U PACKER MILL ASSEMBLY, BHA #8 - SERVICE AND INSPECT TOP DRIVE 13:30 - 17:00 3.50 FISH P -_ DECOMP RIH TO 8306' -165K PUW, 148K SOW 17:00 19:00 2.00 FISH P ■- DECOMP SLIP AND CUT 61' AND 1. DRILLING LINE DRAW A - MECHANIC INSPECTED DRAW WORKS AND REPLACED COTTER PIN 19:00 - 19:30 0.50 FISH P DECOMP OBTAIN MILLING PARAMETERS AT 8306' -165K PUW, 148K SOW, 159K ROT WT, 8 BPM @ 850 PSI -SPR #1 MUD PUMP 30 SPM = 110 PSI, 40 SPM = 170 PSI -SPR #1 MUD PUMP 30 SPM = 160 PSI, 40 SPM = 230 PSI - CONTINUE RIH TO TAG PACKER AT 8385' 19:30 - 00:00 4.50 FISH P DECOMP MILL FROM 8385' TO 8387' @ 80 RPM, 4 -5K TORQUE, 8 BPM, 870 PSI, 5 -6K WOB - INCREASE TO 100 RPM, 5 -6K TORQUE, 10 -18 WOB -PUMP 20 BBL HI-VIS SWEEP, METAL PIECES AND CONTROL LINE RUBBER IN SWEEP RETURNS 12/14/2011 00:00 - 01:30 1.50 FISH P DECOMP CONTINUE TO MILL PACKER FROM 8387' TO 8388' -WOB 18 -23K, VARIABLE PUMP RATES @ 250 -300 PSI, 7 -10K TORQUE, 80 -100 RPM - PACKER CAME FREE 01:30 - 03:30 2.00 FISH P DECOMP POSITION TOOL JOINT -CLOSE ANNULAR AND CBU THROUGH THE CHOKE AND GAS BUSTER AT 5 BPM, 410 PSI. -NO HYDROCARBONS TO SURFACE. - MONITOR WELL, NO FLOW -BLOW DOWN CHOKE MANIFOLD AND TOP DRIVE 03:30 - 05:00 1.50 FISH P DECOMP CHASE PACKER TO BOTTOM AND TAG AT 8508' WITH 8K STACKED -PUMP HI-VIS SWEEP AT 12 BPM, 1750 PSI - DUMPED METAL AND RUBBER IN RETURNS - MONITOR WELL FOR 10 MIN 05:00 - 09:00 4.00 FISH P -_ DECOMP POH STANDING BACK 4" DP F/8508' TO SURFACE. Printed 1/16/2012 11:12:19AM O North America - ALASKA - BP Page 12 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- OOTNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 10:00 1.00 FISH P DECOMP SERVICE BOOT BASKETS, RECOVERED ONE SETTING BAND, FIVE GALS. METAL SHAVINGS. -MILL 50 % WEAR, PIECES OF PACKER SLIPS TUCK IN WATER COURSE OF MILL. -CLEAR RIG FLOOR OR TOOLS 10:00 - 10:30 0.50 FISH P DECOMP M/U STACK RINSING TOOL AND RINSE OUT BOP STACK 10:30 - 12:00 1.50 BOPSUR P DECOMP RIG UP TO TEST BOP'S. 12:00 - 12:30 0.50 BOPSUR P DECOMP PERFORM PRE -TOUR CHECK PJSM, ON TESTING BOPE. 12:30 - 18:00 5.50 BOPSUR P DECOMP WEEKLY TEST OF 135/8" BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS - RAMS TESTED TO 250 PSI LOW AND 4,000 PSI HIGH. - HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH 6 °P - TEST USING 4" TEST JOINT. - PRESSURE TEST FOR 5 CHARTED MIN. , - ALL TEST WITNESSED BY BP WSL / DDI TP. - ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 - ALL TESTS PASSED FUNCTION TEST BOPE: KOOMEY DRAW DOWN TEST: -2900 PSI DRAWN DOWN TO 1700 PSI -200 PSI INCREASE IN 34 SECONDS. -FULL PRESSURE IN 109 SECONDS. -6 N2 BOTTLES @ 2000 PSI. CLOSING TIME OF BOP PREVENTERS: - ANNULAR -18 SEC -UPPER PIPE RAMS - 6 SEC -LOWER PIPE RAMS - 6 SEC - BLINDS - 22 SEC AOGCC INSPECTER, MATT HERRERA, WAIVED STATE'S RIGHT TO WITNESS. 18:00 - 20:00 2.00 BOPSUR P DECOMP RD TEST EQUIPMENT -BLOW DOWN THE STACK AND SURFACE LINES - WEEKLY DERRICK INSPECTION 20:00 - 21:30 1.50 FISH P DECOMP PJSM -MU SPEAR BHA PER BAKER REP 21:30 - 00:00 2.50 FISH P DECOMP RIH FROM SURFACE TO 7554' -155K PUW, 145K SOW 12/15/2011 00:00 - 01:00 1.00 FISH P DECOMP RIH F/7554 TO 8508 - PUTW =167K, SOWT =150K - SPR #1, 3 BPM =180 PSI,4 BPM 350 PSI - SPR #2, 3 BPM =200 PSI, 4 BPM =380 PSI -TAG TOP OF PACKER AT 8508' MD -ENTER PACKER TO 8517' AND ENGAGE GRAPPLE WITH 10K DOWN WT - PULL PACKER OFF BOTTOM, SEE 25K OVER PULL, —3K DRAG 01:00 - 01:30 0.50 FISH P DECOMP PUMPED TUBING VOLUME OF 9.8 PPG BRINE TO BALANCE OUT WELL, 6 BPM =740 PSI - MONITOR WELL, NO FLOW 01:30 - 03:00 1.50 FISH P DECOMP POOH FROM 8517' MD TO 6000' MD Printed 1/16/2012 11:12:19AM •NorthArnericaALASKA*BP .. Page 13 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11:10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 03:30 0.50 FISH P DECOMP , - PERFORM KICK WHILE TRIPPING DRILL WITH MOTORMAN ON THE BRAKE -HOLD AAR MEETING WITH WSL - DISCUSSED ROLES, RESPONSIBILITIES AND CONTINGENCY PLAN FOR LEAKY SAFETY VALVE - RECOGNIZED CREW FOR EFFECTIVE NOTIFICATIONS MADE TO TOOL PUSHER, WSL, AND SCS 03:30 - 05:00 1.50 FISH P DECOMP CONTINUE POOH FROM 6000' MD TO 350' BHA - MONITOR WELL BEFORE PULLING BHA TO RIG FLOOR 05:00 - 06:00 1.00 FISH P DECOMP STAND BACK COLLARS -LAY DOWN SPEAR AND PACKER ASSY - PACKER AND TAIL PIPE = 10.47' -THE REMAINING SEAL ASSEMBLY WAS INSIDE THE TAIL PIPE WITH THE SPEAR STUCK, IT WAS ALL SENT OFF LOCATION TO BAKER MACHINE SHOP. 06:00 - 07:00 1.00 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR - COMPLETE TALLY OF 9 5/8" CSG. - SCHULUMBERGER E -LINE UNIT CREW WAS TIMED -OUT. 07:00 - 10:00 3.00 EVAL P DECOMP PJSM WITH SCHLUMBERGER E -LINE CREW. -MOVE IN AND SPOT E -LINE TRUCK. -R/U E -LINE TOOLS. 10:00 - 13:00 3.00 EVAL P DECOMP E -LINE RUN #1 - JUNK BASKET / GAUGE RING 5.95" OD - CAN NOT GO PAST 8625' MD ( —LINER TOP) - OBSERVE 400 LB OVER PULL. -POH F/8525' MD WITH RUN #1. -11:30 HRS CONFER WITH TOWN RWO ENGINEER ON PLAN FORWARD. - DRILLING HSE TEAM LEAD VISITED RIG. 13:00 - 14:00 1.00 EVAL P DECOMP BREAK DOWN JUNK BASKET , NO RECOVERY, NO WEAR MARKS. -M /U USIT FOR 9 5/8" CSG. ADW HSE COORDINATOR VISITED THE RIG 14:00 - 15:30 1.50 EVAL N DFAL DECOMP RIH W SLB USIT LOG TOOLS T/8500' -USIT TOOL FAILURE 15:30 - 17:30 2.00 EVAL N DFAL DECOMP POH T/ SURFACE - RD SLB USIT TOOLS /SHEAVES & WIRE LINE - SHORT IN USIT POWER HEAD -METAL PACKER SETTING RING CAME BACK WITH USIT TOOL 17:30 - 20:00 2.50 FISH P DECOMP LOAD BHA IN PIPE SHED - STRAP AND BRING BHA TO RIG FLOOR - SERVICE ROUGH NECK/ TOP DRIVE 20:00 - 23:00 3.00 FISH P DECOMP P/U CLEAN OUT BHA AS PER BAKER REP 23:00 - 00:00 1.00 FISH P DECOMP RIH WITH BHA #10 ON 4" DP F/ 820' T/2337' 12/16/2011 00:00 - 02:30 2.50 FISH P DECOMP RIH F/2337 T/8500 -SPR #1, 2BPM = 110 PSI, 4BPM = 210 PSI -SPR #2, 2BPM = 150 PSI, 4BPM = 260 - PUWT =165K, SOWT =150K, ROTW =160K -40 RPM = 4K TQ -4BPM = 300 PSI Printed 1/16/2012 11:12:19AM North America - ALASKA - BP Page 14 of 27 • Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TN0 -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11:10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 04:00 1.50 FISH P DECOMP CONFIRM LINER TOP TAG AT 8516' -TAG JUNK AT 8946 -MILL AND CLEAN OUT JUNK F/8946 T/9015 -PUMP 20 BBL HI VIS SWEEP WHILE CLEANING OUT 04:00 - 05:30 1.50 FISH P DECOMP PUMP 2ND 20 BBL HI VIS SWEEP -10.5 BPM= 1730 PSI - ROTATE AND RECIPROCATE PIPE - CONTROL LINE RUBBER, CEMENT CHUNKS (3" X 3" X 3/4 ") AND METAL PCS IN SWEEP RETURNS. 05:30 - 07:00 1.50 FISH P DECOMP MONITOR WELL FOR 10 MIN BEFORE PULLING OFF BOTTOM -POH F/ 9015', OBSERVE 40K OVER PULL, 10 -30K OVER PULL WHILE ROTATING OUT F/8911' T/ 8516', 7" LINER TOP. 07:00 - 07:30 0.50 FISH P DECOMP PUMP 20 BBLS HI-VISC SWEEP SURFACE TO SURFACE. -13 BPM / 2010 PSI - RECOVERED 3 GAL RED AND BLACK RUBBER AT THE SHAKER. 07:30 08:00 0.50 FISH P DECOMP C F/ 7" T TOP (0 D TAG AT CLEAN OUT DEPTH 901515' ' MD. -SLID TO BOTTOM WITH NO PROBLEMS. 08:00 08:30 0.50 FISH P ■- DECOMP MONITOR WELL STATIC -POH F/ 9015' TO TOP OF 7" LINER, CLEAN TRIP. 08:30 - 10:00 1.50 FISH P DECOMP PUMP 20 BBLS HI -VISC SWEEP SURFACE TO SURFACE. -12 BPM / 1940 PSI -VERY LITTLE SHOW IN RETURNS. - MONITOR WELL STATIC, AND BLOW DOWN TOP DRIVE. 10:00 - 12:30 2.50 FISH P DECOMP POH F/ 7" LINER TOP (8516') T/ 820'. 12:30 - 14:30 2.00 FISH P DECOMP MONITOR WELL STATIC. -RACK BACK DC'S. -LAY DOWN BHA AND SERVICE BOOT BASKET- NOTE: ALL BOOT BASKETS WERE FULL - RECOVERED 5 GAL OF RUBBER AND CONTROL LINE PCS -CLEAN CLEAR RIG FLOOR -1 QT DIESEL RELEASE FROM A CAMP GENERATOR AT 13:45 HRS. PROPER NOTIFICATIONS WERE MADE. - TRACTION #IR- 4016341 14:30 - 00:00 9.50 EVAL P DECOMP PJSM, RIG UP SWS E -LINE -RIH WITH USIT LOGGING TOOLS -LOG 9 -5/8" FROM 3500' TO SURFACE -TOP OF CEMENT = 2340' -LOG F /9000' MD TO 7000' -TOP OF CEMENT = 2340' -POOH AND RIG DOWN WIRELINE DISCUSS LOG AND CEMENT TOP WITH RWO ENGINEER Printed 1/16/2012 11:12:19AM O North America - ALASKA - BP Page 15 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11:10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/17/2011 00:00 - 04:00 4.00 DHB P DECOMP PJSM, M/U HALLIBURTON RBP -RIH TO 2410' -ON 4" DRILL PIPE FROM DERRICK. - PUWT =76K, SOWT =70K -SET RBP WITH CENTER OF ELEMENT AT 2410' AND TOP OF PLUG AT 2405' - CONFIRM SET WITH 25K SET ON PLUG AND 10K OVERPULL 04:00 - 05:30 1.50 FISH P DECOMP BLOW DOWN TOP DRIVE -POH TO TEST RBP -RACK 4" DRILL PIPE IN DERRICK. 05:30 - 06:00 0.50 DHB P DECOMP RIG UP TO TEST RBP 06:00 - 08:30 2.50 DHB P DECOMP BARRIER TEST, 9 5/8 RBP SET AT 2410' MD AGAINST BLIND /SHEAR RAMS -TEST FAILED DUE TO LEAKY 3" BULL PLUG ON TUBING SPOOL AND BLIND /SHEAR RAM LEAK t/ - FUNCTION BLIND /SHEAR RAMS AND TIGHTENED BULL PLUG - PRESSURE TEST 250 PSI LOW, 5 MIN, 4000 PSI HIGH, 30 MIN - CHARTED BOTH TESTS -LOST 40 PSI IN THE FIRST 15 MIN, AND 10 PSI IN THE SECOND 15 MIN -TWO TESTED BARRIERS ARE: 9 5/8" RBP AT 2410' MD. CEMENT / SALT ACROSS THE PERF. 08:30 - 09:00 0.50 FISH P DECOMP M/U MULE SHOE ON DP FROM DERRICK -RIH TO 2278' ON DP FROM DERRICK. 09:00 - 11:30 2.50 DHB P DECOMP DUMP 49, 50# SACK RIVER SAND DOWN THE / DRILL PIPE, SLOWLY. -LET FALL FOR 30 MIN. - MONITOR WELL STATIC F /10 MIN. 11:30 - 12:00 0.50 DHB P DECOMP PUMP 1 DRILL PIPE VOLUME AT 1 BPM / 40 PSI TO CLEAR DP. -25 BBLS. 12:00 - 14:00 2.00 DHB P DECOMP PJSM,POH FROM 2300' MD WITH MULE SHOE -RACK 4" DRILL PIPE IN DERRICK. -CLEAN AND CLEAR FLOOR. 14:00 - 15:30 1.50 FISH P DECOMP M/U 8 1/4" MULTI - STRING CUTTER - DRESSED TO CUT 9 5/8" CSG. -RIH WITH DRILL COLLARS FROM DERRICK - T/292' 15:30 - 16:30 1.00 FISH P DECOMP HELD D-1 DRILL WITH NONE SHEARABLE ACROSS THE BOP, CHALLENGED CREW WITH A FAILED FOSV FOLLOWED BY A FAILED ANNULAR, FOLLOWED BY A FAILED BLINDSHEAR RAM. AAR: WHILE AWAITING THE ANNOUNCEMENT OF THE DRILL, THE WSL AND TOOL PUSHER DID NOT HEAR THE DRILL CALLED OUT DUE TO A FAILED SPEAKER. THE SPEAKER WAS REPAIRED AND TESTED AS THE CREW RETURNED TO WORK Printed 1/16/2012 11:12:19AM North America - ALASKA - BP Page 16 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TN0 -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 18:30 2.00 FISH P DECOMP CONTINUE RIH FROM DERRICK WITH 9 5/8" CSG CUTTER -TAG TOP OF SAND AT 2340 - LOCATE COLLAR ABOVE CUT DEPTH PER BAKER REP AT 2298' -PUW = 77K, SOW = 77K 18:30 - 20:30 2.00 FISH P DECOMP RU CIRC MANIFOLD AND CELLAR CHOKE TO OPEN TOP TANK -RUN LRS -SPOT TRUCKS FOR ARCTIC PACK CIRC OUT 20:30 - 21:30 1.00 FISH P DECOMP PJSM - DISPLACE WELL TO 9.8 HEATED BRINE AT 5 BPM AT 480 PSI 21:30 - 22:30 1.00 FISH P DECOMP HEAT UP AND PRESSURE TEST SURFACE LINES -BLOW DOWN LINES 22:30 - 23:00 0.50 FISH P DECOMP PJSM FOR ARCTIC PACK CIRC OUT WITH RIG CREW, WSL, TP, LITTLE RED, CH2MHILL, MI AND BAKER HUGHES. 23:00 - 23:30 0.50 FISH P DECOMP OBTAIN PARAMETERS PRIOR TO CUT -SPR #1 MP 2.5 BPM @ 90 PSI, 3.4 BPM @ 170 PSI -SPR #2 MP 3 BPM @140 PSI, 4 BPM @ 270 PSI - ROTATIONAL WT = 90K, TQ = 2K, PUMP 7 BPM AT 1140 PSI -CUT 9 -5/8" CASING AT 2310' WITH 5 -10K / CUTTING TQ ✓ - CONFIRM CASING CUT WITH 20K OVERPULL AND TAG AT 3' ABOVE CUT DEPTH -DROP DART TO OPEN CIRC SUB -LAY DOWN SINGLE AND BLOW DOWN TOP DRIVE 23:30 - 00:00 0.50 FISH P DECOMP RU CIRCULATING HEAD WITH SAFETY VALVE 12/18/2011 00:00 - 01:30 1.50 FISH P DECOMP TEST LRS LINE TO 2500 PSI -PUMP 25 BBLS OF 90 DEG DIESEL AT 2 BPM, 100 PSI DOWN THE DRILL PIPE TAKING RETURNS TO THE PITS WITH LRS -SHUT DOWN PUMP, SI ANNULAR ELEMENT -START PUMPING DOWN THE DP TAKING RETURNS UP THE 9 -5/8 X 13 -3/8 ANNULUS TO AN OPEN TOP TANK - INITIALLY PRESSURED UP TO 2000 PSI WHICH HELD FOR 5 MIN - PRESSURE DECREASED TO 1140 PSI, BEGIN PUMPING WITH RETURNS TO TANK - CIRCULATE DIESEL AT AVERAGE PRESSURE OF 1400 PSI AND 1 BPM -FINAL CIRCULATING PRESSURE 400 PSI AT 1 BPM - ARCTIC PACK AND DIESEL IN INITIAL RETURNS, CLEANING UP TO DIESEL AFTER 75 TOTAL BBLS OF DIESEL PUMPED. 01:30 - 03:00 1.50 FISH P DECOMP CLOSE OA -BLOW DOWN HARDLINE -LET DIESEL SOAK IN 9 -5/8" X 13 -3/8" ANNULUS FOR 1 -1/2 HOURS -TABLE TOP STRIPPING PIPE DRILL WITH RIG CREW Printed 1/16/2012 11:12:19AM W orth America - ALASKA'- BP Page 17 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TN0 -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 05:00 2.00 FISH P DECOMP OPEN OA AND PUMP WITH LRS 25 ADDITIONAL BBLS OF DIESEL FOR 100 TOTAL BBLS PUMPED -SI LRS AND PUMP 40 BBL HI-VIS SWEEP WITH FLO -ZAN AND HEATED 9.8 BRINE AT 4.5 BPM AND 1740 PSI - -SMALL VOLUME OF GAS AND SEAWATER IN RETURNS -CHASE WITH 35 BBLS SAFE - SURF -0 - FOLLOW WITH 200 BBLS OF HEATED 9.8 BRINE AT 9 BPM AND 1760 PSI. -FINAL RETURNS CLEAN BRINE -SHUT DOWN PUMP AND OPEN ANNULAR PREVENTOR -PUMP SURFACE TO SURFACE VOLUME OF 9.8 BRINE TAKING RETURNS TO THE PITS AT 12 BPM AND 1430 PSI 05:00 - 05:30 0.50 FISH P DECOMP MONITOR WELL 10 MIN -BLOW DOWN SURFACE LINES 05:30 - 07:00 1.50 FISH P DECOMP POH WITH BAKER MULTI - STRING CASING CUTTER -STAND BACK COLLARS AND L/D CUTTER BHA -CLEAR RIG FLOOR 07:00 - 08:00 1.00 FISH P DECOMP M/U 9 5/8 SPEAR ASSY -RIH AND SPEAR 9 5/8 CASING AT HANGER - ENGAGE GRAPPLE 08:00 - 10:30 2.50 WHSUR P DECOMP BACK OUT LOCK DOWN SCREWS AS PER CAMERON -WORK AND PULL ON HANGER UP TO MAX OF 250K = NO MOVEMENT -PULL TO 225K AND HOLD -STEAM WELL HEAD FOR 25 MINUTES - HANGER POPPED FREE AND PULLED OUT OF CASING HEAD WITH 175K DRAG ; PULLED HANGER TO RIG FLOOR THROUGH BOP STACK WITH 145K UP WEIGHT - L/D SPEAR ASSY - L /D HANGER 10:30 - 12:00 1.50 PULL P DECOMP CIRC BOTTOMS UP - ATTEMPT TO WORK PIPE - ARCTIC PACK TOO THICK AT SURFACE - HANDLE ARCTIC PACK AT SURFACE 12:00 - 15:00 3.00 PULL P DECOMP CLEAN PITS, CUTTINGS BOX AND OPEN TOP TANK 15:00 - 15:30 0.50 PULL P DECOMP CIRC ARCTIC PACK OUT OF WELLBORE AT 8 BPM AND 570 PSI 15:30 - 00:00 8.50 PULL P DECOMP PJSM -RIG UP 9 -5/8 CASING TONGS -LAY DOWN 9 -5/8" CASING FROM 2310 TO SURFACE - AVERAGE BREAK -OUT TORQUE 50K - RECOVERED 56 JOINTS OF 9 -5/8 ", CUT JOINT 12.88' AND 10 CENTRALIZERS -NO STOP RINGS RECOVERED 12/19/2011 00:00 - 03:00 3.00 PULL P DECOMP CLEAN RIG FLOOR, WASH OUT PITS, FLOW LINE, SHAKERS, DRAG CHAIN, CUTTINGS BOX 03:00 - 03:30 0.50 FISH P DECOMP PU 9 -5/8" SPEAR ASSY FROM PIPE SHED -BREAK DOWN AND LD SPEAR ASSY Printed 1/16/2012 11:12:19AM Olorth America - ALASKA BP Page 18 of 27 Operation Su Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 04:30 1.00 FISH P DECOMP MU 9 -5/8 DRESS -OFF ASSY WITH 13 -3/8" CASING SCRAPER 04:30 - 06:00 1.50 FISH P DECOMP RIH 5 STANDS -CBU WITH 20 BBL SAFE - SURF -O PILL - ARCTIC PACK IN RETURNS - CONTINUE IN HOLE 06:00 - 07:00 1.00 FISH P DECOMP OBTAIN PARAMETERS UP WT. 87K DN WT.92K/6BPM 170 PSV3 FREE TQ AT 40 RMP /DRESS OFF 9 5/8" STUMP F/ 2311' TO 2312' WOB 2 -5K 40 RPM 3 -5 TQ/ 6 BPM 180 PSI 07:00 - 07:30 0.50 FISH P DECOMP CIRC. SAFE SURF SWEEP 13 BPM 760 PSI 07:30 - 09:30 2.00 FISH P DECOMP POOH F/ 2312' MD -LD DRESS OFF BHA 09:30 - 14:30 5.00 CASING P DECOMP RU TO RUN 9 5/8" CSG -R/U LONG BALES, STABBING BOARD -R/U COMPENSATOR AND TORQUE TURN EQUIP 14:30 - 21:30 7.00 CASING P DECOMP PJSM, RIH WITH 9 5/8 47# HYDRIL 563 TIE -BACK TO 2314' MD 21:30 - 22:30 1.00 CASING P DECOMP -RIG DOWN COMPENSATOR -M /U PUP JOINT - PUWT =130K, SOWT =140K -LOWER OVER STUMP AT 2311' MD - ENGAGE CASING PATCH AND SLIDE OVER TO 2314' MD -SET DOWN 40K, PULL TO 70K, STACK OUT AGAIN, THEN PULL TO 100K OVER 22:30 - 23:30 1.00 CASING P DECOMP R/U CEMENT HEAD - PRESSURE TEST RIG CEMENT LINE -TEST CASING TO 1000 PSI, 10 MIN CHARTED - INCREASE PRESSURE TO 1600 PSI TO INFLATE "ECP" PACKER, 1/4 BBL TO INFLATE - PRESSURE UP TO 2000 PSI,10 MIN CHARTED - PRESSURE UP AND SHEAR ES- CEMENTER AT 2800 PSI 23:30 - 00:00 0.50 CASING P DECOMP CIRCULATE AT 4BPM =130 PSI 12/20/2011 00:00 - 00:30 0.50 CASING P DECOMP DOYON 16 REACHES 10 YEARS WITHOUT AN ! GREAT JOB RIG 16 TEAM!!! PJSM WITH SLB, HES, CH2MHILL, MI AND RIG CREW FOR CEMENT JOB Printed 1/16/2012 11:12:19AM igg America - ALASKA - BP Page 19 Of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- OOTNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 ©47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 02:30 2.00 CASING P DECOMP FINISH CIRCULATING WELL TO CLEAN BRINE AT 4 BPM -PUMP 5 BBLS WITH CEMENTER'S PUMP -PUMP 153 BBLS OF 15.8 PPG CLASS G CEMENT AT 4.5 BPM AND AVERAGE TREATING PRESSURE 200 PSI -DROP ES- CEMENTER PLUG AND DISPLACE CEMENT WITH 9.8 PPG BRINE AT 6 BPM AND 300 PSI - CAUGHT CEMENT AT 73 BBLS OF BRINE ��/ 4- PUMPED, PRESSURE INCREASED TO 1050 l� PSI -AT 100 BBLS BRINE PUMPED, SHUT DOWN ,j/ it PUMP, SI ANNULAR ELEMENT AND OPEN OA $ VALVE TO TAKE RETURNS TO THE CUTTINGS BOX -SLOW PUMP RATE TO 1 BPM TO BUMP PLUG AT 02:15 -CLOSE ES- CEMENTER AT 1780 PSI, HOLD FOR 5 MIN -BLEED OFF PRESSURE, NO FLOW FOR 10 MIN -22 BBLS OF CEMENT TO SURFACE - CEMENT PROPERTIES: CEMENT -IN -PLACE = 02:15 HRS, 15.8 PPG CLASS G CEMENT, YIELD = 1.17 CUFT /SK 02:30 - 03:30 1.00 CASING P DECOMP FLUSH CEMENT FROM LINES AND BOPS -RD CEMENTING EQUIPMENT -CLEAN CUTTINGS BOX FROM CEMENT RETURNS 03:30 - 08:00 4.50 CASING P DECOMP PJSM -SPLIT BOP STACK AND CASING SPOOL TO SET SLIPS ON 9 5/8 CASING -SET 88K TENSION ON EMERGENCY SLIPS 08:00 - 12:00 4.00 CASING P DECOMP CUT LANDING JOINT AND LAY DOWN SAME -CUT JOINT = 7.17 FT (CUT WAS MADE OFF OF JOINT #54, 7.17') -SET BOP BACK - REMOVE TUBING SPOOL -MAKE DRESS OFF CUT WITH WACHS CUTTER 12:00 - 13:30 1.50 CASING P DECOMP INSTALL PRIMARY PACK OFF AND ENERGIZE - INSTALL NEW TUBING SI'UCSL AND TEST VOID TO 3800 PSI 13:30 - 15:30 2.00 BOPSUR P DECOMP PJSM AND N/U BOPE 15:30 - 16:00 0.50 BOPSUR P DECOMP FLUSH BOP STACK 16:00 - 17:00 1.00 BOPSUR P DECOMP REMOVE FLUID FROM STACK AND SET TEST PLUG 17:00 - 19:00 2.00 BOPSUR P DECOMP PJSM AND REMOVE 2 7/8" X 5" VRR RAMS FROM UPPER CAVITY AND INSTALL 7 5/8" RAMS 19:00 - 20:00 1.00 BOPSUR P DECOMP RU BOPE TEST EQUIPMENT Printed 1/16/2012 11:12:19AM orth America - ALASKA - BP Page 20 of 27 IMF 'Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 BOPSUR P DECOMP PJSM - TEST RAMS TO 250# / 4000# - ANNULAR TO 250# / 3500# - UPPER RAMS W/ 75/8" TEST JT - LOWER AND ANNULAR W/ 4" TEST JT - ALL PASSED - HAD TO BUMP UP ANNULAR ON LOW AND HIGH TO GET PASSING TEST BUT DID NOT CYCLE - AOGCC INSPECTOR, CHUCK SCHEVE HAD (7 WAIVED HIS RIGHT TO WITNESS - TEST CHARTS SCANNED INTO OPEN WELLS 12/21/2011 00:00 - 03:00 3.00 BOPSUR P DECOMP FINISH BOP TEST - UPPER PIPE RAMS CLOSED IN 6.3 SECONDS - BLINDS CLOSED IN 21 SECONDS - ANNULAR CLOSED IN 19 SECONDS - CONDUCT KOOMEY DRAW DOWN TEST - ALL PASSED 03:00 - 04:00 1.00 BOPSUR P ■- DECOMP BLOW DOWN - LAY DOWN TEST ST AND RD BOP TEST JOINTS AND RD BOP TEST EQUIPMENT - INSTALL 12.375 WEAR RING 04:00 - 06:00 2.00 CLEAN P DECOMP MU 9 -5/8" DRILL OUT BHA AND RIH TO 2,127' BHA AS FOLLOWS: - (1) 8 -1/2" MT BIT - (4) 7" JUNK BASKETS - PUMP OUT SUB - 6 -1/4" BUMPER SUB - 6-1/4" OIL JAR - (9) 6 -1/4" DC'S -4 "DP 06:00 - 07:00 1.00 CLEAN P DECOMP SLIP & CUT DRILL LINE 07:00 - 08:00 1.00 CLEAN P DECOMP RIH TO 2,222' JUST ABOVE THE TOP OF CEMENT - PUW -85K , SOW -90K - FREE TORQUE 3K AT 100 RPM WASH DOWN & TAG AT 2,229' , DRILL STRINGERS TO 2,247', 60 -80 RMP AT 6 BPM WITH 250 PSI. - TAGGED HARD CEMENT AT 2,247' , 21' ABOVE THE EZ CEMENTER AT 2,268' Printed 1/16/2012 11:12:19AM "AlliNotillAmerica - ALASKA - HP 10- Page 21 of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TN0 -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 ©47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 08:30 0.50 CLEAN P DECOMP WHILE WASHING DOWN TO TOC, THE H2S ALARM SOUNDED - THE WELL WAS IMMEDIATELY SHUT IN BY DRILLERS STANDING ORDERS FORA FAST SHUT IN. THE GAS PANEL WAS CHECKED TO SEE WHERE THE ALARM WAS COMING FROM AND HOW MUCH CONCENTRATION. THE ALARM WAS FROM ZONE 4, THE SHALE SHAKERS, THE CONCENTRATION WAS SHOWING ZERO. - THE RIG WAS EVACUATED, THE RIG CREWS AND ALL THIRD PARTY MUSTERED TO THE WSL OFFICE. HEAD COUNT WAS TAKEN. - LEVEL 0 NOTIFICATIONS WERE MADE BY THE WSL. DDI TOOL PUSHER NOTIFIED HIS MANAGEMENT. THE DRILLER AND LEAD FLOOR HAND WERE SENT IN TO THE RIG TO VERIFY THERE WAS NO H2S PRESENT. AS SOON AS THE RIG WAS CLEARED AND THE ALARM SILENCED CREWS WENT BACK TO WORK. TOTAL TIME OFF THE RIG WAS ABOUT 35 MIN - RIG ELECTRICIAN CHECKED THE CALIBRATION ON THE #4 SENSOR 08:30 - 12:00 3.50 CLEAN P DECOMP START DRILLING CEMENT F/ 2,247' TO 2,316' - 2 -3K WOB , 100 RPM , 6 -7 BPM WIT 260 -320 PSI. - PUMPED TWO 20 BBL HIGH VIS SWEEP DURING CEMENT & PLUG - SLIDE DOWN WITH NO PUMPS ON TO TOP OF SAND @ 2343' , DRY DRILL FOR 10 MIN TO 2345' - PU 5' AND PUMP 20 BBL SWEEP AND CBU AT 8 BPM WITH 465 PSI. MONITOR WELL 12:00 - 13:30 1.50 CLEAN P DECOMP PJSM - MONITOR WELL FOR 10 MIN , NO FLOW POOH F/ 2345' TO 325', STOP & MONITOR HOLE BEFORE PULLING BHA THROUGH THE STACK 13:30 - 15:00 1.50 CLEAN P DECOMP PJSM FOR BREAKING DOWN BHA. - CLEAN OUT BOOT BASKETS - PU AND MAKE UP REVERSE JUNK BASKET BHA FOR SAND CLEAN OUT. 15:00 - 18:00 3.00 CLEAN P DECOMP RIH WITH RCJB BHA - RIH TO —2336' , ESTABLISH SPR'S - MP #1: 30SPM = 50 PSI, 40 SPM = 190 PSI - MP #2: 30 SPM = 140PSI, 40 SPM = 240 PSI PUW= 86K, SOW 93K, ROT WT= 89K, FREE TQ =1 K DROP BALL - PU SINGLE, RIH TO 2347' , TOP OF SAND 18:00 - 18:30 0.50 CLEAN P DECOMP REVERSE CIRCULATE TO 2353' @ 5 BPM / 1570 PSI 18:30 - 19:00 0.50 CLEAN P DECOMP CIRCULATE BU @ 5BPM / 1570 PSI 19:00 - 19:30 0.50 CLEAN P DECOMP MONITOR WELL FOR 10 MINUTES - CLEAN FLOOR AND PREP FOR POOH Printed 1/16/2012 11:12:19AM P 22 rth.Aiierica - ALASKA = °B Page 2 f 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 20:30 1.00 CLEAN P ■- DECOMP AND POOH FROM TO 331' - MONITOR BEFORE PULLING PULLING BHA INTO STACK 20:30 - 22:00 1.50 CLEAN P DECOMP LD BHA AND EMPTY BOOT - BASKETS - RECOVER 5 PIECES OF BRASS, STRIPS OF METAL FROM ES CEMENTER, PIECE OF 9 5/8" CSG FROM CUT, LOTS OF METAL SHAVINGS AND CEMENT 22:00 - 00:00 2.00 ZONISO P DECOMP PJSM - RU AND TEST 9 5/8" CASING TO 4000 PSI FOR 30 CHARTED MINUTES - TOTAL BLEED OFF OF 40 PSI WITH PRESSURE STABILIZATION MEETING ALL CRITERIA (CHART ATTACHED) - RECEIVE AUTHORIZATION TO PROCEED FROM WTL 12/22/2011 00:00 - 00:30 0.50 ZONISO P ._ DECOMP BLEED OFF PRESSURE AND RD TEST EQUIPMENT 00:30 - 02:00 1.50 CLEAN P DECOMP MU BHA TO PULL RBP AND RIH - DRY TAG SAND @ 2358' - OBTAIN PARAMETERS: PU WT= 70K, SO WT = 76K - WASH DOWN TO RBP @ 2405' X 8 BPM / 310 PSI - CIRC HOLE CLEAN SAND AND CHUNKS OF RUBBER) 02:00 - 03:00 1.00 DHB P DECOMP LATCH RBP X WORK FREE - STACK 25K / 1/4 TURN RIGHT / PULL 25K, REPEAT STACK AND PULL SEQUENCE UP TO 65K, SO AND PUT ANOTHER 1/4 TURN RIGHT AND PULL 35K - PLUG RELEASED - WAIT FOR ELEMENTS TO RELAX AND WORK FREE 03:00 - 04:30 1.50 CLEAN P DECOMP FLOW CHECK WELL - STATIC - POOH W / RBP FROM 2405' - FLOW CHECK BEFORE PULLING RBP INTO STACK - STATIC - LAY DOWN RBP AND RETRIEVING TOOL 04:30 - 07:30 3.00 CLEAN P -_ DECOMP PJSM - MU DRILL OUT BHA# 16 - RIH TO 929' 07:30 - 08:00 0.50 CLEAN P -_ DECOMP RIG SERVICE - GREASE TOP DRIVE 08:00 - 11:00 3.00 CLEAN P DECOMP RIH WITH SCRAPER & MILL BHA, TO 8704 RICIPROCATE PAST PACKER SETTING DEPTH THREE TIMES. - RIH TO 8,988' OBTAIN PARAMETERS PUW -175K , SOW -155K , ROT WT- 160K , FREE TORQUE- 5.5 K FT /LB 10 BPM, 1750 PSI , - TAG JUNK 9,010' 11:00 - 13:30 2.50 CLEAN P DECOMP ROT DOWN TO 9040' WITH 60 RPM, 9.5 BPM , 1435 PSI , 5 -10 WOB. - OBTAIN SPR'S - MP #1: 30SPM = 110 PSI, 40 SPM = 190 PSI - MP #2: 30 SPM = 160PSI, 40 SPM = 280 PSI - DRILL OUT CMT FROM 9080' TO 9108' ,18' OF CMT PLUG AND —20 INTO THE SALT PLUG. LEAVING 155' OF SALT ON TOP OF THE UPPER MOST PERF. - SHUT DOWN PUMPS TO VERIFY WE WERE THRU THE CEMENT PLUG, CHECKED FOR FLOW, NO FLOW OBSERVED.PUMP 20 BBL HIGH VIS SWEEP, Printed 1/16/2012 11:12:19AM North America - ALASKA - BP Page 23 of 27 A ° Operation Summary, Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TN0 -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 15:30 2.00 CLEAN N DPRB DECOMP PUMPING THE HIGH VIS SWEEP AT 9,108' - SHOWED A FLOW INCREASE ON THE FLOW LINE - CIRCULATION WAS STOPPED AND THE WELL WAS FLOW CHECKED. - A TURBULENT FLOW WAS OBSERVED. 13:45 - THE WELL WAS SHUT IN USING THE DRILLERS ORDERS FOR FAST SHUT IN. - SIDP -40 , SICP -30 , CALCULATED PIT GAIN WAS 5 BBLS. MADE NOTIFICATION TO THE RWO SUPT, WHO CONFERRED WITH RWO TL AND ENGINEER. WAS AGREED BY ALL THAT WE WERE MOST LIKELY DEALING WITH SOME TRAPPED PRESSURE UNDER THE CMT PLUG. DECISION WAS MADE TO CIRCULATE A SURFACE TO SURFACE. 15:30 - 17:30 2.00 CLEAN N DPRB DECOMP CIRCULATED SURF /SURF VOLUME 600 BBLS THROUGH THE CHOKE AND GAS BUSTER. - CIRCULATED 4 -5 -1/2 BPM , @ 340 -550 PSI. - ZERO GAS DETECTED AT SURFACE. 17:30 - 20:00 2.50 CLEAN N DPRB DECOMP MONITOR THE WELL, BLOW DOWN THE GAS BUSTER - SICP - 0 , SIDPP SHOWING 20 PSI, DUE TO HYDROSTATIC FROM THE STAND PIPE. - SHUT IN THE IBOP & BLED THE STAND PIPE, OPENED UP THE IBOP BACK TO THE CHOKE AND THE SIDP READ 0. CALLED RWO SUPT TO INFORM HIM OF THE WELL STATUS. - HE MADE THE CALL TO THE RWO WTL FOR AUTHORIZATION TO OPEN THE WELL BACK UP. - WELL CONFIRMED TO BE STATIC W/ RWO SUP'T - GIVEN ATP BY WTL 20:00 - 21:30 1.50 CLEAN P DECOMP POOH STANDING BACK DP FROM 9108' - PULLED TIGHT @8968' - PU TOP DRIVE AND WORK PIPE - W/ 20 RPM - PIPE FREE - CONTINUE POOH TO 8514' (JUST ABOVE 7" LINER TOP) - MONITOR WELL FOR 30 MINUTES 21:30 - 00:00 2.50 CLEAN P DECOMP PJSM - PUMP 20 BBL SWEEP FOLLOWED BY CLEAN 9.8PPG BRINE TO DISPLACE WELLBORE @ 8 BPM / 1120 PSI 12/23/2011 00:00 - 01:00 1.00 CLEAN P DECOMP FINISH DISPACING WELL TO CLEAN 9.8 PPG BRINE - SERVICE RIG 01:00 - 06:00 5.00 CLEAN P DECOMP POOH WITH 9 -5/8" SCRAPER & MILL BHA AND - LAY DOWN DP FROM 8514' TO 929' TO THE PIPE SHED 06:00 - 10:30 4.50 CLEAN P DECOMP MONITOR WELL FOR 10 MIN PRIOR TO PULLING BHA THRU THE STACK - CONTINUE LAY DOWN DP TO BHA. 10:30 - 12:00 1.50 CLEAN P DECOMP BREAK AND LAY DOWN BAKER BHA# 16 - BOOT BASKETS CONTAINED — 3.5 GAL OF GROUND UP CONTROL LINE TUBING - CREW PUT THE COMPLETION JEWLRY IN THE PIPE SHED 12:00 - 13:30 1.50 CLEAN P DECOMP CONT. TO L/D BHA, PER BAKER REP DIRECTION Printed 1/16/2012 11:12:19AM 4110 „ North Attierica - ALASKA = BP Page 24 of 27 Operation Summary Report .. Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- OOTNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 ©47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 14:30 1.00 CLEAN P DECOMP CLEAN BOOT - BASKETS / CLEAR BHA OFF RIG FLOOR. - PEP RIG FOR BOB TESTING 14:30 - 17:00 2.50 CLEAN P DECOMP PJSM, R/U TO TEST ANNULAR TO 3500 PSI. AND TEST IBOP TO 4000 PSI. FOR 5 MIN. - TESTED ANNULAR WITH 4" TEST JOINT - R/D TEST EQUIP. AOGCC REP BOB NOBLE WAIVED WITNESS AT 0830 12/23/2011 - BOPE USAGE FOR WAS SENT IN BY THE RWO SUPT. 17:00 - 20:00 3.00 RUNCOM P RUNCMP PJSM, R/U TO RUN 7" X 9 5/8" HES TNT PKR W/ 7" 26# TAILPIPE - RU CASING RUNNING EQUIPMENT - CLEANING PITS. 20:00 - 22:30 2.50 RUNCOM P RUNCMP RUN PACKER AND TAILPIPE ASSEMBLY TO 7" X 7 5/8" XO, USING TORQUE TURN EQUIPMENT TO MAKE UP CONNECTIONS. COULD NOT GET THE POWER TONGS TO BITE ON THE XO. CALL FOR DIFFERENT DIES FOR THE TONGS 22:30 - 00:00 1.50 RUNCOM N WAIT RUNCMP WAIT ON DIES FOR POWER TONGS 12/24/2011 00:00 - 01:30 1.50 RUNCOM N WAIT RUNCMP WAIT ON DIES FOR POWER TONGS - NEW DIES ARRIVE AND INSTALL 01:30 - 06:00 4.50 RUNCOM P RUNCMP TORQUE UP 7 5/8" x 7 " XO - CHANGE OUT RUNNING TOOLS AND SAFETY VALVE TO 7 5/8" EQUIPMENT - RUN IN HOLE W/ 7 5/8" 29# VAM TOP HC TUBING USING TORQUE TURN TO 14,450 FT /LBS. - BAKER LOC ALL CONNECTIONS BELOW THE PACKER 06:00 - 18:00 12.00 RUNCOM P RUNCMP RUN IN HOLE W/ 7 5/8" 29# VAM TOP HC TUBING USING TORQUE TURN TO 14,450 FT /LBS. - USING TORQUE TURN SERVICES - TRIP DISPLACEMENT HAS BEEN CORRECT 18:00 - 20:30 2.50 RUNCOM P RUNCMP RUN IN HOLE W/ 7 5/8" COMPLETION AND TAG TOP OF 7" LINER @ 8503' X TALLY - SET DOWN 10K - PU AND TAG AGAIN W/ 5K TO CONFIRM 20:30 - 21:30 1.00 RUNCOM P RUNCMP SPACE OUT TUBING W/ 14.88' PUP JT TO LAND 5' ABOVE TOP OF LINER 21:30 - 22:30 1.00 RUNCOM P RUNCMP R/D COMPENSATOR - C/O ELEVATORS - MU HANGER X LANDING JT - PUW =254K, SOW = 211K- LAND HANGER W /EOP @8498'X TALLY 22:30 - 23:00 0.50 RUNCOM P RUNCMP CAMERON REP RILDS ON TUBING HANGER 23:00 - 00:00 1.00 RUNCOM P RUNCMP UD LANDING JT X RIG UP CELLAR TO CIRCULATE 12/25/2011 00:00 - 01:30 1.50 RUNCOM P RUNCMP R/U CELLAR TO CIRCULATE - SUCK OUT BOP STACK- --- CREW WAS BLOWING DOWN LINES WITH AIR AFTER SUCKING OUT STACK WHEN 3" LP HOSE BROKE - 1/2 - 1 GALLON OF RESIDUAL BRINE WAS RELEASED ONTO CELLAR WALLS AND RIG MAT - CLEANED UP WITH ADSORB - NOTIFIED PAD OPERATOR AND ENVIRONMENTAL @ 5700 - TRACTION REPORT # 4022632 Printed 1/16/2012 11:12:19AM North America = ALASKA = BP " Page 25 of 27 Operation' Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 ©47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 05:30 4.00 RUNCOM P RUNCMP PJSM W CH2 - REV CIRC 390 BBLS OF 9.8# BRINE & 145 BBLS OF 9.8# BRINE W/ CORROSION INHIBITOR @ 3.5 BPM X 550PS1 - PUMP 5 BBLS BRINE DOWN TUBING TO FLUSH ROD X BALL LANDING PROFILE 05:30 - 06:00 0.50 RUNCOM P RUNCMP LRS PUMP 20 BBLS DIESEL DOWN IA @ 1.5 BPM W/ 300 PSI 06:00 - 07:30 1.50 RUNCOM P RUNCMP LET DIESEL U -TUBE, TBG BY IA. 07:30 - 08:00 0.50 RUNCOM P RUNCMP P/U LANDING JNT/ DROP BALL & ROD -L/D LANDING JNT 08:00 - 08:30 0.50 RUNCOM P RUNCMP ATTEMPT TO SET BALL & ROD -PUMP 23 BBLS DOWN TBG © 3.5 BPM W/ 700 PSI -NO INDICATION BALL IS ON SEAT. 08:30 - 09:00 0.50 RUNCOM P RUNCMP PUMP 10 BBLS DIESEL DOWN IA -PUMP 23 BBLS DOWN TBG @ 3.5 BPM W/ 700 PSI -NO INDICATION BALL IS ON SEAT. 09:00 - 09:30 0.50 RUNCOM P RUNCMP SUCK OUT BOP STACK - VERIFY BALL & ROD NOT IN HANGER PROFILE 09:30 - 10:00 0.50 RUNCOM P RUNCMP PUMP 18 BBLS DOWN TBG @ 3 BPM W/ 400 PSI 10:00 - 11:30 1.50 RUNCOM N DFAL RUNCMP DISCUS OPTIONS WITH ADW WTL ON PLAN FORWARD. -WAIT ON WIRE LINE UNIT -B /D CIRC. LINES IN CELLAR. 11:30 - 13:00 1.50 RUNCOM N DFAL RUNCMP PUMP 7.5 BBLS DIESEL DOWN IA @ 3 BPM W/ 300 PSI -LET U -TUBE -SI WELL. -BLOW DOWN LINES - R/D LRS - REMOVE LINKS AND 4" DP ELEVATORS FROM TOP DRIVE UNIT. RIG ELECTRICIAN PERFORM MEGGING TOP DRIVE MOTORS INSPECTION. 13:00 - 17:00 4.00 RUNCOM N DFAL RUNCMP DAY WSL CHANGE OUT FROM TOWN. - REPLACE LINKS AND 4" DP ELEVATORS ON TOP DRIVE UNIT. - PJSM WITH SLICK LINE UNIT. 17:00 - 18:00 1.00 RUNCOM N DFAL RUNCMP RIH ON SLICK LINE W/ 5 1/2 BELL GUIDE AND BLIND BOX TO 8365' - POOH 18:00 - 19:00 1.00 RUNCOM N DFAL RUNCMP RIH ON SLICK LINE AND ATTEMPT TO SEAT BALL AND ROD - FAILED TO SEAL OFF - POOH 19:00 - 21:00 2.00 RUNCOM N DFAL RUNCMP RIH ON SLICK LINE TO FISH BALL AND ROD - ENGAGE FISH AND POOH F/ 8365' 21:00 - 22:00 1.00 RUNCOM N DFAL RUNCMP RIH TO FISH RHCM PLUG - ENGAGE AND POOH F/ 8365' 22:00 - 00:00 2.00 RUNCOM N DFAL RUNCMP RIH AND ATTEMPT TO SET PRN 12/26/2011 00:00 - 00:30 0.50 DHB N DFAL OTHCMP POOH, W/ PRN RUNNING TOOL 00:30 - 01:30 1.00 DHB N DFAL OTHCMP RIH W/ GS PULLING TOOL AND LATCH PRN 01:30 - 02:00 0.50 DHB N DFAL OTHCMP POOH W/ PRN PLUG BODY - 02:00 - 02:30 0.50 DHB N DFAL OTHCMP SWS RE -DRESS PRN BODY Printed 1/16/2012 11:12:19AM S .4 orth America - ALASKA' = BP Page 26 of 27 'Operation. Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 03:00 0.50 DHB N DFAL OTHCMP RIH W/ PRN 03:00 - 04:30 1.50 DHB N DFAL OTHCMP ATTEMPT TO INSTALL PLUG - DID NOT IMMEDIATELY SEAT - WORK PLUG - FINALLY SET PRN @ 8372' WLM 04:30 - 05:00 0.50 DHB N DFAL OTHCMP POOH W/ PRN RUNNING TOOL 05:00 - 06:00 1.00 DHB N DFAL OTHCMP RIH W / PRONG AND SET IN PRN PLUG TO ESTABLISH BARRIER IN TUBING 06:00 - 06:30 • S DHB N DFAL OTHCMP POH W /PRONG RUNNING TOOL ON SLICK LINE F/ 8372'. 06:30 - 09:00 2.50 RUNCOM P RUNCMP PJSM SET AND TEST PACKER. - PRESSURE TEST 250 PSI LOW F/ 5 CHARTED MIN. DOWN THE TBG. PASSED. - PRESSURE TEST TBG TO 4000 PSI F/ 30 CHARTED MIN. PASSED ✓ -BLEED TBG TO 1500 PSI AND SI. - PRESSURE TEST IA T/250 PSI LOW FOR 5 CHARTED MIN. PASSED. - PRESSURE TEST IA T /4000 PSI FOR 30 CHARTED MIN. PASSED. - NOTIFY ADW WTL OF TEST RESULTS, OK TO PROCEED. 09:00 - 09:30 0.50 RUNCOM P RUNCMP PSJM R/D SLICK LINE FROM RIG FLOOR. -CLEAR FLOOR. 09:30 - 10:30 1.00 RUNCOM P RUNCMP N/U DUTCH SYSTEM -PJSM P/U DSM LUBRICATOR. -M /U TWC AND DSM LUBRICATOR. 10:30 - 11:00 0.50 RUNCOM P RUNCMP TEST DSM LUBRICATOR T/ 250 PSI LOW AND 3500 PSI FOR 5 CHARTED MIN. PASSED. 11:00 - 12:00 1.00 WHSUR P WHDTRE DSM SET TWC IN PROFILE OF NEW TUBING SPOOL 12:00 - 12:30 0.50 WHSUR P WHDTRE RIG DOWN DSM LUBRICATOR AND DUTCH RISER 12:30 - 13:30 1.00 WHSUR P WHDTRE RIG UP AND ATTEMPT TO TEST TWC FROM ABOVE - FAILED TO PRESSURE UP 13:30 - 14:30 1.00 WHSUR P WHDTRE BREAK DOWN SURFACE LINES - ISOLATE SURFACE VALVES AND TEST GOOD 14:30 - 15:00 0.50 WHSUR P WHDTRE RE -TEST TWC - FAILED TO PRESSURE UP AGAIN 15:00 - 17:00 2.00 WHSUR P WHDTRE RIG UP DSM LUBRICATOR & DUTCH RISER - TULL TWC 17:00 - 18:00 1.00 WHSUR P WHDTRE DSM ATTEMPT TO SETA NEW TWC - UNABLE TO GET 8 TURNS TO ENGAGE DOGS 18:00 - 19:00 1.00 WHSUR P WHDTRE PULL TWC TO SURFACE AND TEST - FUNCTIONED PROPERLY OUT OF HOLE - DISCUSS OPTIONS WITH TOWN 19:00 - 20:00 1.00 WHSUR P WHDTRE RIG DOWN DSM LUBRICATOR & DUTCH RISER - SUCK STACK DOWN TO BELOW PROFILE - RIG UP AIR LINE W/ 25' OF 1/2" PIPE AND LOWER INTO STACK - FLUSH PROFILE WITH AIR 20:00 - 20:30 0.50 WHSUR P WHDTRE RIG UP DUTCH RISER AND DSM LUBRICATOR - DSM SET TWC WITH NO PROBLEMS 20:30 - 21:00 0.50 WHSUR P WHDTRE FILL TACK W/ DIESEL 21:00 - 22:00 1.00 WHSUR P WHDTRE CL E BLINDS AND TEST TWC FROM ABOVE - 0# / 4000# FOR 5 MINUTES EACH ON HART - PASSED Printed 1/16/2012 11:12:19AM crth America - ALASKA = BP Pager of 27 Operation Summary Report Common Well Name: NGI -10 AFE No Event Type: WORKOVER (WO) Start Date: 12/3/2011 End Date: X4- 00TNO -E: (3,931,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 12/27/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 11 : 10 10/26/1976 00:00 @47.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:00 1.00 WHSUR P WHDTRE RIG DOWN DSM LUBRICATOR AND DUTCH RISER - BLOW DOWN LINES AND DRAIN STACK 23:00 - 00:00 1.00 WHSUR P WHDTRE PJSM - REMOVE BELL NIPPLE TO CONDUCT A VISUAL INSPECTION OF THE ANNULAR PREVENTER 12/27/2011 00:00 - 05:00 5.00 WHSUR P WHDTRE REMOVE BELL NIPPLE AND CONDUCT INSPECTION OF ANNULAR ELEMENT BY DDI TOOL PUSHER AND BP WSL - SOME SLIGHT DAMAGE TO UPPER FINGERS BUT SEALING SURFACE IN VERY GOOD CONDITION - OK TO REMAIN IN SERVICE - REMOVE 7 5/8" RAMS & 3 1/2" X 6" VBR'S AND INSPECT RAM CAVITIES 05:00 - 06:30 1.50 BOPSUR P WHDTRE N/D BOPE - DISCONNECT KOOMEY LINES FOR TIRE CHANGE. 06:30 - 08:00 1.50 WHSUR P WHDTRE CLEAN TBG HANGER TOP -N /U 13 5/8" X 7 1/16" 5M ADAPTOR FLANGE. 08:00 - 09:00 1.00 WHSUR P WHDTRE CAMERON REP - PRESSURE TEST HANGER VOID TO 5000 PSI FOR 30 CHARTED MIN.GOOD. 09:00 - 10:30 1.50 WHSUR P WHDTRE N/U 7 1/16" 5M TREE -PAD SIDE WING VALVE WAS REMOVED AND BLIND FLANGE INSTALLED, DUE TO INTERFERING WITH BOP STACK. 10:30 - 12:00 1.50 WHSUR P WHDTRE 7 1/16" TREE TEST. - TESTED 250 PSI LOW, 5000 PSI FOR 5 CHARTED MIN. GOOD. - SECURE WELL. -CLEAN AND CLEAR CELLAR - REMOVE DSM VALVES FROM CELLAR. RIG RELEASED FOR MOVE TO MPL -03 Printed 1/16/2012 11:12:18AM • • NGI -10, Well History (Post Rig Workover) Date Summary 01/15/12 Rig up. Pressure and function test BOPE, 300 / 4000 psi. RIH w/ 2.59" DJN BHA with: CTC 2 x 0.1', Checks 2 x 1.1', stinger 2 x 3.5', stinger 2 x 4.0', XO 2 x 0.33', DJN 2.59 x .7'. BHA OAL = 9.7'. 01/16/12 RIH w/ M/U 2.59" DJN BHA with: CTC 2 x 0.1', Checks 2 x 1.1', stinger 2 x 3.5' , stinger 2 x 4.0', XO 2 x 0.33', DJN 2.59 x .7'. BHA OAL = 9.7'. Tag salt top @ 9119' and corr depth to 9108'. After opening top perfs, experienced gradual losses and at 9335' losses = 100 %. Stopped RIH and Freeze protect surface lines and CTBS. Continued jetting salt plug down to 9490'. Crew change and PJSM. Jet salt plug clean down to 9831', 7' below bottom perf. Wash perf interval up /down 3 times at 2 bpm, 1050 WHP. Bullhead injectivity test at 5.4 bpm, 1480 WHP, down backside and coil. RIH to 9831'. POH while bullheading. Frz protect surface lines. Lay out BHA. Job complete. WOW to finish RD of CTU. Freeze protect well to 2500' with 115 bbl diesel and 5 bbl 60/40 meth cap. 01/19/12 WELL S/I ON ARRIVAL. RIG UP TO SET 7" (6.00" db lock) CA. Al ISSSV @ 2,182' MD. 01/20/12 TAG 6.00" CA. DB -6 NIPPLE W/ 6.16" G -RING @ 2,166' SLM / 2,182' MD. SET 7" CA. Al ISSSV (6.00" db lock, s/n = BWS -138, 3.50" bean, oal = 48.5 ") @ 2,182' MD. PERFORMED SUCCESSFUL CLOSURE TEST. WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. Page 1 of 1 TREE = 6-3/8 CAN WELLHEAd = GRAY • SAFETY.: WELL REQUIRES A SSSV ACTUATOR = BAKER C NGI-10 -CHROME NIPPLES*** i Oka, KB. ELEV = 47' ORIG. BF. ELEV =- i . . . ... KOP = 3405' • . t 2182' --17" SLB DB-6 NIP (9-CR), ID = 6.00' 1 Max Angle = 45. @ 9661, 20" CONDUCTOR, H 106 ■ , 0 • f • Datum MD = 10379 94#, H-40. •,. t 2268 H 9-5/8" FES ES CENENTER 1 1 Of ? Datum TVD = 8800' SS ID = 19.124" 0 2289' H9-5/8" BKR ECP PKR, ID = 8.670" I . i . 9-5/8" CSG, 47#, L-80 HY D 563,10 = 8.681" H 2314' ■,4 A .. 4 i 9-518 BOWEN CSG PATCH H 2314' F . 2361' H 9-5/8" FO CEMENTER 9-5/8" CSG, 47#, S0095 XO TO MN-80 BUTT H 2340' 2487' H 9-5/8" FO CEMENTER 13-3/6 CSG, 72#, MN-80 BUTT, ID = 12.347" H 2811' • Minimum ID =6.600" @ 8355' ,7" HES RN NIPPLE 7-5/8" TBG, 29.7#, L-80 VAM TOP HC (IPC), -L 8230' 1 \ i — I 8230' —17-518 X7" XO, ID = 6.276" .0459 bpf, ID = 6.875" I I I 8247' H7"HES R NIP (9-C HD = 5.963" x x L 8320' H9-5/8" X 7" HES TNT PKR, ID = 5.900" I I 1 I 8356' 1 HES RN NIP (9-CR), ID = 5.500" I 7" TBG, 26#, L-80 TCII, .0383 bpf , ID = 6.276" I--I 8498' / . 8498' —17' WLEG, ID = 6.276" —I ELMD TT NOT LOGGED I TOP OF 7" LNR I 8523' I . il 9-5/8" CSG, 47#, N-80, ID = 8.681" I--I 8815' ■ PERFORATION SUMMARY REF LOG: BHCS ON 11/14/1976 ANGLE AT TOP PERF: 38° i.) 9265' I Note: Refer to Production DB for historical perf data I SIZE SF F INTERVAL Opn/Sqz DATE 2-7/8" 4 9265 - 9293 0 06/11/77 3-3/8 4 9300 - 9448 0 07/04/90 I 3-3/8" 4 9452 - 9492 0 07/04/90 I 3-3/8" 4 9515 - 9540 0 06/11/77 3-3/8' 4 9564 - 9589 0 06/11/77 I ! ; 3-3/8 4 9610 - 9644 0 06/11/77 I 3-3/8" 4 9676 - 9696 0 06/11/77 3-3/8" 4 9713 - 9748 0 06/11/77 3-3/8" 4 9799 - 9824 0 06/11/77 I , 9831' HTOP OF SALT PLUG (01/16/12) 7" LNR, 29#, N-80 BUTT, .0371 bpf, ID = 6.184" I 9986' 1 1111411M •••••••• • At.A.A.AV T O 9990' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ;• 11/23/76 Chalg R51 ORIGINAL COMPLETION 01/05/12 SM/JMD DRLG DRAFT CORRECTIONS WELL: NGI-10 03/22183 NIES RWO 01/06/12 PJC 13-3/8" CSG CORRECTION PERMIT No: r 1760690 12/27/11 D16 RWO 01/10/12 GJB/ PJC FULL PRN PLUG (01/08/12) API No: 50-029-20229-00 07/19/01 RNITP CORRECTIONS 01/19/12 RRW/JMC RENIVD SALT PLUG (01/16/12) SEC 1, T11N, R14E, 137' FSL & 916' FWL ::. 11/12/11 DMS/ PJC SALT PILL (11/03/11) 01/05/12 SIVVJMD PRN PLUG (12/26/11) BP Exploration (Alaska) ■ I prls 17, ovio Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, January 23, 2012 11:21 AM 17- t v To: 'AK, D &C Well Integrity Coordinator' Cc: Brooks, Phoebe L (DOA) Subject: RE: OPERABLE: Gas Injector NGI -10 (PTD #1760690) Resume Gas Injection Post Rig Workover Thanks, but what I really need is report that can be imported into our database; just like you submit for post injection MIT. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeIIIntegrityCoordinator Cabp.com] Sent: Monday, January 23, 2012 11:03 AM To: Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: RE: OPERABLE: Gas Injector NGI -10 (PTD #1760690) Resume Gas Injection Post Rig Workover Jim, The test was performed by the rig after setting the packer. I am enclosing the daily operations report from the rig and a copy of the chart that was performed on the MIT -T and MIT -IA affr"ffe lac er was set on 12/26/2011. If you feel this is insufficent, please let me know and I can reschedule another MIT -IA prior to the well beginning injection. The well is still currently shut -in. Jerry Murphy BPXA Well Integrity Coordinator F- U1L StaktiNED From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, January 23, 2012 9:43 AM To: AK, D &C Well Integrity Coordinator Subject: RE: OPERABLE: Gas Injector NGI -10 (PTD #1760690) Resume Gas Injection Post Rig Workover Send MIT test report Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIIntegrityCoordinator Cabp.com] Sent: Saturday, January 21, 2012 9:37 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops 1 Lead; AK, OPS FS1 DS5 Operator; AK, OPS• EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; G GPB FS1 DS; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Chiwis, Robert Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; LeBaron, Michael 3 Subject: OPERABLE: Gas Injector NGI -10 (PTD #1760690) Resume Gas Injection Post Rig Workover All, Gas injector NGI -10 (PTD #1760690), which has operated under AA 4E.006 for IAxOA communication, has completed a rig workover and passed an MIT -IA to 4000 psi on 12/26/11. The rig workover was performed to repair TxIA communication through the SSSV and to repair IAxOA communication by cementing the OA to surface. The passing MIT - IA confirms the existence of two competent barriers in the wellbore. This well is reclassified as Operable. Once the well is thermally stable, an AOGCC witnessed MIT -IA will be required. The plan forward for this well is: 1. WOE: Put well on injection 2. Fulibore: AOGCC MIT -IA to 2000 psi when thermally stable 3. DHD: Monitor wellhead pressure for 10 -14 days to evaluate IAxOA communication 4. WIC: Evaluate for cancellation of AA for IAxOA communication Please be aware of the potential for annular fluid expansion. A wellbore schematic and a copy of the AA have been included for reference. «Gas Injector NGI -10 (PTD #1760690) wellbore schematic.ZIP» «NGI -10 AA Approval 4E.006 05- 31- 06.ZIP» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2 0 • R3C( MCJ--1(9 ( u ' I , - 176o6 15 M. Isel....1.1.00°..., -----w■rat-7:11 „77'-:-''.--- !•100, ....-. 4 . 1 W •00■1110/..;,,,,,,Inerr 4141■1%41tww iiirog._. 4 ONEtrimirepT: 1,074fti , 11111P11 ilwilor illiiiite U41411.74741110, 0.0.0.1 it; 01111 oligitial l i i m lar ammiliftwil liari / ;00 oisuoiwinrAmm, 0 ##. .74% `. orifitio •••••• 1110110Miliftir, 11W.I. ' ' S li tils o. % 4 00 10 ; 101 _MASslia=rium4r. 0 7 1 114p 44:i \ $.41r 01111111.0011MINIiiinavitifr,itil, 44 . 4 41T ... .e . ' \ # Pgratailimilliii.PIP At1141 # 0011101•WiAmirrip O lilorirjai.141IWPIP \ ul.° ...„ 1 A \ I 6, 0 1110111111.1.1111,41, 001110. 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I WON / / \. \ "* 4 * *4• 414, ' 41m.._44114.19011".. jar411.1.11101.1. -4- 4- -4.._11.1441111, 111./..4=011 10.000011 . ,..44t:/ iMINTAIn==i1Wil II 0.0.00 4.414 44 ■Nr 00 .0 0 , ■14°■90 ' 0 41 ■ 1las i i ".., -. ftor*I■4rr Milral......W.0.0 / , A 4 ■ ftio..4,41 0, Atara . ftup. ... 0 ,.. ast■imag'ir - , . oc, — - 3t mC3 -to 9 • t? 6 66 icy . .: . k .. .: .. . t:: .. .. . .... 4 Nort . , .. . . .�.; Daily Operations'Repait (WORKOVER) Operator: BP Eve nt Type: Report: 12/26/2011 WORKOVER 24 Well/Wellbore No.: NGI - 10 /OH Event Objective'. 12/2 Well Type: DEVELOPMENT Site: NGI Job Number: Acct Proj No: X4- 00TNO -E: Contractor: DOYON DRILLING INC. Rig: DOYON 16 �P., = :.::'';,,,:,#,..; Current a . .1' v r - ski Well Sttus ,r..; , Depth MD: Ground Elevation: 0.00 (ft) AFE No.: X4- OOTNO -E: Rig Accept: 9:03:OOPM 12/5/2011 Est TVD: Casing(MD): AFE Cost: 3,931,000.00 Rig Release: PBTD: Cost in: US Dollar Spud Date: Elev Ref: 11 : 10 10/26/1976 00:00 ©47.00ft (above Mean Sea Daily Well: 603,930.00 WX Date: 11/30/2011 Level) DOUDFS/Target: Cum. Well: 3,226,877.49 Geologist: Est Days: 15.00 days Total Personnel: 39 Engineer: MCLAUGHLIN Rig. Days: 21.92 Day WSL: KNOWLES/ RHODES Night WSL: MILLER Weather: -20 F, WIND 6 MPH, WIND CHILL -35 F Current Status: REMOVE BELL NIPPLE TO INSPECT ANNULAR ELEMENT 24 Hr Summary: SET PLUG AND PRONG IN RN NIPPLE BELOW PACKER - TEST TUBING AND IA TO 250# / 4000# - PASSED - SEVERAL ATTEMPTS TO SET TWC FAILED BEFORE DRAINING STACK AND FLUSHING PROFILE WITH AIR - SET TYPE "J" TWC - CLOSE BLINDS - TEST FROM ABOVE 250 / 4000 - PASSED 24 Hr Forecast: INSPECT ANNULAR ELEMENT - PULL RAMS FOR MILNE PT CONVERSION - REMOVE BOP X INSTALL TREE - TEST HANGER SEALS AND TREE - LAY DERRICK OVER - PULL OFF WELL AND CHANGE TIRE Update at 06:00: REMOVING RAMS AND INSPECTING BOPE Comments: HSE RIGHT DAY Cost and AFE Summary by AFE - Event Type AGSP Planned Cum Cost Grouped AFE Cost Estimate( Cum Cost Grouped Event Cost WORKOVER X4- 00TNO -E: 3,931,000.00 3,931,000.00 3,226,877.50 3,226,877.50 Totals 3,931,000.00 3,931,000.00 3,226,877.50 3,226,877.50 - .. , . HSE and Well Control. - ..L: Days Since Last DAFWC: 5,182 All Free Days: Incident Details: Last Csg Test Press: 4,000.00 (psi) Number of Dropped Objects: Last H2S Drill: 12/21/2011 Last BOP Pressure Test: 12/21/2011 Last Abandonment Drill: 12/21/2011 Last Trip Drill (D1): 12/18/2011 Next BOP Press Test: 12/28/2011 Last Accum Drill (D4): 11/11/2011 Last Safety Meeting: 12/18/2011 Last Diverter Drill (D3): Last Spill Drill: 12/12/2011 Last Environmental Inciden 12/25/2011 Stop Cards: Regulatory Agency Insp: No Non - compliance Issued: No Kick Tolerance: Kick Volume: No. Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate I Pressure (psi) Stroke Rate I Pressure (psi) Stroke Rate I Pressure (psi) No Pump Operations with Slow Pump Rates - F; ,.. , Perforrrance Measures _. Stop Cards SOC JSEA/TOFS First Aid Near Miss Today Total 133 44 142 Drilling Fluid . Type: WATER/BRINE Funnel Visc: Lost Downhole: Depth: 47.00 (ft) PV: Lost Surface: FL Temp.: (°F) YP: Density: 9.80 (ppg) . , pe Summa - `" � " From - To Hrs Phase Task Activity Code NPT Operation Op. Depth (ft) (hr) 00:00 - 00:30 0.50 OTHCMP DHB PLUG C POOH, W/ PRN RUNNING TOOL 12/27/2011 5:43:58AM f' t 106:1, -10 • `wo� r c North America - ALASKA -. BP . . .. .. .: ark ,. ' - Daily Operations Report (WORKOVER).. Operator: BP Event Type: WORKOVER Report: 24 Well/Wellbore No.: NGI -10 /OH Event Objective: Date: 12/26/2011 Well Type: DEVELOPMENT Site: NGI Job Number: Acct Proj No: X4- 00TNO -E: Contractor: DOYON DRILLING INC. , Rig: DOYON 16 ''' Operations Summary - - .. ', From - To Hrs Phase Task Activity Code NPT Operation Op. Depth (ft) (hr) 00:30 - 01:30 1.00 OTHCMP DHB PLUG C RIH W/ GS PULLING TOOL AND LATCH PRN 01:30 - 02:00 0.50 OTHCMP DHB PLUG C POOH W/ PRN PLUG BODY - 02:00 - 02:30 0.50 OTHCMP DHB PLUG C SWS RE -DRESS PRN BODY 02:30 - 03:00 0.50 OTHCMP DHB PLUG C RIH W/ PRN 03:00 - 04:30 1.50 OTHCMP DHB PLUG C ATTEMPT TO INSTALL PLUG- DID NOT IMMEDIATELY SEAT - WORK PLUG - FINALLY SET PRN @ 8372' WLM 04:30 - 05:00 0.50 OTHCMP DHB PLUG C POOH W/ PRN RUNNING TOOL 05:00 - 06:00 1.00 OTHCMP DHB PLUG C RIH W/ PRONG AND SET IN PRN PLUG TO ESTABLISH BARRIER IN TUBING 06:00 - 06:30 0.50 OTHCMP DHB PLUG C POH W /PRONG RUNNING TOOL ON SLICK LINE F/ 8372'. 06:30 - 09:00 2.50 RUNCMP RUNCO TSTPRS P PJSM SET AND TEST PACKER. M - PRESSURE TEST 250 PSI LOW F/ 5 CHARTED MIN. DOWN THE TBG. PASSED. "y( r - PRESSURE TEST. TBG TO 4000 PSI F/ 30 CHARTED MIN. "t' PASSED -BLEED TBG TO 1500 PSI AND SI. - PRESSURE TEST IA T/250 PSI LOW FOR 5 CHARTED MIN. PASSED. - PRESSURE TEST IA T /4000 PSI FOR 30 CHARTED MIN. PASSED, - NOTIFY ADW WTL OF TEST RESULTS, OK TO PROCEED. 09:00 - 09:30 0.50 RUNCMP RUNCO RD P PSJM M R/D SLICK LINE FROM RIG FLOOR. -CLEAR FLOOR. 09:30 - 10:30 1.00 RUNCMP RUNCO RU P N/U DUTCH SYSTEM M -PJSM P/U DSM LUBRICATOR. -M /U TWC AND DSM LUBRICATOR. 10:30 - 11:00 0.50 RUNCMP RUNCO TSTPRS P TEST DSM LUBRICATOR T/ 250 PSI LOW AND 3500 PSI FOR 5 M CHARTED MIN. PASSED. 11:00 - 12:00 1.00 WHDTRE WHSUR TSTPRS P DSM SET TWC IN PROFILE OF NEW TUBING SPOOL 12:00 - 12:30 0.50 WHDTRE WHSUR TSTPRS P RIG DOWN DSM LUBRICATOR AND DUTCH RISER 12:30 - 13:30 1.00 WHDTRE WHSUR TSTPRS P RIG UP AND ATTEMPT TO TEST TWC FROM ABOVE - FAILED TO PRESSURE UP 13:30 - 14:30 1.00 WHDTRE ' WHSUR TSTPRS P BREAK DOWN SURFACE LINES - ISOLATE SURFACE VALVES AND TEST GOOD 14:30 - 15:00 0.50 WHDTRE WHSUR TSTPRS P RE -TEST TWC - FAILED TO PRESSURE UP AGAIN 15:00 - 17:00 2.00 WHDTRE WHSUR TSTPRS P RIG UP DSM LUBRICATOR & DUTCH RISER - TULL TWC 17:00 - 18:00 1.00 WHDTRE WHSUR PLUG P DSM ATTEMPT TO SETA NEW TWC - UNABLE TO GET 8 TURNS TO ENGAGE DOGS 18:00 - 19:00 1.00 WHDTRE WHSUR PLUG P PULL TWC TO SURFACE AND TEST - FUNCTIONED PROPERLY OUT OF HOLE - DISCUSS OPTIONS WITH TOWN 19:00 - 20:00 1.00 WHDTRE WHSUR RU P RIG DOWN DSM LUBRICATOR & DUTCH RISER - SUCK STACK DOWN TO BELOW PROFILE - RIG UP AIR LINE W/ 25' OF 1/2" PIPE AND LOWER INTO STACK - FLUSH PROFILE WITH AIR 12/27/2011 5:43:58AM • • 1- A."06`r° : ,yap,„ . -En h." r I' ,� : f _., : � , Pa Noah ;Ai'i'i - A�AS�I�A °- F';' v ,. , . , :" Operator: BP Event Type: WORKOVER Report: 24 Well/Wellbore No.: NGI -10 /OH Event Objective: Date: 12/26/2011 Well Type: DEVELOPMENT Site: NGI Job Number: Acct Proj No: X4- 00TNO -E: Contractor: DOYON DRILLING INC. Rig: DOYON 16 :. =.: Operations umrtia ; a a "-.:; From - To Hrs Phase Task Activity Code NPT Operation Op. Depth (ft) (hr) 20:00 - 20:30 0.50 WHDTRE WHSUR PLUG P RIG UP DUTCH RISER AND DSM LUBRICATOR - DSM SET TWC WITH NO PROBLEMS 20:30 - 21:00 0.50 WHDTRE WHSUR TSTPRS P FILL STACK W/ DIESEL 21:00 - 22:00 1.00 WHDTRE WHSUR TSTPRS P CLOSE BLINDS AND TEST TWC FROM ABOVE - 250# / 4000# FOR 5 MINUTES EACH ON CHART - PASSED 22:00 - 23:00 1.00 WHDTRE WHSUR RD P RIG DOWN DSM LUBRICATOR AND DUTCH RISER - BLOW DOWN LINES AND DRAIN STACK 23:00 - 00:00 1.00 WHDTRE WHSUR INSP P PJSM - REMOVE BELL NIPPLE TO CONDUCT A VISUAL INSPECTION OF THE ANNULAR PREVENTER Materials /Consumption : „ r Item - ,,._ Unit Usage On Hand Item „" `:: Una `; Usage On Hand -: FUEL -ULSD -RIG GAL 660 3,760 FUEL -ULSD- CAMP -( GAL 270 1,952 FUEL -ARCD -RIG ( GAL 1,037 9 "? nel - H �._ ........... - Pers - Personnel on Board: 39 .Company .. No. Peopte Hours Company= , ' No. People -. t Hours ASRC ENERGY 2 BAKER 2 BP 3 CAMERON 1 CH2M HILL 2 DOYON 18 DOYON 4 DOYON 6 M -I DRILLING FLUIDS 1 - Cumulative Phase Breakdown . Phase Planned Change of Scope Total Hour: Total Cost I Prod % Total NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total PRE 45.50 70.00 19.50 30.00 0.00 0.00 0.00 0.00 65.00 659,187.00 DECOMP 412.00 97.51 10.50 2.49 0.00 0.00 0.00 0.00 422.50 2,567,690.50 RUNCMP 42.50 93.41 3.00 6.59 0.00 14.00 100.00 0.00 0.00 59.50 OTHCMP 0.00 0.00 0.00 6.50 100.00 0.00 0.00 6.50 WHDTRE 13.00 100.00 0.00 0.00 0.00 0.00 0.00 13.00 Total I 513,00 93.961 33.00 6.041 0.00 20.50 100.00 0.00 0.00 566.50 3,226,877.50 Remarks 12/27/2011 5:43:58AM TREE = 6-3/8" CNV • VVELLHF_AD = GRAY SAFETY NO1PWELL RE-QUIRES A SSSV ACTUATOR= BAKER C NGI-10 .CHROME NIPPLES*** Oizic. ki47 OELE • ----- - ' . , KOP= 3405' , 4 II 0 1 i45 20" CONDUCTOR, 106' V I 0 1 2182' I SLB DB-6 NIP (9-CR), ID = 6.0(7 1 ■4 4 f Datum MD = 10379' 94 °. FL'40- •) 22 ;' 1-19-5/6' HES ES CENTER I Detr -;- - - 8800' S6 10= 19.124" • . 1. • .'! 2289' j-[ 9-5/8" BKR E-CP FKR ID = I (9-518" CSG, 47#, L-80 Fh'D 563, ID = 8.681" 1 2314' i •;`, ■1 li 9-5/8" BOWEN CSG PATCH I 2314' fil x 2381' 1 9-5/8" FO CEMENTER 19-5/8" CSG, 47#, S0095 XO TO MN-80 BUTT 1- 2340' 2487' H9-5/8" FO CEMENTF_R (13-3/8» CSG, 72#, M1-80 BUTT, ID = 12.34T I- 2811' Minimum ID = 6.600" @ 8366' 7" HES RN NIPPLE 7-5/8" TBG, 29.7#, L-80 VAM TOP HC (II), - 8230' j / 1 8230' -17-5/8" X 7" XO, ID = 6.276" i 0459 bpf, ID 6.875" • I 1 8247' --VHES R NIP (9-CR), f0 = 5.963" 1 ,Z I 8320' ., - I9 - 5/8" X 7" HES TNT PKR, ID = 5.900" • • I 8356' [-V HES RN NIPOI-OR), ID = 5.500" Fr TBG, 26#, L-80 Tell, .0383 bpf , ID = 6 276" H 8498' / \ i 8498' I---17" WLEG, ID = 6.276" I [TOP OF T' LNR H 8523' 1---ii I H ELMD TT NOT LOGGED 1 9-5/8" CSG, 47#, N-80, 10= 8.681" 1-1 8815' 1-41 IL PERFORATION SUMMARY REF LOG. BHCS ON 11/14/1976 ANGLE AT TOP PERF: 38° (:, 9265' I Note: Refer to Production DO for historical pert data 1 • SIZE - SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 9265 - 9293 0 06/11/77 3-3/8" 4 9300 - 9448 0 07/04/90 1 3-3/8" 4 9452 - 9492 0 07/04/90 3-3/8" - 4 9515 - 9540 0 06/11/77 3-3/8" 4 9564 - 9589 0 06/11/77 1 3-3/8" 4 9610 - 9644 0 06/11/77 1 3-3/8" 4 9676 - 9696 0 06/11/77 3-3/8" 4 9713- 9748 0 , 06/11/77 3-3/8" . 4 9799 - 9824 , 0 06/11/77 I _ . 1 9831' -I TOP OF SALT PLUG (01/16/12) I 7" LNR, 29#, N-80 BUTT, .0371 bpf, ID = 6.184" H 9988' 't".11VVI • •• • • • • i 8 tv A I TD H 9990' ' IVA 41 llgrAbli S'a DATE - REV BY ' COMMENTS DATE REV BY - COMMENTS PRUDHOE BAY UNIT 11/23/76Chalg R510R1GINAL COMPLETION 01/05/12 SM/JMD TiRLG DRAFT CORRECTIONS • WELL: NGI-10 03122/83 NI ES RWO 01/06/12' PJC 13-3/8" CSG CORRECTION PERIVIIT No. 9 760690 12/27/11 D16 MA/0 01/10/12;G4B1PJC POLL PRN PLUG (01/08/12) API N0 50-029-20229-00 07/19/01 , RNITP CORRECTIONS 01/19/12 RRW/JA/C REMVD SALT PLUG (01/16/12) SEC 1, T11N, R14E, 137' FSL & 916' FWL. 11/12/11 DM& PJC SALT PILL (11/03/11) ! 01/05/12, SIWJWO PRN PLUG (12126/11) _ BP Exploration (Alaska) Prb oc /0 Regg, James B (DOA) / Z { z, c From: Burnett, Richard D [burnr8 @BP.com] Sent: Friday, December 23, 2011 8:20 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Willingham, James M; Daniel, Ryan; Kilfoyle, Jeffery A; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft); Schultz, Mikel; Bill, Michael L (ASRC); Mountford, Carl F; Bjork, David; Reem, David C; AK, D &C Rig 16 Well Site Leader; Knowles, Anthony R Subject: Doyon 16 BOPE Usage Report (NGI -10) Attachments: BOPE Usage Report to AOGCC NGI -10 12- 22- 2011.doc Jim - Attached please find the BOPE usage form for NGI -10. Please let me know if I can answer any questions or you need any further clarification. Thanks, Rich Rich Burnett Operations Superintendent RWO /CTD +1 (907) 659 -5329 (Office - slope) +1 (907) 748 -5821 (Cell Phone) Harmony 2157 Alternate: Greg Sarber 1 • • ? I41 " Il i Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of my BOPE use to Prevent the flow of fluids from a well. Field Superintendent Name: Rich Burnett Weilsite Leader Name: Anthony Knowles Contact Number: 659 -5329 Contact Number: 659 -4177 Traction Number: Traction # to follow Well Location /Name & Rig Name: NGI -10 , Doyon 16 Permit To Drill (PTD) Number: 1760690 Date and Time of Incident: 12/22/11 , 13:45 Original Scope of Work: Drilling a cement plug on top of a salt plug covering the perforations. Operational Description Leading up to Well Control Event: Drilled - 18' of cement above the salt plug, drilled 20' into the salt plug leaving 155' of salt plug still over the perforations. Circulated a sweep to clean the hole. BOPE Used and Reason: The IBOP and the Annular were used. During the sweep, a flow increase was noted; circulation was shut down to verify flow. Flow was verified and the IBOP was shut in and the annular closed on the DP. Is a BOPE Test Required after use ( Yes / No): If no, why? 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Use the driller's method to circulate surface to surface and monitor the well for pressure. If the well is showing zero pressure, the plan is to pull up above the 7" liner and swap the well to clean brine and P( laying down DP. Once out of the hole we will re -test the IBOP and the annular before re -entry for runni completion. ,S \ Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa .aoccc.prudhoe.bayCc�alaska.gov Email CC List BP WSL Harry Engel Wells Team Leader Jeff Kilfoyle Engineering Team Leader Operations Drilling Engineer- Well File Wells Operations Manager Drilling & Completions Engineer Manager Wells Intervention Manager BOPE Usage Report for AOGCC Rev 1 September 1, 2010 Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, December 19, 2011 10:01 AM To: 'Bjork, David' Cc: Reem, David C; Daniel, Ryan Subject: RE: NGI -10 USIT Togs Sundry 311 -174 PTD(176 -069) Dave, Cement looks excellent in the 7" liner and up through the packer setting depth in the 9 5/8" intermediate casing. The proposed packer depth is acceptable. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Monday, December 19, 2011 9:48 AM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Daniel, Ryan Subject: NGI -10 USIT logs Sundry 311 -174 PTD(176 -069) Guy, Attached are the USIT logs from NGI -10 we ran over the weekend. Also attached is a proposed schematic for reference. File 030 is in the 7" liner from the top of our salt/cement plug to the liner top. File 032 is the 9 -5/8" casing from the 7" liner top to - 7,000ft. The new proposed packer setting depth is - 8,350ft. Please call if you have any questions. Regards, Dave • 12/19/2011 TREE = 6 -3/8" CIW WELLHEAD = GRAY F' I -.4 fk SAFETY NOTES: I. REQUIRES A SSSV. ACTUATOR = BAKER ''KB. ELEV = 47' proposed RWO BF. REV = KOP = 3405' I. Max Angle = 45 @ 9757 9 -5/8" Bowen Casing Patch, Datum MD = 10328' HES ES cementer and ECP Datum TV D = 8800' SS I 30' 1-17" DB - 6 Nipple, ID = 6.00" I 9 -5/8 ", 47 #, L -80, Hyd 563 cemented to surfac 13 -3/8" CSG, 72 #, N -80, ID = 12.347" H I 2810' ' Minimum ID = I 17 -5/8" TBG, 29.7 #, L -80, .0459 bpf , Co = 6.875" H - -8380' –8380' H 7 -5/8" X 7" XO • • I 8400' Hr. HES "R" MP, ID = 5.963" I ,7 � — 9 -5/8" X 7" HES TNT Packer ID = 5.900" • • --I –8505' H 7" HES "RN' NIP, ID = 5.500" 8520' I- I8-1/2° WLEG / TOP OF 7" LNR H 8523' —In 9 -5/8" CSG, 47 #, N-80, ID = 8.681" H 8815' Ilk PERFORATION SUMMARY REF LOG: BHCS ON 11/14/1976 ANGLE AT TOP PERF: 38 @ 9265' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 4 9265 - 9293 0 06/11/77 3 -3/8" 4 9300 - 9448 0 07/04/90 3 -3/8" 4 9452 - 9492 0 07/04/90 3 -3/8" 4 9515 - 9540 0 06/11/77 3 -3/8" 4 9564 - 9589 0 06/11/77 3 -3/8" 4 9610 - 9644 0 06/11/77 3 -3/8" 4 9676 - 9696 0 06/11/77 3 -3/8" 4 9713 - 9748 0 06/11/77 3 -3/8" 4 9799 - 9824 0 06/11/77 17" LNR, 29 #, N -80, 0.0371 bpf, ID = 6.184" —I 9986' v•IIV•11' TD H 9990' Ma&• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/23/76 ORIGINAL COMPLETION 10/10/06 CJN/TLH IBP PULLED WELL: NGI -10 03/22/83 LAST WORKOVER 07/05/07 DSM/PJC TREE C/O PERMIT No: 76 -069 07/19/01 RN/TP CORRECTIONS 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE API No: 50- 029 - 20229 -00 08/27/06 RRD/PAG IBP FISH IN HOLE .9/22/11 WJH Proposed R. SEC 1 T11 N R14E 4091.17 FEL 1123.28 FNL 08/28/06 TWS /PAG SET BKR IBP 09/12/06 CJN/TLH DSSSV INSERT SET BP Exploration (Alaska) Page 1 of 1 • • Schwartz, Guy L (DOA) Sent: Wednesday, December 07, 2011 9:16 AM 5 " ~J To: 'McLaughlin, Sean M EH 7 Subject: RE: NGI -10 BOPE test ( .D (760 - o‘? Sean, Sounds like a good change to the plan. With the very short run of 5 %" pipe the 4" test jt makes sense also. The change in BOPE configuration is granted. Regards, Guy Schwartz Senior Petroleum Engineer i.i ; ;' AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Wednesday, December 07, 2011 8:04 AM To: Schwartz, Guy L (DOA) Subject: NGI -10 BOPE test Guy, The NGI -10 Sundry was written when BP was proposing a three preventer stack and a second BOPE test after pulling the 7" tubing. Rather than setting a test plug and changing rams mid well BP has decided to use a 4 preventer stack. Also, the lower rams will only test on a 4" test joint since we will only be pulling 40' of 5 -1/2" (31' above pkr and 9' tail pipe) out of the ground. Proposed testing: NU BOPE with a 4 preventer stack configuration: annular, 7" fixed rams, blind shears, mud cross and 3 -1/2" x 6" VBRs. Test the BOPE to 250 -psi low and 4,000 -psi high. Test the 7" fixed rams with 7" test joint. Test the VBR's with a 4" test joint. Test the annular to 250 -psi low and 3,500 -psi high with a 4" test joint. WSL to sign the test chart. Pressure test BOPE every 7 days per AOGCC regulations. Continue to fill the well down the IA with 9.8 -ppg brine as necessary, keeping the hole full at all times. Please let me know if the State agrees with the changes to the Sundry. Regards, sean Sean McLaughlin RWO Engineer 564 -4387 Office 223 -6784 Cell 12/7/2011 3Q2011 Not Operable Injector Report 0 • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Thursday, November 24, 2011 9:59 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 3Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 3Q2011.zip >t4� ..b;, r i k , # ' i ; t ,, t Tom, Jim, Phoebe and Guy, " . Attached is the 3Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 3Q2011.zip» Notes on wells: Removed from Quarterly Injection Report: MPF -74 (PTD #1961080): Long term shut in that was returned to service. Passed MIT -IA on 09/11/11. Added to Quarterly Injection Report: 09 -36C (PTD #1951140): Leak found in tubing patch 13 -17 (PTD #1820260): Well reclassified while flowline repair is being performed END 3- 43/P -36 (PTD #1931700): Surface casing leak discovered post Brinker treatment MPC -08 (PTD #1850140): Long term shut in requiring MITIA to be compliant MPF -89 (PTD #2050900): Surface casing leak MPF -99 (PTD #2061560): Long term shut in requiring MITIA to be compliant r GI -10 (PTD #1760690 TxIA communication when on gas injection, AA for IAxOA communication. R-02 (PTD #1781000): Identified TxIA communication with leak detect log R S -09 (PTD #1821040): Shut in for rig workover to replace tubing U -04A (PTD #1920270): Starting head leak with a Furmanite repair failure Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/28/2011 NOT OPERABLE: Injector NGI -10 (PTD 060690) Downhole Tubing Plug Pulle. Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Wednesday, November 02, 2011 5:57 PM To: Maunder, Thomas E (DOA) Cc: Daniel, Ryan Subject: NOT OPERABLE: Injector NGI -10 (PTD #1760690) Downhole Tubing Plug Pulled Tom, The downhole tubing plug on injector NGI -10 (PTD #1760690) was pulled on 10/31/2011 in order to proceed with operations to prepare the well for the rig workover anticipated to begin end November 2011. On 11/01/2011, the wellhead pressures were SSV/2150/2150. The well remains shut in and operations are in progress currently to bleed down the annuli and secure the well with a salt plug and cement cap. Once the rig workover is complete and integrity is restored to the well, we will notify the AOGCC for a witnessed MIT -IA. Until such time, the well will remain shut in and under Not Operable status. Please let me know if you have any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator • BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com Fro • AK, D &C Well Integrity Coordinator Sent: Wee - day, July 27, 2011 7:43 PM To: 'Maunder, The E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 D ' aerator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; is, Robert; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, ' ey Subject: NOT OPERABLE: Injector NGI -10 (PTD #17.: -•0) Secured with Downhole Tubing Plug All, Injector NGI -10 (PTD #1760690) has passed a MIT -T to 3000 psi on . 7/2011 after being secured with a downhole tubing plug. The well is reclassified as Not Operable. The plan o -rd will be repair the TxIA communication with a rig workover tentatively scheduled for Q4, 2011. Please call if you have any questions. Thank you, 11/29/2011 NOT OPERABLE: Injector NGI -10 (PTD #1760690) Secured with Downhole Tubing Plug Page 1 of 2 • • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Wednesday, July 27, 2011 7:43 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Chiwis, Robert; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney Subject: NOT OPERABLE: Injector NGI -10 (PTD #1760690) Secured with Downhole Tubing Plug All, Injector NGI -10 (PTD #1760690) has passed a MIT -T to 3000 psi on 07/27/2011 after being secured with a downhole tubing plug. The well is reclassified as Not Operable. The plan forward will be repair the TxIA communication with a rig workover tentatively scheduled for Q4, 2011. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 ..,, ` JUL 2 9 2O From: AK, D &C Well Integrity Coordinator Sent: Wednesday, June 29, 2011 2:39 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA) ; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Chiwis, Robert; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Injector NGI -10 (PTD #1760690) Slow IA Repressurization All, Injector NGI -10 (PTD #1760690) is again exhibiting slow IA repressurization. IA repressurization was mitigated at the end of April, 2011 with a SSSV change out. The well currently operates under Administrative Authorization 4E.006 for IAxOA communication. The most recent AOGCC MITIA passed on 10/10/2010. The plan is to keep the well on injection, bleed the IA pressure and monitor the IA build -up -rate until slickline is prepared to remove the SSSV, and begin steps to secure the well. A rig workover on the well is scheduled for this fall. The well is reclassified as Under Evaluation. Plan forward: 7/29/2011 NOT OPERABLE: Injector NGI -10 (PTD #1760690) Secured with Downhole Tubing Plug Page 2 of 2 • • 1. DHD: Bleed and monitor IA BUR while well on injection 2. Slickline: Remove SSSV 3. Fullbore: Pump salt pill to cover perforations 4. Slickline: Dump bail cement. 5. Rig: Workover well A TIO plot, welibore schematic and AA for IAxOA communication have been included for your reference. Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/29/2011 • • Sit AITEE (IF ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. ! r6 - 0 P.O. Box 196612 Anchorage, AK 99519 -6612 /---- Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI -10 Sundry Number: 311 -174 Dear Mr. Reem: - r� {� 6 20 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday : -ekend. 1 k . Seamount, Jr. if Ch a i r DATED this ..5 day o f May, 2011. Encl. all STATE OF ALASKA ,i S . �i'1`� 1 ALASKA *AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPRO 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool - Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate - IN Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate _ ® Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 176 - 069 - 3. Address: - ® Service ❑ Stratigraphic 6. API Number: 1 P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 20229 - 00 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: PBU NGI -10 - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028302 Prudhoe Bay Field / Prudhoe Bay Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9990' - 8556' - 9904' 8491' None Yes, Unknown Depth Casing Length Size MD TVD Burst Collapse Structural Conductor 80' _ 20" 80' 80' 1530 520 Surface 2310' 13 -3/8" 2810' 2810' 5380 2670 Intermediate _ Production 8815' 9-5/8" 8815' 7660' 6870 4760 Liner 9163' _ 7" 8523' - 9986' 7433' - 8553' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9265' - 9824' 8017' - 8432' 7 ", 29#x5-112", 17# L -80 8395' Packers and SSSV Type: 9 -5/8" x 5 - 1/2" Baker'FB - packer Packers and SSSV 8386' / 7327' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development -IN Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 15, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas , ® GINJ ❑ GSTOR ❑ Abandoned ❑ WAG ❑ SPLUG ❑ Suspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Wilmer Hoffman, 564 -4592 Printed Name i avid Reem Title Engineering Team Leader Prepared By Name/Number. Signature < !s Phone 564 Date 5 /i /m oll Terrie Hubble, 564-4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i l r" ❑ Plug Integrity XFB.OP Test prMechanical Integrity Test ❑ Location Clearance 'f 40 Es:. '3oP /zs/- REcENED Other: ,1" ZS ,arc Ai J k 10440 & 6 P: Cl . CGlisnissron Subsequent Form Required: /6 _c/ / APPROVED A fl mongol ` IF MM S ✓ _Approved By: • MISSIONER THE COMMISSION Date � 4 1/ Form • 10403 Revised 1�MS M AY 2 5 iii ,,Z, S / q . (( Submit In Duplicate . ORIGINAL • • 0 b P GP .. egg -:/-, ,• :. NGI -1O Expense Rig Workover Scope of Work: Repair IA x OA communication. Pull existing 7" L -80 tubing. Cut and pull 9- casing. Replace and fully cement 9 casing to surface. Change casing packoffs and tubing spool. Run new 7- 5 / 8 " x 7" L -80 tubing. MASP: 2,520 psi Well Type: Gas Injector Estimated Start Date: July 15 2011 Production Engineer: Bob Chivvis Intervention Engineer: Wilmer Hoffman Pre -Riq Work Request: S 1 SBHPS. F 2 Place sized salt pill with -100' cement cap in the 7" liner across existing perforations. Swap the tubing to 9.8 ppg brine with diesel cap. MIT -T to 1,000 psi to test salt/cement plug. MIT -IA to 3,500 psi. MIT -OA to 2,000 psi. LLR if any fail. Well has IA x OA. W 3 Check the tubing and casing hanger lock down screws for free movement. Completely 1 back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. S 4 Drift tubing for 5 -1/2" jet cutter and tag top of salt/cement plug. E 5 Jet cut the 5 -1/2" tubing at 8,355' which is 5' down from the top of the 20', 5 -1/2" pup joint above the packer (based on tubing tally dated 03/22/1983). We want a 15' stub looking up. F 6 Circulate the well with 9.8 ppg brine and place a diesel freeze protect cap on top to protect surface equipment. CMIT TxIA to 500 psi. ✓ 7 Set a BPV in the tubing hanger. O 8 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. Circulate out freeze protection fluid and circulate well to clean 9.8 ppg brine through the cut. ND tree. NU BOPE consisting of annular, blind shear rams, flow cross and 7" fixed rams. Pressure test BOPE to 4.000 psi high / 250psi low. Test the annular to 3,500 psi. 2. Pull and lay down 7" tubing to the jet cut. 3. Set test plug in wellhead. Change out 7" fixed rams for 3 -1/2" x 6" VBRs. Test rams to 4,000 psi with 4" and 5 -1/2" test joints (two barriers are salt with cement top and test plug). 4. Mill and retrieve 5 -1/2" packer and tailpipe._ ece., /spa- - 5. RU a -line and run USIT in the 9-5/8" casing to determine TOC in the 13 -3/8" x 9 -5/8" annulus. —F 6. Set 9 -5/8" retrievable bridge plug -100' below top of cement. , / Pert) 7. Cut and pull the 9 -5/8" surface casing. Note: pipe rams will not be changed to 9 -5/8" as the welt has two tested barriers (salt with cement top and 9 -5/8" RBP) to the reservoir. Na Gat 8. Run and fully cement 9 -5/8 ", 47 #, L -80, Hydril 563 casing with ECP, ES cementer and casing patch to c,.,.. C,J,a7 surface. tr-411.- s 2 V•K • • 9. Install new casing packoff and new tubing spool.` 10. Drill out shoe track and retrieve 9 -5/8" RBP. v 11. Run a 9 -5/8" casing scraper to proposed packer setting depth and swap the well over to clean 9.8 ppg brine. 12. Set test plug in wellhead. Change out 3 -1/2" x 6" VBRS for 7 -5/8" fixed rams. Test the fixed rams to — 4,000 psi with a 7 -5/8" test joint (two barriers are salt with cement top and test plug). 13. Run 7 -5/8 ", 29.7 #, L -80, Vam Top HC IPC injection tubing with 7" tailpipe. A 7" Schlumberger DB -6 nipple will be run at -2,200'. This nipple will have an A -1 injection valve installed post rig to comply - with SSSV regulations. 14. Displace the IA to packer fluid and freeze protect. Pump KWF and freeze protect down the tubing. 15. Set and test the packer to 4,000 psi. AOGCC slope rep will be notified 24 hrs prior to test. 16. Set TWC. ND BOPE. NU and test tree. RDMO. Post -riq work: S 1 Pull Ball -n -Rod, pull RHC seat. C 2 Clean out cement plug and salt pill. S 3 Set A -1 SCSSSV injection valve in DB -6 nipple at -2,200'. F 4 Post RWO AOGCC MIT -IA. TREE = • 6 -3/8" CIW • WELLHEAD = GRAY SAFETY N WELL REQUIRES A SSSV. ACTUATOR= BAKER N G 110 KB. ELEV = 47' BF. ELEV = KOP = 3405' Max Angle = 45 @ 9757' Datum MD = 10328' • 2173' —17" OTIS RPB SSSV NIP, ID = 5.963" I Datum TVD = 8800' SS 2173' --17" OTIS INSERT AS DSSSV, D = 3.813" (09/12/06)1 13 -3/8" CSG, 72 #, N-80, ID = 12.347" I--I 2810' Minimum ID = 3.813" @ 2173' 7" OTIS INSERT AS DSSSV (09/12/06) 7" TBG, 29 #, L -80, .0371 bpf, D = 6.184" (--I 8350' 1 8350' H 7" X 5-1/2" XO I (TOP OF 5 -1/2" TBG H 8350' 1 1 I 8370' H5-1/2" OTIS XN NIP, ID = 4.455" I g g I 8386' H9 -5/8" X 5 -1/2" BAKER FB -1 FKR I ( 5 -1/2" TBG, 17 #, L -80, .0232 bpf , ID = 4.892" H 8395' , / 8395' H5-1/2" TUBING TAIL I 8403' H ELMD IT LOGGED 07/04/90 I TOP OF 7" LNR H 8523' I--' UNKNOW N I-I IBP FISH IN HOLE >8510' TO TD (08/27/06) I 9 -5/8" CSG, 47 #, N-80, ID = 8.681" H 8815' I GIKT PERFORATION SUMMARY REF LOG: BHCS ON 11/14/1976 ANGLE AT TOP PERF: 38 @ 9265' • • Note: Refer to Production DB for historical perf data • • SIZE SPF INTERVAL Opn /Sqz DATE gALT 2 -7/8" 4 9265 - 9293 0 06/11/77 3 -3/8" 4 9300 - 9448 0 07/04/90 3 -3/8" 4 9452 - 9492 0 07/04/90 3 -3/8" 4 9515 - 9540 0 06/11/77 3 -3/8" 4 9564 - 9589 0 06/11/77 3 -3/8" 4 9610 - 9644 0 06/11/77 - 3 -3/8" 4 9676 - 9696 0 06/11/77 • 3 -3/8" 4 9713 - 9748 0 06/11/77 3 -3/8" 4 9799 - 9824 0 06/11/77 • 7" LNR, 29 #, N-80, 0.0371 bpf, ID = 6.184" I-{ 9986' 1 TD H 9990' ........ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/23/76 ORIGINAL COMPLETION 10/10/06 CJN/TLH IBP PULLED WELL: NGI-10 03/22/83 LAST WORKOV ER 07/05/07 DSM/PJC TREE C/O PERMIT No: 76 -069 07/19/01 RN/TP CORRECTIONS 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE API No: 50- 029 - 20229 -00 08/27/06 RRD /PAG IBP FISH IN HOLE SEC 1 T11 N R14E 4091.17 FEL 1123.28 FNL 08/28/06 TWS /PAG SET BKR IBP 09/12/06 CJN/TLH DSSSV INSERT SET BP Exploration (Alaska) TREE = 6-3/8" CAN • ACTUATOR = __- __- - BAKER N G1-1 0 SAFETY 4: WELL REQUIRES A SSSV. KB. ELB/ = -- -- 47 proposed RWO BF. ELEV= - KOP = 3405' Mot Angle = 45 (i 9757' 9 -5/8" Bowen Casing Patch, Datum ND= 10328' HES ES cementer and ECP . . I - 2200' H7 6 Nipple, ID =6.00" Datum TVD = 8800' SS 47# L -80 Hyd 563 cemented to surface \, �� i� . j ✓G.�aat �.- - 1 vl j ct , Dry �C-p/ 13 -3/8" CSG, 72 #, N-80, ID = 12.347" 2810' ■ �a 5 I- - r U - Minimum ID = 7 -5/8" TBG, 29.7 #, L- 80..0459 bpf , ID = 6.875" H —8380' \ r I —8380"i—i7-5/8" X 7" XO , • •-- I - 8400' 1 HES "R" NIP, ID= 5.963" I E B I —8480' H9 -5/8" X 7" HES TNT Packe I • • I —8505' H7" HES "RN' NIP, ID = 5.770" I i \ I —8520' H8 -1/2" WLEG I ITOP OF 7" LNR H 8523' ill 9 -5/8" CSG, 47 #, N-80, ID = 8.681" I - -- 8815' PERFORATION SUMMARY REF LOG: BHCS ON 11/14/1976 ANGLE AT TOP PERF: 38 @ 9265' Note: Refer to Production CB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 4 9265 - 9293 0 06/11/77 3 -3/8" 4 9300 - 9448 0 07/04/90 3 -3/8" 4 9452 - 9492 0 07/04/90 3 -3/8" 4 9515 - 9540 0 06/11/77 3 -3/8" 4 9564 - 9589 0 06/11/77 3 -3/8" 4 9610 - 9644 0 06/11/77 3 -3/8" 4 9676 - 9696 0 06/11/77 3 -3/8" 4 9713 - 9748 0 06/11/77 3 -3/8" 4 9799 - 9824 0 06/11/77 I 7" LNR, 29 #, N-80, 0.0371 opt, ID = 6.184" H 9986' 1'11'4'f44V1 TD 9990' •••••••• DATE REV BY COMWENTS DATE REV BY COAAVE TS PRIAHOE BAY UNIT 11/23/76 ORIGINAL COMPLETION 10/10/06 CJN/TLH IBP PULLED WELL. NGI-10 03/22/83 LAST WORKOVIR 07/05/07 DSANPJC TREE CJO PERMIT No: 76-069 07/19/01 RNI TP CORRECTIONS 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE API No: 50- 029 - 20229 -00 08/27/06 RRD/PAG EP FISH IN HOLE 02/22/11 WJH Roposed RWO SEC 1 T11 N R14E 4091.17 FEL 1123.28 FAIL 08/28/06 TWS/PAG SET BKR EP 09/12/06 CJN/TLH DSSSV INSERT SET BP Exploration (Alaska) Page 1 of 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, May 24, 2011 9:49 AM To: 'Hoffman, Wilmer' Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C; Chivvis, Robert Subject: RE: NGI -10 RWO (PTD 176 -069) Wilmer, OK, sounds good. I'II write in that change to the sundry and attach this email to the well file. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Hoffman, Wilmer [mailto:hoffmawj @bp.com] Sent: Tuesday, May 24, 2011 9:27 AM To: Schwartz, Guy L (DOA) Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C; Chiwis, Robert Subject: RE: NGI -10 RWO (PTD 176 -069) Guy, per our phone conversation we will amend step #5 in the proposed procedure for the USIT log. We will go ahead and run the bond log from just above the top of the cement cap (plug across the perforations) up through the top of the 7" liner looking for top of cement behind the 9 -5/8" casing down in the production interval. We will then bring the logging tool up above the 13 -3/8" shoe to find top of cement behind the 9 -5/8" to find a cutting depth to retrieve the 9 -5/8" as originally stated in step #5. I have confirmed that no bond log exists with the pad engineer as well as our north slope operations and thus running a bond log across the production interval /liner lap will be done during this workover. WJH Ta w* Xorma,,k Operations Drilling Engineer Rig Workovers - BPXA Direct 907.564.4592 CeII 907.250.2601 BOOMER SOONER/ From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, May 23, 2011 9:45 AM To: Hoffman, Wilmer Subject: NGI -10 RWO (PTD 176 -069) Wilmar, I am reviewing the sundry to work -over NGI -10. The records I have do not indicate the 9 5/8" or 7" casing ever had a CBL done to verify cement quality. As a USIT is being run for finding the TOC in the 9 5/8" for cutting and 5/24/2011 y • Page 2 of 2 pulling it would be relatively easy to log from PBTD and verify that we have good cement down near the finer lap area also ( and insure we have 300' of cement above the proposed new packer depth). Please call me to discuss. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) ) 444 -3433 (cell) 5/24/2011 (-: r i f-A\ 9 ir i fT\ ric p $� L, q SEAN PARNELL, GOVERNOR r)1 t\ L R ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 January 28, 2011 Mr. Harold R. Engel Alaska Wells — Engineering Team Leader BP Exploration (Alaska), Inc. P. O. Box 196612 Anchorage, AK 99519 -5111 Subject: Late Mechanical Integrity Test PBU NGI -10; PTD 1760690 Prudhoe Oil Pool JAN 3 I a" Dear Mr. Engel: The Alaska Oil and Gas Conservation Commission (Commission) has reviewed the explanation from BP Exploration (Alaska), Inc (BPXA) regarding a late mechanical integrity test on Prudhoe Bay Unit (PBU) NGI -10. That explanation was in response to the Commission's notice of violation dated December 23, 2010. The Commission is satisfied with the corrective action summarized in BPXA's response — namely modification of the mechanical integrity test tracking system that uses the fixed anniversary date for required tests where appropriate. As requested, the Commission has again reviewed the facts associated with the issuance of the December 23, 2010 notice of violation. BPXA's request for the Commission to reconsider its position regarding the issuance of the notice of violation is denied. The fixed anniversary date for the mechanical integrity test on PBU NGI -10 was May 31, 2006; subsequent tests were to be performed no later than every 4 years thereafter according to Area Injection Order Administrative Approval AIO 4E.006, Rule 3. The test performed October 10, 2010 was more than 4 months late. BPXA suggests the October 7, 2006 mechanical integrity test satisfies the requirements of AIO 4E.006 and shifts the anniversary date established by Rule 3. That is an incorrect interpretation by BPXA. Commission records indicate the October 7, 2006 mechanical integrity test was performed for diagnostic purposes. A mechanical integrity test completed less than one month prior (September 18, 2006; reasons unknown) indicated possible pressure communication in addition to the already known inner annuls by outer annulus pressure communication that was addressed in AIO 4E.006. The two mechanical integrity tests within 5- months following issuance of the administrative approval to continue injecting into PBU NGI -10 does not satisfy Mr. Harold Engel • • • January 28, 2011 Page 2 of 2 the requirement for testing in 2010, nor would those tests reset the fixed date to be used for determining when future integrity testing is to be completed. To adjust the required mechanical integrity test anniversary date in AIO 4E.006 would require an amended administrative approval. The Commission considers this matter closed with BPXA's corrective action. Sincerely, Daniel T. Seamount, Jr. Chair, Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • by BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 January 21, 2011 Anchora95Alaska99519 -6612 Commissioner Dan Seamount Alaska Oil & Gas Conservation Commission rf-JVM 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 JAN 2 5 2011 Re: Notice of Violation, Late Mechanical Integrity Test �C PBU NGI -10; PTD 1760690 Intligrhge Dear Commissioner Seamount, This letter is in response to your December 23, 2010 letter to Mr. Thor Hjelmaas regarding the subject mechanical integrity test (MIT -IA) for PBU NGI -10. The MIT -IA anniversary date for NGI -10 was established in the Commission's administrative approval AIO 4E.006 dated May 31, 2006. The administrative approval requires an MIT -IA every four years, with the anniversary date being the effective date of the approval. We believe that the intent of this requirement is that an MIT had to be performed on or before the first four year anniversary date of the administrative approval, and that subsequent MITs were required at four year intervals after that test, consistent with standard practice for injectors not covered an administrative approval. On October 7, 2006 an AOGCC witnessed MIT -IA was successfully completed. This date was entered into our tracking system and re- established the next MIT - IA as October 7, 2010. Consequently, on October 10, 2010, four years after the initial MIT, a second AOGCC witnessed MIT -IA was successfully completed. Our tracking system to manage MIT's used the latest AOGCC witnessed MIT -IA date to establish the four year cycle. To avoid confusion and the potential for future misunderstandings, the tracking system has been modified to reflect only the administrative approval anniversary date. This modification applies to all wells including those with administrative approvals. We have reviewed our MIT records and believe all required MIT's for wells with administrative approvals conform to the required anniversary dates. Alaska Oil and Gas Con•ation Commission • January 21, 2011 Page 2 We believe that the two MITs conducted for PBU NGI -10 comply with the intent of the four year testing requirements of AIO 04E.006. The first MIT was performed on October 7, 2006; a date within the initial four year period specified in AIO 04E.006, and the second MIT was successfully performed four years later on October 10, 2010. Considering the successful MIT -IA's on NGI -10 coupled with daily well pressure monitoring, and that the integrity of the well is not in question, we respectively request that the Commission reconsider their position regarding this incident. As noted above, to avoid the potential for future misunderstandings we will maintain the administrative approval anniversary date as the deadline for conducting future MITs, and consequently conduct the next MIT -IA on PBU NGI -10 on or before May 31, 2014. Should you have any questions concerning these comments and our request, please contact me at 907 - 564 -4194. incerely, VA/tiO Harold R. Engel Alaska Wells Engineering Team Leader BP Exploration (Alaska) Inc. CC James Regg Winton Aubert Cathy Foerster • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, November 26, 2010 TO: Jim Regg SUBJECT: Mechanical Integrity Tests P.I. Supervisor R Q I I Sl / 1 BP EXPLORATION (ALASKA) INC NGI -10 FROM: Lou Grimaldi PRUDHOE BAY UNIT NGI -10 Petroleum Inspector Src: Inspector NON - CONFIDENTIAL Well Name: PRUDHOE BAY UNIT NGI -10 API Well Number: 50- 029 - 20229 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG101010133320 Permit Number: 176 -069 -0 Inspection Date: 10/10/2010 Rel Insp Num: M1TOP000003346 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI -10 Type Inj. N TVD 7327 IA 1860 4300 ! 4250 4240 P.T.D 1760690 , TypeTest SPT Test psi 1831 ' OA 740 740 750 750 Interval Other (describe in P/F Pass - Tubing 1610 1720 1720 1720 Notes: AA 4E.006 Compliance test (late, due 5/31/10). I.B.P. set in tubing tail. Good solid test, - Q0) t Z- 2 ;--1 o taik miNED FEB 0 " 20Th Friday, November 26, 2010 Page 1 of 1 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, December 23, 2010 12:18 PM To: 'Engel, Harry R' Subject: FW: NOV PBU NGI- 10.pdf - Adobe Acrobat Professional Attachments: NOV PBU NGI- 10.pdf Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Colombie, Jody J (DOA) Sent: Thursday, December 23, 2010 10:33 AM To: Crisp, John H (DOA); Grimaldi, Louis R (DOA); Jones, Jeffery B (DOA); Noble, Robert C (DOA); Scheve, Charles M (DOA) Cc: Regg, James B (DOA) Subject: NOV PBU NGI- 10.pdf - Adobe Acrobat Professional 12/28/2010 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, December 23, 2010 9:22 AM To: Roschinger, Torin T. Cc: Maunder, Thomas E (DOA) Subject: MIT Scheduling - PBU NGI -10, X -23, and NGI -01 Torin - Re: responding to your call about late MITs at NGI -01 and X -23 (follow -up to same issue for PBU NGI -10) Commission has discussed your request for clarification about the need to test PBU NGI -01 and PBU X- 23. Both wells were tested approximately 1 year early for diagnostic reasons; Commission Inspectors witnessed both tests. BPXA should retest both NGI -01 and X -23 to satisfy the requirement of administrative approvals AIO 4E.004 and AIO 3.011, respectively. Alternatively, BPXA may request an alternate test anniversary date for NGI -01 and X -23 since a Commission Inspector witnessed the early diagnostic MITs. If you choose to request a new MIT date, the Commission will issue amended AlOs. Also, I noticed that NGI -01 is not showing up on the monthly injector TIO report. Condition 2 of AIO 4E.004 requires this report for well to remain on injection. The well's TIO data appears to have disappeared from monthly submittal after report covering May 2010 (received by Commission 6/4/2010) without explanation. Regarding NGI -10, the Commission will be issuing a Notice of Violation with corrective action being documentation that the MIT scheduling program used by BPXA be corrected to include the flexibility to schedule MITs based one either witnessed MITs or a specified anniversary date as set by the Commission. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 12/28/2010 • • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Wednesday, December 15, 2010 8:57 AM To: Regg, James B (DOA); AK, D &C Well Integrity Coordinator Rep IZ I' 0 Cc: Maunder, Thomas E (DOA) Subject: RE: NGI -10 MIT 10 -10 -10 Jim, Our program queries the last AOGCC MITIA that passed and schedules the next test according to the frequency requirements on the AA. An AOGCC witnessed MITIA was performed on 10/07/06 after IA repressurization was reported on NGI -10. Since the AOGCC MITIA passed and has a 4 -year test frequency, the database scheduled the next AOGCC witnessed MITIA due 10/07/10. The MITIA was witnessed on 10/10/10. Though the 4 -year frequency was maintained, we recognize that our computer program did not identify the anniversary date for NGI -10. We are currently working toward a solution to address wells with anniversary dates. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, November 26, 2010 1:24 PM To: AK, D &C Well Integrity Coordinator Cc: Maunder, Thomas E (DOA) Subject: NGI -10 MIT 10 -10 -10 PBU NGI -10 (PTD 1760690); attached is MIT report documenting test witnessed by AOGCC on 10 -10- 2010. Due date for MIT per administrative approval AIO 4E.006 (Condition 3) was 5/31/2010. What Commission approval was BP relying on to postpone this MIT? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 12/20/2010 Page 1 of 1 • Regg, James B (DOA) From: Regg, James B (DOA) I Sent: Friday, November 26, 2010 1:24 PM ` eet'? 6(l� 1(0 To: AK, D &C Well Integrity Coordinator Cc: Maunder, Thomas E (DOA) Subject: NGI -10 MIT 10 -10 -10 Attachments: MIT PBU NGI -10 10- 10- 10.pdf PBU NGI -10 (PTD 1760690); attached is MIT report documenting test witnessed by AOGCC on 10 -10- 2010. Due date for MIT per administrative approval AIO 4E.006 (Condition 3) was 5/31/2010. What Commission approval was BP relying on to postpone this MIT? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 11/26/2010 1 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday, October 11, 2010 Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -10 FROM: Lou Grimaldi PRUDHOE BAY UNIT NGI -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI - 10 - API Well Number: 50 029 - 20229 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG101010133320 Permit Number: 176 - 069 - e Inspection Date: 10/10/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI -10 ' Type Inj. N TVD 7327 IA 1860 4300 ' 4250 4240 P.T.D 1760690 TypeTest SPT Test psi 1831 ' OA 740 740 750 750 Interval OTHER P/F P Tubing 1610 1720 1720 1720 Notes: AA 4E.006 Compliance test ate, due 5/31/10)1 set in tubing tail. Good solid test. lX� C 46 • 00 b cq p o v t 5131 2oo(0 -- al t.L c L.- -e. 1-5 > die • ±L r v�4�1 ■,tz'I j 7 b 2¢.�0�. ��t■ r- Monday, October 11, 2010 Page 1 of 1 ( p s' ' ( h i ( s b �� lI � � n � $ g ��� s � 5 � F F � � ` , � ,�� R � i � � SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 December 23, 2010 CERTIFIED MAIL — RETURN RECEIPT REQUESTED 7009 2250 0004 3911 4405 Mr. Thor Hjelmaas GPB Operations Excellence Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Subject: Notice of Violation Late Mechanical Integrity Test PBU NGI -10; PTD 1760690 Prudhoe Bay Oil Pool Dear Mr. Hjelmaas: On October 10, 2010 an Alaska Oil and Gas Conservation Commission (Commission) Inspector accompanied by a BP Exploration (Alaska), Inc. (BPXA) representative performed a mechanical integrity test (MIT) on Prudhoe Bay Unit (PBU) gas injector NGI -10. The well passed the MIT, however, the Commission notes that the test was more than 5 months past its compliance due date. Commission records indicate the MIT on PBU NGI -10 was due on or before May 31, 2010. The late MIT represents a violation of an administrative approval under Area Injection Order (AIO) 4E allowing PBU NGI -10 to continue gas injection with inner annulus by outer annulus pressure communication. Condition 3 of the Commission's administrative approval AIO 4E.006 dated May 31, 2006 requires the following: "BPXA shall perform an MIT - IA every four years to the maximum anticipated injection pressure, the anniversary date of which shall be this approval's effective date." The Commission understands from discussions with BPXA staff in the North Slope Well Integrity Office that the missed MIT may be the result of a computer scheduling program used by BPXA that does not have the flexibility to input alternate due dates for a compliance MIT. If this is the case, BPXA potentially could be out of compliance with every administrative approval granted by the Commission for injectors with compromised mechanical integrity unless immediately corrected. SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY • Complete items 1, 2, and 3 Also complete A- item 4 if Restricted Delivery is desired. x - ?Raged • Print your name and address on the reverse 1:1 Addressee so that we can retum the card to you. jatclir Im(PrinaliVame) C. Date of Delivery • Attach this card to the back of e the mailpiece, 9 D flatIWPOtil /2407X0 or on the front if spac permits. D. Is delivery address different from item 1? 0 Yes 1. Article Addressed to: If YES, enter delivery address below: 0 No nid r di in9aC/5 rie Po3 igt T YP e • e - Mail Mall AneL/fii<qq5iy •._. istenad etum Receipt for Merchandise 0 Insured Mail C.O.D. 4. Restricted Delivery? (Extra Fee) 0 Yes 2. Article Number (Renate r from swim label) 7009 2250 0004 3911 4405 PS Form 3811, February 2004 Domestic Retum Receipt 102595-02-M-154 U.S. Postal Service, CERTIFIED MAIL, RECEIPT 14 (Domestic Mail Only; No Insurance Coverage Provided) .1" For delivery information visit our website at www usps.com 1-4 OFFICIAL USE rq cr Postage $ m Certified Fee Postmark Retum Receipt Fee (Endorsement Required) Here D Restricted Delivery Fee (Endorsement Required) Ln ru Total Postage & Fees ru t 0 Er g // mie ina.as Ntreet, Apt. ' -- 1 - 1 or PO Sox No. city, State, ZIP+4 PS Form 3803 August 2006 EcP n In, Mr. Thor Hjelmaas 1 1 , December 23, 2010 Page2of2 Within 14 days of receipt of this letter, you are requested to provide the Commission with a written assessment of the cause for missing the required MIT and what has been or will be done in the future to prevent its recurrence in BPXA- operated fields. Failure to respond will result in further enforcement action in connection with this apparent violation of well MIT requirements as provided by 20 AAC 25.535. Sincerely, 4 _, . Daniel T. Seamount, Jr. Chair, Commissioner cc: AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within l0 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • Regg, James B (DOA) Page 1 of 1 From: Regg, James B (DOA) P& ,t;C-- lc� Sent: Thursday, December 23, 2010 9:22 AM �P�c I Z` Z � � � � 1-7 00 To: Roschinger, Torin T. 11 Cc: Maunder, Thomas E (DOA) Subject: MIT Scheduling - PBU NGI -10, X -23, and NGI -01 Torin - Re: responding to your call about late MITs at NGI -01 and X -23 (follow -up to same issue for PBU NGI -10) Commission has discussed your request for clarification about the need to test PBU NGI -01 and PBU X- 23. Both wells were tested approximately 1 year early for diagnostic reasons; Commission Inspectors witnessed both tests. BPXA should retest both NGI -01 and X -23 to satisfy the requirement of administrative approvals AIO 4E.004 and AIO 3.011, respectively. Alternatively, BPXA may request an alternate test anniversary date for NGI -01 and X -23 since a Commission Inspector witnessed the early diagnostic MITs. If you choose to request a new MIT date, the Commission will issue amended AIOs. Also, I noticed that NGI -01 is not showing up on the monthly injector TIO report. Condition 2 of AIO 4E.004 requires this report for well to remain on injection. The well's TIO data appears to have disappeared from monthly submittal after report covering May 2010 (received by Commission 6/4/2010) without explanation. Regarding NGI -10, the Commission will be issuing a Notice of Violation with corrective action being documentation that the MIT scheduling program used by BPXA be corrected to include the flexibility to schedule MITs based one either witnessed MITs or a specified anniversary date as set by the Commission. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 12/23/2010 Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellintegrityCoordinator @bp.com] Sent: Wednesday, December 15, 2010 8:57 AM To: Regg, James B (DOA); AK, D &C Well Integrity Coordinator Cc: Maunder, Thomas E (DOA) Subject: RE: NGI -10 MIT 10 -10 -10 Jim, Our program queries the last AOGCC MITIA that passed and schedules the next test according to the frequency requirements on the AA. An AOGCC witnessed MITIA was performed on 10/07/06 after IA repressurization was reported on NGI -10. Since the AOGCC MITIA passed and has a 4 -year test frequency, the database scheduled the next AOGCC witnessed MITIA due 10/07/10. The MITIA was witnessed on 10/10/10. Though the 4 -year frequency was maintained, we recognize that our computer program did not identify the anniversary date for NGI - 10. We are currently working toward a solution to address wells with anniversary dates. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, November 26, 2010 1:24 PM To: AK, D &C Well Integrity Coordinator Cc: Maunder, Thomas E (DOA) Subject: NGI -10 MIT 10 -10 -10 PBU NGI -10 (PTD 1760690); attached is MIT report documenting test witnessed by AOGCC on 10 -10 -2010. Due date for MIT per administrative approval AIO 4E.006 (Condition 3) was 5/31/2010. What Commission approval was BP relying on to postpone this MIT? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 12/15/2010 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, November 26, 2010 TO: Jim Regg SUBJECT: Mechanical Integrity Tests P.I. Supervisor BP EXPLORATION (ALASKA) INC NGI -10 FROM: Lou Grimaldi PRUDHOE BAY UNIT NGI -10 Petroleum Inspector Src: Inspector NON - CONFIDENTIAL Well Name: PRUDHOE BAY UNIT NGI -10 API Well Number: 50- 029 - 20229 -00 -00 Inspector Name: Lou Grimaldi Insp Num• mitLG101010133320 Permit Number: 176 -069 -0 Inspection Date: 10/10/2010 Rel Insp Num: MITOP000003346 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI -10 Type Inj. I N I TVD 7327 IA 1860 4300 4250 4240 P.T.D 1760690 TypeTest I SPT I Test psi 1 1831 OA 740 740 750 750 Interval Other (describe in Pte, Pass Tubing 1610 1720 1720 1720 Notes: AA 4E.006 Compliance test (late, due 5/31/10). I.B.P. set in tubing tail. Good solid test. I I i Friday, November 26, 2010 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commis TO: Jim Regg P.I. Supervisor .---J \<g-clc~1 ! DA TE: Wednesday, October I I, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-JO PRUDHOE BAY UNIT NGI-IO t1 {g' t}(,q FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprvíB ¡;.-. Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT NGI-IO API Well Number 50-029-20229-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS06I008I2304I Permit Number: 176-069-0 Inspection Date: 101712006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. NGI-IO ¡Type Inj. : r--- I -~--_. I ! Well N ITVD 7327 IA 240 4300 4240 4240 4230 : --t I I i ! i , , -~~~~._-- .~~--- I ' ! 550 ! P.T. , 1760690 ¡TypeTest i SPT i Test psi 183L75 OA ! 30 I 390 I 470 ¡ 520 -- , , , - --- I i -~ Interval OTHER P/F P v Tubing ¡ 1880 i 2500 i 2500 I 2490 ì 2480 ! ~-~.. ........L_~__ Notes Test performed for waiver for slow IA x OA communication :/,. C ('J Wednesday, October I I, 2006 Page I of I MEMORANDUM . TO: ,r"j _ j '" , '_1 ·'7 -r (1,;_., ir V//; ''''''-'-' Jim Regg P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector Well Name: PRUDHOE SAY UNIT NGI-IO Insp Num: mitCS060919115916 ReI Insp Num Packer Well ¡ NGI-IO ¡Type Inj. I N TVD P.T. , 1760690 !TypeTest! SPT Test psi Interval OTHER PIF F Notes Well is reported to have slow IA x OA communication. This pressure indicates IA x tubing communication. ;;/ Wednesday, September 20, 2006 Alaska Oil and Gas Conservation Commission State of Alaska DATE: Wednesday, September 20,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-IO PRUDHOE BAY UNIT NGI-IO Src: Inspector NON-CONFIDENTIAL Permit Number: API Well Number 50-029-20229-00-00 176-069-0 Depth 7327 ! iAT ..l.. ' lOA I I ' I Tubing! 1831.75 :/" . 1lu'O~ ~t> \ ~ Reviewed By: -¡-ve:---- P.I. Suprv ..' D, Comm Inspector Name: Chuck Scheve Inspection Date: 9!l8/2006 4300 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4060 1000 ! 170 I 2020 I .-------L 170 2130 r;". "'f.:'"' C) V'¡' 2!'ìf\\=) S'í"'Ah:t.. 'N l) ;"ir:¡" (J t tk,JU ~v.MII~' " - 4190 4140 110 170 4100 170 170 2160 2200 2260 2330 Page I of I i ~ _ ~' r~RANK :-l. iiAURKOWS6C/, GOVEAPlOR _-; _ - _ -- _ ~ ®~ ~`~ ~aa7 333 W. 7TM AVENUE. SUITE 100 ~®10T~~It~A1'I®1~T C®P~iaSSI®1~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 PAX (907) 276-7542 :~DiViINISTI2ATIVE APPI2®dAL 4E.006 ylr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99~ 19-6612 ;~t~6~~,~ JAN ~ ~ 20D$ RE: PBli NGI-10 (PTD 176-069) Request for Administrative Approval Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order ("AIO") 0-IE.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska} Inc. (``BPXA")'s request for administrative approval to continue gas injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU NGI-10. The Commission further finds that the well exhibits slow IA x OA pressure communication that can be safely managed with infrequent pressure bleeds. However, the Commission acknowledges that events such as SSSV control line failures may allow the well's tubing pressure to communicate with the I.3. Accordingly, the Commission be- lieves that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the con- straints enumerated below. AOGCC's administrative approval to continue gas injection in PBli NGI-10 is condi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of w~eli pressures and injec- tion rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform an iV1IT - IA every four years to the maximum anticipated injection pressure, the anniversary date of which shall be this approval's effective date; i~Ir. Stove Rossberg ~1ay 31, 2006 Pa;e2of2 =1. BPXA shall limit the well's OA pressure to 1000 psi; ~. BPXA shall install and operate remote pressure monitoring equipment on the wen's OA; 6. BPXA shall immediately shut in the well and notify the AOGCC it there is any change in the well's mechanical condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. I9one at o ge, Alaska and dated May 31, 2006. f/ ~ '~ .- J orma Dan T. Seamount ha;r,Y,an Commissioner ~~ '`~,':~ • ~ ~ ,~ Cathy f . Foerster Commissioner Re: WGI-06 (PTD # 1900300) Slow IA Repressurization BP notified the affecting 6 PBU AGI-06¡ TxIA NGI-01¡ TxIA NGI-06¡ IAxOA NGI-10¡ IAxOA NGI-13¡ TxIA WGI-06¡ TxIA Commission about varying degrees of pressure communication gas injectors. Wells are: -: ( BP intends no repairs to correct the pressure communication, instead relying on human intervention to manage the pressures. The correct mechanism for reviewing continued operation of these wells is the administrative approval process under AIO 4D Rule 9. Please submit admin approval requests to the Commissioner's attention. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hello Jim and Winton. Well WGI-06 (PTD # 1900300) is exhibiting indications of pressure communication between the tubing and lA, as noted on the attached TIO plot. An MITIA on 6/15/03 passed to 2500 psi. The field Operators safely manage this repressurization by bleeding the IA pressure approximately once every 30 days. This pressure management maintains the IA pressure below BP's maximum allowable annular surface pressure limit of 2000 psi. Current plans are to continue gas injection operations. No repairs are planned at this time. Attached is a TIO plot and wellbore schematic. Please call with any questions. «WGI-06.pdf» «WGI-06 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWelllntegrityEngineer@bp.com =r!1_?:_~:l:.!::(?:~:?1,.Jl:\ºYi~~_:l:.:l:.JJ1.~_~9:.r::_~..t:-y'§~!:!:g~_T.1.::::::~~£..:...S:(?'I!!.?- 1 of 1 3/24/2006 9:36 AM NGI-lO (PTD #1760690) Slow OA Repressurization e e Hello Jim and Winton. Well NGI-10 (PTD #1760690) is exhibiting indications of pressure communication between the fA and OA, as noted on the attached TIO plot. On 8/28/03, an MITIA passed to 4320 psi and an MITOA passed to 4320 psi. The IA and OA annuli are currently operating below BP's maximum allowable annular surface pressure limit of 2000 psi and 1000 psi respectively. Current plans are to continue gas injection operations. No repairs are planned at this time. Both the tubing and production casing packoffs tested okay. Attached is a TIO plot and well bore schematic. Please call with any questions. «NGI-10.pdf» «NGI-10 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllnteQrityEnQineer@bp.com Content-Description: NGI-IO.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: NGI-IO no Plot.jpg TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 1 of 1 3/20/2006 11 :38 AM TREE = WB..LHEAD = ACTl.IA.TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = DatumMD= DatumlVD = ? GRAY AXELSON 47' NGI-10 3405' 45 9757' 10328' 8800' SS 113-3/8" CSG, 72#, N-80, ID = 12.347" I Minimum 10 = 4.455" @ 8370' 5-112" OTIS XN NIPPLE 17" TBG, 29#, L-80, 0.0371 bpf, ID = 6.184" l-i mpOF 5-1/2" TBG H 8350' 8350' 5-1/2" TBG, 17#, L-80, 0.0232 bpf, ID= 4.892" 9-5/8" CSG, 47#, N-80, ID= 8.681" PERFORATION SUMMARY REF LOG: BHCS ON 11/1411976 ANGLEAT TOP ÆRF: 38 @ 9265' flbte: Refer to A"oduction DB for his1Drical perf da1a SIZE SPF INTERVAL OpnlSqz Oð.TE 2-7/8" 4 9265-9293 0 06/11/77 3-3/8" 4 9300-9448 0 07104190 3-3/8" 4 9452-9492 0 07104190 3-3/8" 4 9515-9540 0 06/11/77 3-3/8" 4 9564-9589 0 06/11/77 3-3/8" 4 9610-9644 0 06/11/77 3-3/8" 4 9676-9696 0 06/11/77 3-3/8" 4 9713-9748 0 06/11/77 3-3/8" 4 9799-9824 0 06/11/77 I 7" LNR, 29#, N-80, 0.0371 bpf, ID = 6.184" 9986' 9990' DATE 11/23/76 03/22/83 01/11/01 01/26/01 07/19/01 SIS-CS SIS-MD RNITP COMMENTS ORIGNAL COMA..El10N LAST WORKOVER CONVERTED TO CANVAS F INII. L CORRECTIONS REV BY Oð.TE REV BY . COMMENTS 2173' I SAFETY NOTES 7" OTIS RPB SSSV NIP, ID = 5.963" .-> ilv~ f·o.- 53eD r"'; CH¥e: :.- 2b 7Dr; 8350' 8370' 8386' 8395' 8403' 7" X 5-1/2" XO 5-1/2" OTIS XN NIp, ID = 4.455" 9-5/8" X 5-1/2" BAKER FB-1 PKR 5-lIZ' TUBNG TAL H ELMDTTLOGGED07/04/90 _';> }v\5A-( P - ~U~ ~ 6CO lOps; ~150f7(' ... PRUDHOE BAY UNrT WELL: NGI-10 ÆRMT fib: 76-069 API fib: 50-029-20229-00 SEC 1 T11N R14E4091.17 FEL 1123.28 FNL BP Exploration (Alaska) RE: NGI-1 0 (PTD 1760690) Gas Injector with TxIAxO... Subject: RE:NGI-IO (PJUD:.1760690},Gàs Injector with TxIAXOA communication (CO 492) From: "Dube, Anna Tn <Anna.Dube@BP.com> Date: Thu,22 Jan 2004 16:39:39-0900 . . To: -Winton Aubert .<winton ~aubert@ad.iniil.state.ak~us>. . , . CC:Ja~~s:'B"Regg..<jim_regg@a~n~:s.täte.ak.us>,:.DánierSeamount. '. . ',.: :., <da~~seam()unt@adn1ii1.state~'ak.us>,}'.NSU,: :ADW.W~ll'Oper~tioIls:Supervisor"'::;:', <NSUADWW e110peiatiol~sSuperVisor@BP . com> , .'.Rossbètg;' R' Sfevel1".: '...:'..' . <RossbeRS@BP .:com>, "Engel,. HaIÌ)'.' R'~. <EngelHR@BP . èom>', , ",Anders; Joe L" . <anders22@B:p.cotn> . .. .' . "'.' '. Winton, We agree this is of high priority and are mobilizing equipment as soon as possible to restore tubing integrity. Thank you, }lnna (j)u6e Well Integrity Engineer GPB Wells Group Phone: (907) 659-5102 Pager: . (907) 659-5100 x1154 -----Original Message----- From: Winton Aubert [mailto:winton_aubert@admin.state.ak.us] Sent: Thursday, January 22, 2004 2: 11 PM To: Dube, Anna T Cc: James B Regg; Daniel Seamount Subject: Re: NGI-10 (PTD 1760690) Gas Injector with TxIAxOA communication (CO 492) Anna, Because NGI-10 is a high rate gas injection well, AOGCC believes the 28 day window for sustained pressure mitigation measures is not appropriate. Please conduct preliminary diagnostics, and any indicated repairs, as soon as practicable. Thank you, Winton Aubert AOGCC 5)GANNED JJ\N 2 3 2004 1 of2 1/22/20044:50 PM RE: NGI-1 0 (PTD 1760690) Gas Injector with TxIAxO... 793-1231 Dube, Anna T wrote: Hi Jim and Winton, NGI-10 (PTD 1760690) has been found to have sustained casing pressure on the IA and OA (T/I/O = 2500/2520/2300; IAP & OAP < 45% of Pb). A MITOA passed to 4320 psi 8/28/03. The plan forward for this well is as follows: 1. Continue to inject gas while bleeding the IA and OA to maintain pressures below 2000 psi. 2. Slickline to pull and re-set the SSSV to restore tubing integrity 3. DHD to conduct AOGCC witnessed MITIA 4. Waiver for IAxOA communication This well is on a 28 day clock as of 1/20/04 to restore tubing integrity. Once pressures are confirmed to no longer be sustained pressures over trigger limits, the well will be removed from the 28 day clock. Testing will continue to waiver the well for IAxOA communication. Please give me a call if you would like to discuss this well further. Thank you, Anna Dube Well Integrity Engineer GPB Wells Group Phone: (907) 659 - 5102 Pager: (907) 659-5100 xl154 2of2 1/22/20044:50 PM MEMORANDUM State of Alaska Alaska Oil and Gas Consentation Commission TO: Julie Heusser Commissioner THRU: Tom Maunder P.I. Supervisor FROM: Jeff Jones Petroleum Inspector DATE: August 20, 2001 SUBJECT: Mechanical Integrity Tests BPX NGI Pad NGI-06, 07, 08, 10, 12 PBU PBF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. W,~lI NGI-06 I~'"e'nJ'l ~ I,-v-"- i ~"~ I'u~'n"i ~'~°1 ~.~o I ~'° I'~ I'"t~va'l 4 P.T.D.I 176o290 I Type testI P ! Test psiI 1857 I Casing I r,40 I 2010 I. 2ooo I 2000 I P/F i -~ I~tes: Pre-test pressures monitored 30 minutes & stable. .i w=,l .~,~ I'~"e'nJ-I ~ IT-v-~- I ~ ITu="~,I ~ I~oo I~oo I~oo i'n'~v='l .~ p.T.D.I 1760380ITYpetestl P I TestpsiI 1850 I Casingl 8O I 2010 I 2010 I 2010 I P/F I E I~tes: pre-test pressures monitored 30 minutes & stable. w~'l "~'~ I T~e'nj'! ~ '1 T.V.O. I ~"~'~ I,'u=n~ i .~00 I ~ I'~°° I ~ I'nte"a'l ~ P.T.D.I 1760520 ITypetestl P ITestpsiI 1855 I CasingI 110, I 2015 I 2020 i 2015 I P~F IE I~les: Pre-test pressures monitored 30 minutes & stable. w~,! .~,-~o I.,,e,.J.I ~ I T.V.O. I ~=~ I Tu~,n~ i' ~.1 ~00 I ~00 i ~oo i,n~,a,I ~ "P.T.D.I 1760690 ITypetestl P ITestpsil 1832 I Casingl 280 I 2O2O I 2O2O I 2O2O ! P/F I~ l~tes: Pre-test pressures monitored 30 minutes & stable. ' w~,I .~,-~= I.~,e,nJ.I G I..v.o. I ~.=.~ I.u~,.~l~o. I~ I~01~ I,.~e~a,I ~ P..T.D.I 1770810 ITypet. estl P ITestpsil 1856 I Casing.I 54O I 2010 I 2OOO I 2OOO I P/F. I ---P I~tes: Pre-test pressures monitored, 30 minutes & stable. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) Test's Details Monday~ August 20, 2001: I traveled to BPX's NGI Pad to witness 4 year MIT's on wells NGI-06, NGI-07, NGI-08, NGI-10 and NGI-12. Scott Lyon (BPX representative) performed the tests today. The pre-test pressures were monitored for 30 minutes and observed to be stable. All five wells passed the MIT's and are suitable for continued injection. Summary.: I witnessed 5 successful MIT's at BPX's NGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: _5 Number of Failures: _0 Total Time during tests: 3.$ hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU NGI-06,07,08,10,12 8-20-01 JJ.xls 8/27/01 STATE OF ALASKA ALASK IL AND GAS CONSERVATION COM,.~.~,SlON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 567' SNL, 1064' EWL, SEC. 12, T11N, R14E, UM At top of productive interval 1642' NSL, 239' EWL, SEC. 06, T11N, R15E, UM At effective depth 1852' NSL, 692' EWL, SEC. 06, T11N, R15E, UM At total depth 1890' NSL, 767' EWL, SEC. 06, T11N, R15E, UM 12. Present well condition summary Total depth: measured 11015 feet 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Plugs (measured) Alaska 0il & Gas Cons. 6. Datum Elevation (DF or KB) KBE = 47' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number NGI-04 9. Permit Num/ber 176-069 "' I~O.~A P I Number tVt .. ~). 029-20183.00 1 ~. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool ORI¢INAL Effective depth: ^nchorage Junk (measured) Fish: Perf Gun lost 06/77 at about 11010' true vertical measu red true vertical 8556 feet 10898 feet 8474 feet Casing Length Size Cemented MD TV[) Structural Conductor 103' 20" 240 sx Permafrost II 103' 103' Surface 2664' 13-3/8" 6000 sx PF II, Top Job of 400 sx PF II 2711' 2711' Intermediate Production 9894' 9-5/8" 750 sx Class 'G', 125 sx PF II 9942' 7808' Liner 1358' 7" 350 sx Class 'G' 9624' - 10982' 7575' - 8533' Perforation depth: measured 10216'-10268', 10329'-10406', 10410'-10425', 10441'-10558', 10574'-10630', 10639'-. 10644', 10662'-10762', 10819'-10844' true vertical 8010'-8047', 8089'-8142', 8144'~ 8154', 8165'-8243', 8253'-8291', 8297'-8300', 8312'-8381 8420'-8437' Tubing (size, grade, and measured depth) 7",29#, L-80to 9222'; 5~1/2",17#, L~80 9222'-9414'; 4-1/2",12.6#, N~80 9414'-9538' Packers and SSSV (type and measured depth) Baker 'SAB' packer at 9400'; Otis 'RPB' SSSVN at 2207' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation January 5, 2001 Date Approved 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Paul Chan, 564-5254 [] Detailed Operations Program [] BOP Sketch 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service co Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,'// _,/¢'~//. Title Senior Drilling Engineer Date Lowell C r a n ~y/~.;¢../~ -(__~ -¢' i~'f... ~- f_.-~...._~- ! Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test '~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10-~ ORIGINAL SIGNED ~:'""~, Approved by order of the Commission B Taylor Seamourl( Form 10-403 Rev. 06/15/88 I Approval No.,~d--,~.~/..Z/ Commissioner Date /¢~/¢d Submit In'Tril~lfcate NGI-04 RWO SCOPE OF WORK: Well NGI-04 has been diagnosed with IA x OA communication. A leak in the 9-5/8" casing is suspected and a RWO is required to restore the mechanical integrity of the well. The RWO is expected to require 12.5 rig days including the rig move. The RWO program is based on recovering the existing string, locating the 9-5/8" casing leak, cutting and pulling 9-5/8" casing, running a 9-5/8" tieback string, and running a new string of plastic coated 7-5/8" tubing. Pre-Rig Work: 1. Test the tubing hanger (through test port) to 5000 psi. Test the 9 5/8" packoff to 3500 psi. After conducting the 9 5/8" packoff test, completely back out and check each 9-5/8" and 7" lock down screw for breakage (check one at a time). If wellhead has been tested recently, email or fax in test report. 2. Bullhead 2% KCI water down tubing to perforations to load tubing. Liquid pack the 9-5/8" annulus by lubricating in diesel and bleeding of gas as required. (Tubing should be loaded with 2% KCI to avoid possible collapse of 7" tubing during 9-5/8" MIT). 3. Bullhead sized salt pill down to perforations to serve as lost circulation pill for upcoming workover operations. Follow the same procedure used to spot the salt pills on the WGI-1, 3, and 4 workovers. - 50 bbls of 10 ppg NaCI saturated hi-vis spacer - Sized salt pill in saturated NaCI brine -12.0 ppg (volume as required) - 40 bbls of 10 ppg NaCI saturated hi-vis spacer - Displace sized salt pill with 9.4 ppg NaCI brine Slow pump rate as hi-vis spacer and salt pill hit the perforations and pump only as required to adequately place sized salt pill in perforations. Do not fracture formation. Shut down and allow salt pill to leak-off to formation and settle out, isolating perforations. RU slickline. Drift tubing for upcoming E-line work and tag top of sized salt pill. RU E-line. RIH and perforate 4-1/2" tubing tail at -9420' MD (1' at 4spf). These perforations will be needed to remove any trapped gas from behind tubing tail, which could otherwise be exposed while milling the packer. RIH and cut 5-1/2" tubing (chemical cutter) immediately above 9-5/8" packer at 9344' MD (in the pup joint between the PBR and XN profile. Circulate well to 8.8 ppg NaCI filtered brine. ~/~~E IVE D Set a BPV and clear and level pad in preparation of the rig move. Assure tubing are freeze protected. Workover Procedure: DEC :[ 5 .... Alaska Oil & Gas Cons. Commission MIRU. Pull BPV. ND tree, NU and test BOPE. Circulate out freeze protect T~U~(] an(] c~rcu~ well to clean 8.8 ppg brine. Pull and LD 7" tubing. Retrieve PBR assembly. RIH and mill up 9-5/8" packer. Recover packer and tailpipe. RIH with 9-5/8" RTTS and isolate the leak in the 9-5/8" casing. Test the 9-5/8" casing to 4000 psi. If leak found, run casing inspection log to top of 7" liner. Send results to Anchorage ODE. If no leak found, set RBP at 2500' MD and go to step 13. RIH with RBP and set +/-600' below the leak. NOTE: FO @ 2367' and 2573', cemented with 125 sxs PFII cement. Dump 50' of sand (not carbolite) on top of RBP. RIH with multi-string casing cutter and cut 9-5/8" casing in the middle of the first full joint below the leak point. Circulate out Arctic Pack using diesel sweeps. POH and LD 9-5/8" casing. RIH with back off tool and recover 9-5/8" casing stub. RIH with 9-5/8" casing and screw into the stub. Set 9-5/8" casing with emergency slips. Changeout 9-5/8" packoff. . , Rig 1. . 3. 4. 5. o , , . 10. 11. 12. 13. 14. RIH and retrieve RBP. 15. Test 9-5/8" casing to 4000 psi with RTTS. 16. Run new completion of 7-5/8" IPC tubing with 9-5/8" packer. SSSV at N2200' MD. 17. Freeze protect permafrost zone. 18. Set BPV, ND BOPE, NU and test tree. RDMO. Post-Rig Work: 1. Cleanout sized salt pill. 2. Set DHSV at 2200' MD. Set packer at +/- 9540' with WELLHEA D= GRAY A CT UA TO R= KB. FLEV = 47 BF. ELEV: 47 KOP = 28O0 Max Angle = 54 @ 6700 Datum MD = · Datum TVD= 7" TBG-NPC, 29#, L80, 0.0371 bpf, ID:6.184 Id Minimum ID = 3.813" @ 9475' 4-1/2"OTIS X NIPPLE ..... NGI-04 .... ' Il 0.1481 bpf, ID=12.347 9317' I--I 93 ' I--I 9400' I--I 9535' I'-'-I 11 9538' t % Ii 9535' I~ 9623,I ~ I9475' I I5-1/2" TBG-NPC, 17#, L80, .0232 bpf , ID=4.892 I TOPOF 4-1/2" TBG-NPC 4-1/2" TBG-NPC, 12.6#, N80, .0152 bpf, ID=3.958 H I I-t 9941' 9-5/8" CSG, 47#, MN-80, .0732 bpf, ID=8.681 PERFORATION SUMMARY REF LOG: BHCS on 6/17/1977 ANGLE AT TOP PERF: I 47 @ 10323 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 10216-10268 O 06/29/1990 4 10354-10373 O 02/28/1987 4 10398-10406 O 02/27/1987 4 10470-10486 O 02/27/1987 4 10510-10535 O 02/27/1987 4 10599-10630 O 02/27/1987 4 10639-10644 O 02/27/1987 4 10673-10686 O 02/27/1987 4 10697-10725 O 02/27/1987 4 10750-10762 O 02/27/1987 4 10329-10354 O 06/17/1977 4 10373-10398 O 06/17/1977 I 7" LNR, 29#, MN-80, 0.0371 bpf, ID:6.184 Id 10982' 7" OTIS RPB SSSV NIPPLE, ID= 5.963 XO 7" X5-1/2" I 5-1/2" OTIS XA SLIDING SLV 5-1/2" OTIS XN NIPPLE ID=4.455 5-1/2" BOT PBRASSY I 9-5/8" X 5-1/2" BAKER SAB PACKER XO 5-1/2" X4-1/2" I 4-1/2" OTIS X NIPPLE, ID=3.813 I 4-1/2" SHE&ROUT SUB I 4-1/2" TUBING TAIL FLMD TUBING TAIL FISH - PERF GUN (LOST 06/18/77) i DATE REV BY COMMENTS 02/27/76 ORIGINAL COMPLETION ~2/4/2000 SIS-lsl CONVERTED TO CANVAS PRUDHOE BAY UNIT WELL: NGI-04 PERMIT No: 75-69 APl No: 50-029-20183-00 11N 15E6 4128.7 FEL 3388 FNL BP Exploration (Alas ka) 175-069-NGI04mitfai1092400.txt Subject: NGI-04 IAxOA Communication Date: Sun, 24 Sep 2000 08:29:31 +0100 From: "PBU, Well Integ T L" <pbuwellintegtl@BP.com> To: "'AOGCC - Blair Wondzell'" <blair wondzell@admin.state.ak.us>, "'AOGCC - Tom Maunder'" <tom maunder@admin.state.ak.us> CC: "'AOGCC - Lou Grimaldi'" <lou_grimaldi@admin.state.ak.us> Hello Blair and Tom. Gas injection well NGI-04 (PTD 1750690) is SI and to be secured with a TTP due to rapid IAxOA communication. While replacing the SSSV/injection v alve on 9/22/00, the OA pressure was observed to be tracking the IA pressur e. Further evaluation of the IAxOA communication on 9/23 determined the 1 eak path is not through the wellhead. An IAxOA leak rate of 11 gpm @ 245 p si was established with full returns up the OA. A CMIT IAxOA passed to 2000 p si, indicating a competent packer. Note that the 4-year MITIA passed on 7/ 23/00, there was no indication of IAxOA communication at that time. Plan is to leave the well SI and secured with a TTP while a RWO is evaluated. Please call if you have any questions. Joe Anders, PE / Kevin Yeager Well Integrity Engineer BP Exploration, Alaska Inc. (907) 659-5102 - Work (907) 659-5100, x1154 - Pager Page 1 STATE OF ALASKA ALAS'KA OIL AND GAS CONSERVATION COMMI~iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Alter casing __ Repair well Stimulate Plugging m Perforate Pull tubing Other X Workover 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 137' FSL, 915' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 1599' FNL, 1072' FWL, Sec. 1, T11N, R14E, UM At effective depth 1179' FNL, 1173' FWL, Sec. 1, T11N, R14E, UM At total depth 1123' FNL, 1186' FWL, Sec. 1, T11 N, R14E, UM 6. Datum elevation (DF or KB) 48' RKB 7. Unit or Property name Prudhoe Bay Unit 8. Well number NGI-10 9. Permit number/approval number 76-69 / 90-875 10. APl number 50-029-20229 11. Field/Pool Prudhoe Bay Field feet Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 9990' feet 8555' feet Plugs (measured) None Effective depth: measured 9904' feet true vertical 8491 ' feet Junk (measured) None Casing Length Size Cemented Conductor 8 0' 2 0" 240 sx AS cmt Surface 2783' 1 3-3/8" 4300 sx PF II Intermediate 8 7 8 9' 9 - 5 / 8" 750 sx Class G & 250 sx PF 'C' Liner 905' 7" 335 sx Class G Measured depth 106' 2811' 8815' 8523'-9986' True verticaldepth 106' 2811' 7659' 7432'-8552' Perforation depth: measured 9265'-9293', 9564'-9589', true vertical 8024'-8045', 8244'-8263', Tubing (size, grade, and measured depth 7", L-80, tubing w/ tail @ 8395' Packers and SSSV (type and measured depth) Otis 'RPB' sssv @ 2173', Baker 'FB-I' pkr @ 8386'WLM 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) 9300'-9448', 9610'-9644', 8050'-8159', 8278'-8303', Treatment description including volumes used and final pressure 9452'-9492', 9676'-9696', 8161'-8191', 8325'-8339', 9515'-9540' 9713'-9748', 8209'-8228' 8351'-8376', 9799'-9824' 8412'-8430' Alaska Oit & G3s Cons. 'A~chomge 14. N/A Prior to well operation Representative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments *Workover Well History Copies of Logs and Surveys run __ Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Gas Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~ 0/)/),/~/ ~,/.L/.L~__,, Title Form 10-404 ~ev 0S/17/89 ,4'1 I'?- ~,, 'h.~. '~',~-~3 ~ Drillin~ Analyst /..,.~.. ~7. / :2_ I z ~ /~-c Date I'iE " I SUBMIT IN DUPLICATE W.II HI.tory - Inltl81 Report - D811' idlY Ift8r I well I. .pudded or wOtlalver opel'8tloM ~. """d. the lorm glvlno IncluelVl dlhl8 Oft/y. District NORTH SLOPE AK F'Ald Lelle or UnIt 'Nell 00 ADL: 28302 NGI-IO Auth. or w.o. no, Title I AS3919 WORKOVER > API: 50-029-20229 Operator ARCO W.!. ARCO 21.7800 Spudded or W.O. bagun DItI Hour Prior status if a w.o, ACCEPT 12-14-90 0600 HRS Olte and. depth Complete record tor eech day reported a8 01 8:00 a.m. NABORS. 2ES .12/15/90 (1) DISP TEMBLOCK W/ 8.9 BRINE. 7"@ 9986' MW: 8.9 NaCl TD: 0 ACCE2T RIG @ 0600 HRS, 12/14190. TAKING ON 600 BBLS8.S PPG SEAWATER, 1000 BBLS 8.9 PPG NACL. PB: 9904 PUMP THRU BPV. R/U OTIS. TEST LUBE TO 4500 PSI. RIH. PUMP SUPV:RJB/GT THRU SSSV. ENGAGE SSSV. POOH 'Ill sssv. RIU HARD LINE TO TREE. TEST SAME TO 4500 PSI. DISP TBG WI FSW. PUMP 50 BBbS TEHBLOCK 120. PUMP 2ND 50 BBLS TEMBLOCK PILL. DAILY:$36,470 CUM:$36,470 ETD:$36r470 EFC:$55S,000 12/16/90 (2) PULL 'XXN' PLUG 'Ill S-LINE. 7"@ 9986' MW: 8.9 NaCl TD: 0 CHASE SO BBLS TEMBLOCK PILL 'Ill 8.9 PPG BRINE. Rlu OTIS. PB: 9904 SET ,POSITIVE PLUG. RID OTIS LUBE. SET BPV. N/D TREE. SUPV:RJB/GT INSTALL GRAY TEST PLUG. N/U BOPE. C/O TOP RAMS. TEST SAEM. INSTALL WEAR RING IN HGR. R/u OTIS. RIH. PULL 'XXN' PLUG 'Ill 'XN' NIPPLE. TDH. DAILY: $99, 872 CUM:$136,342 ETD:$136,342 EFC:$555,OOO 12/17/90 (3) CBU. DISP 'Ill BIOZAN. 7"@ 9986' MW: 8.9 NaCl TD: 0 POOH 'Ill 'XXN' PLUG. RID OTIS. Mlu BHA fl. WELL FLOWING. PB: 9904 SHUT IN WELL. MONITOR WELL. RIH WI BHA fl. TAG @ 9519'. SUPV:RJB/GT CBU. DISPLACE 'Ill 8.9 PPG BIOZAN NACL. ,DAILY:$55,939 CUM:$192,281 ETD:$192,281 EFC:$555,OOO 12/18/90 (L~¡NG. 7"@ 9986' MW: 8.9 NaCl TD: 0 ':8.9 PPG NACL 'Ill BIOZAN. DRLG FILL FI 9519'-9664'. PB: 9904 WI' BHA .1. RIH 'Ill BHA '2. CBU. DRLG FI 9664'. SUPV:RJB! CUM: $227, 971 ETD:$227,971 EFC:$555,OOO 12/19/90 ( WASHING FILL @ 9844'. 7"@ 9986' MW: 8.9 NaCl TD: 0 DRLG 'Ill MILL FI 9664'-9665'. CBU. POOH. LID NILL. M/U PB: 9904 BHA t3. RIH. TAG BTM @ 9665'. WASH FI 9665'-9815'. CIRC SUPV:RJB/GT SO BBLS HEC PILL. WASHED FI 9815r- 9849'. DAILY: $23, 370 CUM:$251,341 ETD:$251,341 EFC:$555rOOO 12/20/90 (6) TESTING 'ilL BOP. 7"@ 9986' MW: 8.9 NaCl TD: 0 WASHHD'FILLF/ 9857'-9862'. SHORT TRIP TO 8218'. RIH TO PB: 9904 9862'. CIRC. PUMP 50 BBLS HEC SWEEP. POOH. LID 3-1/2" SUPV: LAP IDB DF. N ID RI SER. .. N IU 'ilL ~HOOTING FLANGE. TEST 'ilL BOP. DAILY[~5f¡1~). r;. ~ ¥:f3!5} 482 ETD: $305, 482 EFC: $555,000 jI'¿ ¡ ï.f)~,f1¡,~~~,~¡~::i ~~vJ i~~'\~.é;'.; ,,,L A:~. c' Number all dally well history lorm8 consecutively Page no. ae they ere prepared for each well. AR3B-459-1-D Dally Well History - Final Report .<"'; ,., ¡, ',. Wednesday alter allowable has been assigned or well Ie Plugged, Abandoned, or So¡'d, I t nded for an indefinite or appreciable length of time. On workovenl when a~ offici. te~t s no teat data in blocks provided. The "Final Report" form may be used for reporting the ent re Accounting cost center code NORTH SL P County or Parish State District , ADL.: 283 Well - Lease or Unit Field AS3919 WORKOVER Auth, or W.O. no. Title API: ARCO Operator A.R,Co. W.I. ACCEPT 12- Spudded or W.O, begun Date Date and depth Complete record forNI'FB$RgePJ!ffS as of 8:00 a.m. RIG RELEASED @ 06:00 HRS. 7"@ 9986' MW: 8.9 NaCl RIH 'Ill OTIS XXN PLUG. SET PLUG IN XN NIPPLE @ 8392t. TEST TBG TO 4000 PSI. PULL PLUG. RID CAMeO. INSTALL BPV.'~7 CHANGE TOP RAMS. NID BOP. INSTALL 7" GRAY GEN II TREE. TESTED TO 5000 PSI. PUMPED 23 BBLS DIESEL DN TBG TO FREEZE PROTECT. RIG RELEASED @ 06:00 HRS, 12/21/90. DAILY:$28,070 CUM:$333,552 ETD:$333,552 EFC:$555,OOO Old TO New TO PB Depth Released rig Date Kind of rig Type completion (single, dual, etc.) Classifications (oil, gas, etc.) Olflcial reservoi r name{s) Producing method Potential test data R' Producing Interval Oil or gas Test time Production Well no. Date eservolr 011 on test Gas per day 0 GOR Gravity Allowable Effective date Pump size, SPM X length Choke size T,P, C.P. Water V. corrected' Title Drillln.g SUpt. For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Number all daily well hlatory forma consecutively PIQI no. as they are prepared for each well. DIYllion of .1IIt. . AI 1IC'-P8"y AR3B-459-3-C TO: THRU: MEMORANUUM State of Alaska ALASKA OIL AND GAS CONSERVATION CO~MiSSION · Lonnie C. Smi '~ DATE: December 20, 1990 Commissioner -- FILE NO: JT.HH.1220.11 TELEPHONE NO: SUBJECT: BOP Test AAI PBU NGI #10 Permit No. Prudhoe Oil Pool FROM: Harold R. Hawkins Petroleum inspec Saturday Dec. 14, !9.9P: i witnessed the BOP test on Nabors 2E-S £or AAi PBU NGI f~]0. There were no failures, i filled out an AOGCC ~ield report which is attached. In summary: The BOP test i witnessed on Nabors 2E-S for AAI PBU NGI #10 was satislactorily performed. At t achment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 OPERATION: Drlg Wkvr V// Operator AA / Location: Sec / T ///(Y R//~/~~ ~M Orlg contrctr STATE OF ALASKA ALASKA OIL AND CAS CONSERVATION COMMISSION BOPE Inspection Report / / TEST: Initlal ~ Weekly Other Representative'/~/X'~///~/~) Ba/~)~ Location (general) Housekeeping (general)'//~, ~/ ! Reserve pit, 0 MUD SYSTEHS: lrip tank Pi t gauge Flow monitor Gas detectors Well sign~/A Audio BOPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve "-f~4J0 Kill line valves Check valve Test Pressure ACCUMULATOR SYSTEM: Full charge pressure ~(~) ~ psig Press after closure /7~(~ psig Pump incr clos press 200 psig -~- min V~~ sec Full charge press attained ~_ min '-- sec /Fa Controls: Master Remote 6~/~/~y/ Blind switch cover ! ' KELLY AND FLOOR SAFETY VALVES: Upper Kelly Test pressure Lower Kelly Test pressure Ball type Test pressure Inside BOP Test pressure Choke manifold Test pressure Number valves /y Number flanges 2 ~ Adjustable chokes ~.~ ~z~ Hydraul ical ly operated choke ../~/.y~/)/~.~/~/~ TEST RESULTS: Failures /(y/~'~ Test time ~ hrs Repair or replacement of failed equipment to be made within -'--- days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 05/10/90) W I TNESS STATE OF ALASKA ALAST(A OIL AND GAS CONSERVATION COMMI,~°'~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well ~ Plugging _ Time extension _ Stimulate _ Pull tubing w Variance _ Perforate _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951O 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service ~X Other 6. Datum elevation (DF or KB) RKB 48' 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 137' FSL, 915' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 1599' FNL, 1072' FWL, Sec. 1, T11N, R14E, UM At effective depth 1179' FNL, 1173' FWL, Sec. 1, T11 N, R14E, UM At total depth 1123' FNL, 1186' FWL, Sec. 1, T11 N, R14E, UM 8. Well number NGI-10 9. Permit number 76-69 10. APl number 50-029-20229 12. Present well condition summary Workover 11. Field/Pool Prudhoe Bay Field Total Depth: measured 9990' feet Plugs (measured) None true vertical 8555' feet Effective depth: measured 9904' feet Junk (measured) true vertical 8491' feet Casing Length Size Cemented Conductor 8 O' 20" 240 sx AS cmt Surface 2783' 1 3-3/8" 4300 sx PF II Intermediate 8789' 9-5/8" 750 sx Class G & 250 sx PF 'C' Liner 905' 7" 335 sx Class G DEC 1 1990 None Alaska 0ii & Gas Cons, .C0.tll~ts$i~' .Anchorage Measured depth True vertical depth 106' 106' 2811 ' 2811 ' 8815' 7659' 8523'-9986' 7432'-8552' Perforation depth: measured 9265'-9293', 9300'-9448', 9564'-9589', 9610'-9644', true vertical 8024'-8045', 8050'-8159', 8244'-8263', 8278'-8303', Tubing (size, grade, and measured depth 7", L-80, tubing w/ tail @ 8395' Packers and SSSV (type and measured depth) Otis 'RPB' sssv @ 2173', 9452'-9492', 9515'-9540' 9676'-9696', 9713'-9748', 9799'-9824' 8161'-8191', 8209'-8228' 8325'-8339', 8351'-8376', 8412'-8430' Baker 'FB-I' pkr @ 8386'WLM 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch X 14. Estimated date for commencing operation December 13, 1990 16. If proposal was verbally approved Lonnie Smith Name of approver 1 2/O 7/9 0 Date approved 15. Status of well classification as: Oil __ Gas m Suspended Service Gas Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~~4,g.,, Title Drillin9 Analyst FOR COMMISSION USE ONLY Date IZ'IZ-"~O Conditions of approval: Notify Commission so representative may witness Plug integrity m BO? Test _ Location clearance m Mechanical Integrity Test ...~,." Subsequent form require Approved by the order of the Commission Commissioner IApproval No. / , Date Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned SUBMIT IN TRIPLICATE i, al- 10 WORKOVER SUMta. ,,-IY RIG PROCEDURE 1. MIRU workover rig. Pull BPV. . . . . . o Bullhead 8.5 ppg seawater into perforations. Pump HEC/Temblock pills as necessary to control fluid loss, Set BPV. Nipple down tree. Nipple up and test BOP. Test surface casing packoff to 1500 psi, test 9-5/8" packoff to 4000 psi. Test 9 5/8" casing to 4000 psi. Pull BPV. RIH with 31/2" x 27/8" drill pipe with 23/8" motor assembly; and clean out to PBTD. Displace well with clean fluid. POOH and lay down drill pipe. RU slick line and set standing valve. Test tubing to 4000 psi for 30 minutes. Pull standing valve. RIH and set SSSV and function test. RD slick line. Test annulus to 4000 psi for 30 minutes. Notify the AOGCC 24 hr prior to testing so they may witness the tests. Nipple down BOP. Nipple up tree. Test tree to 5000 psi. Secure well, set BPV. Release rig. · Estimated BHP · Planned Workover Fluid 3649 psi @ 8350' TVD 8.5-8.7 ppg Seawater RECEIVED DEC 1 5 1990 0JJ & Gas Cons, Commission Anchorage 13-5/8" 5000 PSI BOP STACK I I ANNULAR PREVENTER 7 PIPE RAMS 6 BLIND RAMS 5 DRILLING SPOOL 4 PIPE RAMS 3 iTUBING 1. 13-3/8" CASING HEAD 2. 5000 PSI TUBING HEAD 3. 13-5/8" - 5000 PSI PIPE RAMS 4. 5000 PSI DRILLING SPOOL 5. 13-5/8" - 5000 PSI BLIND RAMS 6. 13-5/8" - 5000 PSI PIPE RAMS 7. 13-5/8" - 5000 PSI ANNULAR ACCUMULATOR ~APA(~ITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. RECEIVED DEC 1 5 199~ Oil & Gas Cons. Commissiot~ Anchorage BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL IN WINTER OR SEAWATER DURING SUMMER MONTHS. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PS! AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORDTEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOP TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY FOR DRILLING OPERATIONS. FOR COMPLETION/ WORKOVER OPERATIONS, PERFORM COMPLETE BOP TEST EVERY 21 DAYS AND FUNCTION TEST BOP WEEKLY. DAM 11/20/89 BOP SCH (FOR: NAB 2ES) STATE OF ALASKA ALASKA .AND GAS CONSERVATION CC ,~ISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 137' N & 915' E of SW Cr. Sec. 1, T11N, R14E, UM At top of productive interval 1599' S & 1072' Eof NWCr. Sec. 1, T11N, R14E, UM At effective depth At total depth 1123' S & 1186' E of NW Cr. Sec. 1, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 48 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-10 (22-1-11-14) 9. Permit number/approval number 76-69/90-302 10. APl number 50 - 029-20229 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9990 feet Plugs(measured) 8555 feet Effective depth: measured 9503 feet true vertical 8200 feet Junk(measured) 9756' CTM Casing Length Size Cemented Measured depth True vertical depth Conductor 20" 240 Sx AS 80' 80' Intermediate 13-3/8" 4300 Sx PF II 2310' 2309' Production 9-5/8" 750 Sx 'G' 8815' 7659' Liner 7" 335 Sx 'G' 9986' 8552' Perforation depth: measured 9265-9293'; 9300-9335'; 9335-9434'; 9444-9448'; 9452-9492'; 9515-9540'; 9564-9589'; 9610-9644'; 9676-9696'; 9713-9748'; 9799-9824' true vertical 8024-8045'; 8050-8076'; 8076-8148'; 8156-8159'; 8161-8191 '; 8209-8228'; 8244-8263'; 8278-8303'; 8325-8339'; 8351-8376'; 8412-8430' Tubing (size, grade, and measured depth) 5", 17#, L-80, PC tubing @ 8395', 7", 29#, L-80 PC tubing @ 8350' 13. Stimulation or cement squeeze summary 14. Packers and SSSV (type and measured depth) Baker FB-1 packer @ 8386' MD, Otis RPB SSSV @ 2173' Intervals treated(measured) C'"'if"'Y ~ ~iii' ~ ¢'r~'~'~ Treatment description including volumes used and final pressure , ;i;;!,;!;:;~ .~jj .~ G~ts ¢'"'~¢u1~. ~ 6~.f~'~¢~8~ ~ " Representative Daily Average Produ~ion or Iniection Data ~8hg['~i~ - -~e~ere~ce - OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - 160M .... 3900 Subsequent to operation 182M .... 3900 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations x Oil Gas Suspended 17. I hereby ce~'fy~he foregoing is true and correct to the best of my knowledge. Signed~-~-~y O~/'[/f/1 ~ Title Form 10-~04 Rev 06/15/88 Service Gas InJection SUBMIT IN" DUPI~ICATE Senior Area Engineer NGI-10 Work Summary Qn July 4, 1990 the following perforations were added in Well NGI-10. Interval, MD ~.v ~.:l~,~ ~. (BHCS 11/14/76) Interval Length Zone SPF 9300-9310' 10' 4 4 9335-9360' 25' 4/3 4 9380-9434' 54' 4 4 9444-9448' 4' 4 4 9452-9460' 8' 3 4 ARf":O ALA3'KA, INr;., P, O, BO× 'i ANCHflI:;:Ar;F A I__ A.":,' K A c.~'c' '";.' i ,".", ..... ,~ ,,' : .:' o... R Ii." F:' E R E i'..! C F.L' · A R C 0 i"-: A 3' E 0 H O L_ E. I'~ _'F_ N A L ~.' F'I..IEA;5.~E ,'FI(iN AND IRIF.'I"UI'?N THE A'i-TA("~F'Y A2 t;eECIFtF'i- OF' DATA, HAVE A NICE DAY! A L. L. 'Y' H C) F:' F:' E C: I< E Fi: 'i- 0 .- i 15 2 9 JUL 1 0 1990 /Lqchorag~ A "f'l... A Z':: A ! i...A2 A 'i" L.. ,q ,F rq T' L.. A,fi.' ,,q 'i" L. A 3' ,q '}" L.. :q 5' A'i' LA:ii: A'?'L.A£ D ! 3' T R I B U 1" I 0 N · * C F'N'r I;.: A I_ F" I I_ I.'-" ~" CHE:'VRrli'-~ E X 'i" I!.': N ,':";' ]: 0 N E X F:' I.. 0 R A "l' ICi N EX. XON i'JAl:;,' A T HON :~ HOB .'[ L · ¢ F'HILL IF'3' F'B bELL. F]:L.E:£ F'..' & D :,~ BF'X '"' ZTA]"E OF ALAZKA 'Ir TEXACO STATE OF ALASKA ALASI" OIL AND GAS CONSERVATION , _ MMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon :1 Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Operation shutdown Plugging Pull tubing Variance · ,, 5. Type of Well Development Exploratory Stratigraphic Service X 4. Location of well at surface 137' N & 915' E of SW Cr. Sec. 1, T11N, R14E, UM At top of productive interval 1599' S & 1072' E of NW Ct. Sec. 1, T11N, R14E, UM At effective depth At total depth 1123' S & 1186' E of NW Cr. Sec. 1, T11N, R14E, UM Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) 48 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-10 (22-1-11-14) 9. Permit number 76-69 10. APl number 50 - 029-20229 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9990 feet Plugs(measured) 8555 feet Effective depth: measured 9904 feet true vertical 8491 feet Junk(measured) Casing Length Size Cemented Measured depth Tru~~l depth Conductor 20" 240 Sx AS 80' 80' Intermediate 13-3/8" 4300 Sx PFII 2310' 2309' Production 9-5/8" 750 Sx 'G' 8815' 7659' Liner 7" 335 Sx 'G' 9986' 8552' Perforation depth: measured 9265-9293'; 9310-9335'; 9360-9380'; 9434--9444'; 9460-9492'; 9515-9540'; 9564-9589'; 9610-9644'; 9676-9696'; 9713-9748'; 9799-9824' true vertical 8091-8106'; 8147-8155'; 8167-8191 '; 8209-8228'; 8244-8263'; 8278-8303'; 8325-8339'; 8351-8376'; 8412-8430' Tubing (size, grade, and measured depth) 5", 17#, L-80, PC tubing @ 8395', 7", 29#, L-80 PC tubing @ 8350' Packers and SSSV (type and measured depth) Baker FB-1 packer @ 8386' MD, Otis RPB SSSV @ 2173' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1990 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify that the fore,Icing is true and correct to the best of my knowledge. Signed 2~,"~~,~~¢'~ Title Operations Engineering Manager 15. Status of well classification as: Gas Suspended gas injector Date '~/,j'O//~'O FOR COMMISSION U~I= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approval No.~ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Commissioner Date Approved Copy _.Returned -- SUBMIT IN TRIPLICATE NGI-10 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations in Well NGI-10. The proposed perforation intervals are as follows: Interval, MD Interval, MD Interval Zone (BHCS 11/14/76) (Tie-in) Length 9300-9310' 93C0-9310' 10' 4 9335-9360' 9335-9360' 25' 4/3 9380-9434' 9380-9434' 54' 4 9444-9448' 9444-9448' 4' 4 9452-9460' 9452-9460' 8' 3 A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with the wellbore loaded with sea water. After perforating, gas injection will resume with the wellbore Icad fluid being displaced into the wellbore formation. No flaring is anticipated. 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) .3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 bi ! REL ! NE BOP EI;tU ! PHENT ARCO Alaska, In, Prudhoe B~f Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 23, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: NGI-10 (22-1-11-14) Permit No. 7-604 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. S cheve DFS/TPA/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(NGI-10)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA AL.A,.-_~A OIL AND GAS CONSERVATION COL,,~...~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown --' Stimulate X Plugging -7 Perforate -- Pull tubing - Alter Casing Other 2. Name of Operator ARCO Alaska_. I. ne. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 137' N & 915' E of SW Cr. Sec. 1, TllN, R14E, UM 5. Datum elevation (DF or KB) 48 ' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Welt number NGI-IO (22-1-11-14) At top of productive interval 1599' S & 1072' E of NW Cr. Sec. At effective depth At total depth 1123' S & 1186' E of NW Cr. Sec. 1, TllN, R14E, UM 1, TllN, R14E, UM 8. Approval number 7-604 9. APl number 50-- 029-20229 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth' measured 9990 true vertical 8555 feet Plugs (measured) feet Effective depth: measured 9904 feet Junk (measured) true vertical 8491 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 20" 240 Sx AS 80' 80' Intermediate 13-3/8" 4300 Sx PFII 2310' 2309' Production 9-5/8" 750 Sx 'G' 8815' 7659' Liner 7" 335 Sx 'G' 9986' 8552' Perforation depth: measured 9265-9293', 9310-9335', 9360-9380', 9434-9444', 9460-9492 9515-9540', 9564-9589', 9610-9644', 9676-9696', 9713-9748', 9799-9824' true vertical 8091-8106' 8147-8155' 8167-8191' 8209-8228' 8244-8263 8278-8303', 8325-8339', 8351-8376', 8412-8430' Tubing (size, grade and measured depth) 5", 17#, L-80, PC tubing @ 8395', 7", 29#, L-80 PC tubing @ 8350' Packers and SSSV(type and measured depth) Baker FB-1 packer @ 8386' MD, Otis RPD SSSV @ 2173' 12. Stimulation orcementsqueeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure -- 79,000 .... -- 104,000 .... Tubing Pressure 14. Attachments Daily Report of Well Operations .,~ Copies of Logs and Surveys Run ,%__ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Signed ~~~~~~j Title Operations Engineering Manager Form 10-404 Rev. 12-1-85 WELLS/126 T. P. Allen, ATO-1516, 263-4837 Submit in Duplicate NGI-10 DESCRIPTION OF WORK PERFORMED Xylene/water wash treatment Objective: To increase gas injection into Zone 4. Date Performed: 10/1/87 1. MIRU pump truck and transports. 2. Pumped the following liquids: a. 50 bbls of 165° F diesel @ 2 BPM b. 60 bbls of xylene @ 1 BPM c. 50 bbls of 100° F diesel @ 2 BPM d. 487 bbls of 145° F water @ 4 BPM e. 24 bbls methanol 3. Allowed to soak for six hours. 4. Put well on gas injection. WELLS/126 ARCO Alaska, In( Prudhoe Ba.z Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 16, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: NGI-10 Permit No. 76-69 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp At tachment cc: Standard Alaska Production Company P1 (NGI-10)W1-3 Nask~ 0~t & Gas Cons. C0 Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompa.y AR3B--6132-C STATE OF ALASKA ALA~.~,A OIL AND GAS CONSERVATION CO,._~.~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon '~ Suspend ~ Operation Shutdown ~% Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate C Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well atsurface 137' N & 915' E of SW Cr. Sec. 1, TllN, R14E, UM At top of productive interval 1599' S & 1072' E of NW Cr. Sec. 1, TllN, R14E, UM At effective depth At total depth 1123' S & 1186' E of NW Cr. Sec. 1, TiIN, R14E, UM 5. Datum elevation (DF or KB) 48 ' RK]3 feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-10 (22-1-11-14) 8. Permit number 76-69 9. APl number 50-- 029-20229 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical 9990 feet 8555 feet Plugs (measured) Effective depth: measured 9904 feet Junk (measured) true vertical 8491 feet Casing Length Size Cemented Conductor 20" 240 Sx AS Intermediate 13-3/8" 4300 Sx PFII Production 9-5/8" 750 Sx 'G' Liner 7" 335 Sx 'G' Measured depth True Vertical depth 80' 80' 2310' 2309' 8815' 7659' 9986' 8552' Perforation depth: measured 9515-9540' 9564-9589' 9610-9644' 9676-9696' 9713-9748' 9799-9824' , , , , { true vertical 8091-8106' 8147-8155' 8167-819 ' 8209-8228' , , , 8278-8303', 8325-8339', 8351-8376', 8412-8430' Tubihg '(size, grade and measured depth) 5", 17#, L-80, PC tubing @ 8395', 7", 29#, L-80 PC tubing @ 8350' Packers and SSSV (type and measured depth) Baker FB-1 packer @ 8~86' MD, Otis RPD SSSV 0 2173' 12.Attachments 9265-9293' 9310-9335' 9360-9380' 9434-9444' 9460-9492' , , , , , Description summary of proposal [] Detailed operations program 13. Estimated date for commencing operation October 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~ertify that the~oreg.oing is true and correct to the best of my knowledge Signed ~//~;,,~¢ jpd{//~.a.~- Title . Opcratzons .~_~in~ring l.~anag~r Commission Use Only Conditions of approval Notify commission so representative may witness Approval No. ~ Plug integrity ~ BOP Test Fq Location clearanceI Approved by Date Commissioner by order of the commission Date WELLS/126 T. P. Allen, ATO-1516, 263-4837 Form 10-403 Rev 12-1-85 Submit in triplicate NGI-10 XYLENE/WATER WASH TREATMENT ARCO Alaska, Inc. intends to perform a xylene/water wash treatment on NGI-10. The treatment will be pumped as follows: 1. MIRU pump truck and transports. 2. Pump the following fluids: 50 bbls of hot diesel (170° F) 60 bbls of xylene 50 bbls of hot diesel (170° F) 500 bbls of 150° F water with 84 gals of surfactant (LoSurf 300, F75N or NE-18) 20 bbls of methanol Note: Reduce pump rate to 1 BPM after 300 bbls of fluid are pumped to increase contact time with xylene and hot diesel in the tubing tail and wellbore regions. After all xylene and hot diesel is in formation, increase rate (after 500 bbls). 3. Allow well to soak for 6 hours before injecting gas. 4. Obtain injection capacity. 5. MIRU wireline unit. Make tag run. 1 WELL S / 125 3 I I 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF W I REL I NE BOP EOU I PMENT STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO,~ISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL E~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-69 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20229 4. Location of Well Surface: 137' NSL, 915' EWL, Sec. 1, T11N, R14E, UN 9. Unit or Lease Name Prudhoe Bay Unit BHL.' 1123' SNL, 1186' EWL, Sec. 1~i T11N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 48 ' RKB 6. Lease Designation and Serial No. ADL 28302 10. Well Number NGI #10 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 12. (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stim u late [] Abandon [] St im u lation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [~])( Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accept rig at 0400 03/14/83. Pull BPV. NU WL BOPE and lub. Attempt to pull MBR valve w/o success. RIH & perf tubing above packer. Circ well. ND WL BOPs & lub. Set BPV. ND tree, NU BOPE & tst. Pull & stand back 3-1/2" DP. PU BPV. Pull & L[~7" tbg. RIH w/fishing assy, recovered junk. MU seal assy on DP. RIH & tst pkr & csg to 2000#. Ran 7" 29# 8~d tbg to SSSV & 7" 26# IJ4S tbg to surf. Pull 7" tbg, LD sliding sleeve. Rerun 7" tbg & land. Set BPV. ND BOPE. NU tree. Pull BPV. Set injection valve in nipple. Set BPV. Release rig @ 1200 hrs 03/23/83. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Title A~'ea Drillin~ Fn~in~.~.r' The space below for Commission use Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 CSM/SN2 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate · _, STATE OF ALASKA ' ALASKA O,. ,.AND GAS CONSERVATION CON.~ISSION MONTHLY REPORT oF DRILLING AND WORKOVER OPERATIONSy , 1. Drilling well [] Workover operation 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of Well at surface 137'N & 915'E of SWCR Sec 1, TllN, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 48' RKB ADL 28302 7. Permit No. 76-69 8. APl Number ~0-029-20229 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. NGI #10 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool For the Month of. March ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accept rig at 0400 3-14-83, could not pull MBR valve, ~erf tbg above ~kr. Pull 3 1/2" tbg. Pull 7" tbg. Fished for & recovered jnk. Ran 7" 29# 8rd tbg to SSSV & 7" 26# IJ4S tbg to surf. Pull 7" tbg, rerun 7" & land. Release riA @ 1200 hrs 3-23-83. 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description N/A 15. Logs run and depth where run CCL - 8400 - 8150' 16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~~ TITLE Area T'h-~ 11 ~.~r W.n¢~ o o neer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 NGI #10 Drilling History Accept rig at 0400 03/14/83. Pull BPV. NU WL BOPE and lub. Attempt to pull MBR valve w/o success. RIH & perf tubing above packer. Circ well. ND WL BOPs & lub. Set BPV. ND tree, NU BOPE & tst. Pull & stand back 3-1/2" DP. PU BPV. Pull & LD 7" tbg. RIH w/fishing assy, recovered junk. MU seal assy on DP. RIH & tst pkr & csg to 2000#. Ran 7" 29# 8rd tbg to SSSV & 7" 26# IJ4S tbg to surf. Pull 7" tbg, ~. Rerun 7" tbg & land. Set BPV. ND BOPE. NU tree. Pull BPV. Set injection valve in nipple. Set BPV. Release rig @ 1200 hrs 03/23/83. CSM/DH9'I lm 04/14/83 ARCO Alaska, Inc. Post Office ~..~--3~;3 Anchora§e, A!~ska 995I(;1 Telephone 907 277 5637' January 24, 1983 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' NGI-IO Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose repairing this well by eliminating communication to the tubing annulus. Since we estimate starting this work on February 1, 1983, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JGL31'sm Enclosures ,,,~r:('~ ,*',i~:~k;~ ih{: i:; ~ ¢:l~'h:;idiafy of Atlantic~qichfieldCompany STATE OF ALASKA ALASKAO1L AND GAS CONSERVATION CG,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL F~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-69 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20229 4. Location of Well Surface: 137'N & 915'E of 5W CR Sec. 1, T11N, R14E, UH Bottomhole: 1123'5 & 1186'E of NW CR Sec. i, T11N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) /+8 ' RKB 12. 6. Lease Designation and Serial No. ADL 28302 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number NGI #10 11. Field and Pool Prudhoe Bay Fie]d Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [~X Change Plans [] Repairs Made [] Other [] Pull Tubing [~]X Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to repair this well by eliminating communication to the tubing annulus. The 7" tubing will be pulled and the 9-5/8" casing will be tested and repaired as necessary. A new 7" completion assy will be ran with all necessary subsurface safety equipment. A 13-5/8", 5000 psi, RSRRA BOP stack will be used on well work performed by the workover rig. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be ]eft in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Approximate start date: February 1, 1983 Alaska Oil & Gas Anchorage 14. I hereby_~certify that~t~e foregoing is true and correct to the best of my knowledge. Signed ~' /' "- '%, ~'~'"~~ Title Area Dri 11 ing Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER Approv¢~ Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 GRU1/SN29 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Oliicll~x 3~0 Anchor ,Alaska 99510 hone 907 277 5(537 July 13, 1979 Reference' Enclosed are final R¥ints for the following ARCO cased-hole well~ .... :.I.~ ,. _ ¥'I1.i:: ,, ............. ~ D.S.. 1-13 ... ~'1 Spacing Thema'l Neutron Decay~T~e .... 1/23/7~.-~--5 ~/~ ";"-' :~ .... . "t' ~'-'~' .... o"': "~,l' / / ~ ~ ' D.S. 14-5 ~couStic Cement Bond Log ~L ~ '. 2/20/79 5,,' D.S. 14-2 /~erforation Collar Log ' 3/9/79 5 D.S. 1-18 ¢~ie In Log For ~wer Baker Packer 5/2/78 5;; Run 1 D.S. 3-8 ~-luid Density ' 2/12/79 5 Run D.S..-5~8 .....%-Spi~er Flo~neter ....... : ........ : ..... : ..................... 1--19/21~79. 5" .S. 13 2 ~Col.~z ~g ........... 2/~n/va- c,, / Please sign and return ~he attaC]~ed copy as reCeip~ of data. VeO, truly yours, R. A. Bellinger TI~NSMITTAL # 215 DISTRIB[fI'ION North Geology · Dri 1 ]. ing Eng. Manager R&D Geology State o~ Alaska I) & lXl Mobil. Get ty Sohio MarathOn Phil 1. ips Chevron ,:;~t~:~ r,ticRichfiMd Company North Amerir. an Producin§ Di¥ision North A~as ~istrict Post Office Bo× 360 Anchorage, Alaska 99510 'Telephone 907 277 5637 April 10, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' NGI #10, Permit No. 76-69 Dear Sir' Enclosed please find a Completion Report along with the Acidizing History for the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV' cs Attachment ~?~* SUBMIT IN DU.~,-~iCATE* STATE OF ALASKA '~ (Seeotherln- st ructions on OIL AND GAS CONSERVATION COA4/~ITTEE reve,,s~ s~e~ I WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: b. TYPE OF COMPLETION: .~Ew [] wonK [ WEI, L ()','ER OU,,,.ELL []]] 'CASw£LL [~ DRY[]] Other Gas Injection ' Acidize BACK nESVR, r EN 2. NAbIE OF OPKRATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. L0C^r~0X Or WELL (Report location clearly and in accordance with any State requirements)* At surface 137'N a 915'E of SW cr Sec. l, TI IN, RI4E, UM t~o~ pro~. ~n~l. reported below E of NW cr Sec. 1, TllN, R14E, UM At total depth l123'S a l186'E of NW cr Sec. l, TllN, R14E, UM 5. API NLrlVZE~CAL CODE 50-029-20229 LF_~E DI~GNA[IXON A/NID SERIAL NO. ADL 28302 7. IF INDIA.N, AJ-,LOTTEE OR TRIBE NA1VIE 8. UNIT,FAtT1Vi OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #10 (22-1-11-14) 10. FIELD AJqD POOL, OR WILDCAT p.,,~hn~Prudh°eni~BaPnolFie]d/ :~i.'SEC¥~:,-R~, Mi, (BOTTOM HOLE OBJECTIVE) Sec. l, TllN, R14E, UM 12. P~'R1VIIT NO. 76-69 9990'MD, 8555'TVD/9904'MD, 8491'TV ~ow~¥* , ~O~^R~OO=,~ ...... [.:. . .- Sinqle ~ AT~ ..... i~ :' ~ ' ~" None 22. PRODUCING INTERVAL(S), OF ~IS COMP~TIO~--~P, BO~OM, ~E (~ AND )* ~ . ' ~ ~{23.'WAS DIRE~O.NAL ~ SURVEY MADE Top Sadlerochit .9258'MD 8011'TVD ..... ~ Yes Base Sadlerochit 9895'MD 8484'TVD j 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/FDC/GR/BHCS/Calipor, GR/CCL, GR/CNL/CCL ! CASING RECORD (Report all strings set in well) CASING SIZE I WEIGHT, LB/FT. 20" 194#-Vetc° 13-3/8" 72#-Butt 9-5/8" 47#-Butt 9799'-9809' 9713'-9748' 9676'-9696' r GI::L~DE [ D~PTI-I SET (MD) [ HOLE SIZE [ ¢~,,,*~NTI~G RECOI{D a-40 '[80' be]' ~ad] 32" 240 sx Arcticset cmt MN-80| 2315' ! ]7-]/2"[4300 sx PF II cmt MN-80&[ 88]5' ] ]2-]/4"[750 sx Class 6 cmt soo-951 i I 26. LINER R.EC Ol%D SIZt~ t TOP (I%~D) [ BOTTOM (MD) [SACKS C]!IA<[EZNTT* -? [ 8523' [ 9~86' IL Class 335 GSX 28. PERFORATIONS OPF2N TO PRODUCTION (Interval, size and number) 98]8-'9824' 9610'-9644' 9360'-9380' 93] 0' -9336' 9265'-9295' iA~MOUlqTT PULLEq) 9560' -9589' 9513'-9540' 9460' -9492' 9404' -9444' 30. ,, w/4 shots per ft. I i I ii PRODUCTION I 27. SCRF-.I~N (MD) SIZE 7" TUBING RECOP,,D SET (RD) P.ci~ER SET (MD) 8387' , i 8386' 29. ACID, SHOT, Fi%A~C'I'LrRE, CF.M[E:NT SQUEEZE, ETC. DI~'~TTI INT~IRVA.L (MD) [ AMOUN'i~ £~ND KIND OF 1ViAT~ER/AL USED 9824'-gZbb'[2300 bbls 10% HC1 DATE FIRST PiIODUCTiON [ PT~ODUCTION MEiHOD (Flowh~g, gas lift, pumping--size and type of pump) [WELL STATUS (Producing or anut-in) N/A · [ Injection Oct. 1977I 24 I N/A[l~s'~~?. 1' 0 1' MSCF/D"U'UUU I' 0 It N/A f~:~f p,~::]CASING PRESSURE [CAL~~ OI~BBL. GA~.~ WA~BBL. lOI~ GRAVITY-~I (CO~.) '"~ ....... i [~-~og~ ~= , I IU, UU · 4300 psi J I = [ 0 I MSC¢,~D J 0 J N/A J TEST WITNESSED BY Re~ njected Production 0pecat~on 32. LIST OF ATTACHMENTS Ac~d~z~n9 H~story 3~. I hereby certify that the foregoing and attached information is complete and correct as determined from all:available records SIGNED ...... TITLE District Drilling Engineer DATE ·(See [m~cfio~s ~ S~ce~ [o~ Addi~io~[ 0~ o~ Re,erse Side) 4/6/79 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in ether spaces on this form and in any attarhmer~ts Items 20, and 22:: If this well is completed for separatc [)reduction fror'q more than one ~nterval zone (multiple completion), so state ~n item 20. and in ~te'~ 22 show the prc:]L.,c~r~.Cl interval, or Jr~te, vals, top(s), bottom(s) and name (s) (if any) for only the interv.~J ref~orted ir~ item 30 Submit a sep:~rate report (page) on this form, adequately identified, for each additional ir~te~val to be separately produce4, show- ing the ac:kJitional d~ta pert~nent to such ~nterval. _ Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ~ --., SUMM'A~'Y ()Iv IVORMATION TES'I"S IN('LUI)INt;"'INTEI'~VAL TESS'FED. /;{~E~St;'RE DATA ~COVERI~ OF OIL GAS. 35. G~G IC ~ARK~ WAT~ AND MUD None ............ lop Sa~ R~ver 9170' 7942' lop Shub] ~k 9220' 7981 ' lop Sad]eroch~t 9258' 8011' Base Sadl eroch~t 9895' 8484' i i '~ i '1' ir"i'l '1 J .... T J rll Illllll Illlilill II aN~ ~'[~'TE1) ~II'O:WS 0~. O'l'k, GAS' O.R None , ,, , .......... , ........ , NGI #1 0 Acidizing History API 50-029-20229, ADL 28302, Permit No. 76-69 Rigged Up Acidizing Eq..uipment 3/22/79 Stage #1 ~1200 bbl i0% HC1 followed by 25 bbls Wtr - final rate 8 BPM @ 2000'psi Stage #2 Stage #3 Stage 100 bbl 10% HC1 w/diverter balls (1 ball/bbl) followed by 25 bbls wtr - final rate 8 BPM @.2050 psi 100 bbl 10% HC1 w/diVerter balls (1 ball/bbl) followed by 25 bbl wtr- final rate 8 BPM @ 1700 psi 100 bbl 10% HC1 w/diverter balls.(1 ball/bbl) fOllowed by 25 bbls wtr - final rate 8 BPM @ 2100 psi Stage #5 100 bbl 10% HCl w/diverter balls (1 ball/bbl) followed by 25 bbls wtr - final rate 8 BPM @ 2100 psi Stage #6 100 bbl 10% HCl w/diverter balls (1 ball/bbl) followed by 25 bbls wtr - final rate 8 BPM @ 2100 psi~ Stage #7 100 bbl 10% HC1 w/diverter balls (1 ball/bbl) followed by 25 bbls wtr - final rate 8 BPM @' 9QO psi Stage #8 lO0 bbl 10% HC1 w/diverter balls (l ball/bbl) followed by 25 bbls wtr - final rate 8 BPM @ 2100 psi Stage #9 Stage #1 0 100 bbl 10% HC1 w/diverter balls (1 ball/bbl) followed by 25 bbls wtr - final rate 8 BPM @ 2050 psi 100 bbl 10% HCl w/diVerter balls (1 ball/bbl) followed by 25 bbls wtr - final rate 8 BPM @ 2000 psi Stage #11 100 bbl 10% HC1 w/diverter balls (1 ball/bbl) followed by 25 bbls wtr - final rate 8 BPM @ 1900 psi Stage #1 2 100 bbl 10% HC1. Pumped 417 bbl disp @ ll BPM @ 2500 psi Shut down to allow balls to fall off perfs. Reinjected gas to displ fluids in tbg. SI well. Backflowed well to release any balls remaining on perfs. Put well on injection & released to Production Dept 3/28/79. ]979 ]:,nc]osed are tho £ollowinS Arco Cased "*'~,-~,d:.,~ Loss' ]) S t/14.-4 Casing Co21ar T n~ D.S. //13-2 Cement Bond LoS CasS. n~ Col'lar Log it 11 N(;J //10 Temperature LoS 5" PI. ease sign and -rc(t~r:t m~d attached cop>' of the enclosed transmittal as receipt of data. Very truly ),ours, R. A. Ilamlin North Operations Engineering Transntittal fi145 k H~'~t,'cR~chhe~dCompa ny North American Producing Divisio~ North A]~ )istrict Post Offi~e~ ~× 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 5, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #10, Permit No. 76-69 Dear Mr. Hamilton' Enclosed find our Sundry Notice of Subsequent Report and Completion Report detailing the work done on the above- mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV- cs Enclosures FILE: Form 10-403 REV. 1-10~73 Submit "Intentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to ~Jrlll or to deepen Use "APPLICATION FOR PERMIT--" for ~uch proposals,) 5. APl NUMERICAL CODE 50-029-20229 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 °w~Ln'lWELL''GAS I'"! OTHER Gas Injection 7. NAMEOFOPERATOR 8. Atlantic Richfield Company ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 137'N & 915'E of SW cr Sec l, TllN, R14E, UM IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #10 10. FIELD AND F~)OL, OR WI.LDCAT Prudhoe Bay Field-Prudhoe 0il R14E, UM 13. ELEVATIONS (Show whether DF, RT, QR, at~.) 12. PERMIT NO. 18.4 Pad Level 76-69 14. Check Appropriate Box To Indicate Nature of Notice, Re )orr, or Other Data Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 1, TllN, NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* ' ' REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) (NOTEI Report results of multiple completion on Well Completion or Recomplatlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent gletlll~, an~l give pertinent elates; Including estimated date of starting any I:fl, oposed work. See attached sheet RECE VE D 16.SIGNEDI hereby certlfy.~that t~~rrect (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE District Drilling Engineer DATE TITLE DATE See Instructions On Rever~ Side ~-~ SUBMIT iN D~JI~LICATE* STATE OF ALASKA ~, (See other in- structions on OIL AND GAS CONSERVATION COMMITTEE rev~,-s~ sme~ WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ~, TYr~. or wren: O,',,,.ELL []]] ~ASWELL Eli DR~ El] oth;er"Gas Injection b. TYPE OF COMPLETION: NEW ~ WORK [-~1 DEEP-[---] PLUG F--'] DIFF.['--] W E I, I, OV ER E N BACK RESVR. Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESSOF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOC^TmN Or WELL (Report location clearly and in accordance with any State requirements)* At surface 137'N & 915'E of SW cc Sec. l, TllN, RI4E, UM t~ pro~. interval reported below 1072'E of NW cr Sec. l, TllN, RI4E, OM At total depth 1123'S & l186'E of NW cr Sec. l, TllN, RI4E, UM 5. API NIINLEltICAL CODE 50-029-20229 6. ~E. ASE DESIGNA~ON AND SER~L NO. ADL 28302 7. IF INDIA.N, ALLOTTEE OR TRIBE NA. NLE 8. UNIT,F~RM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #10 (22-1-11-14) 10. FLELD AaND POOL, OR WILDCAT Prudhoep~,,rlhnm c)~BaPnnlFi el d/ n. 'SEC:,-~.;-R7, MT, -(BOTTOM OBJECTIVE) Sec. l, TllN, R14E, UM ~12. PER,MIT N'O. 76-69 INTERVALS DRILLED BY HOWMANY* ROTARY TOOLS ' CABLE TOOLS 9990'MD, 8555'TVD [9904'MD, 8491'TVD [ Single All None 22. PRODUCING INTERVAL(S), OF THIS. COMPLETIOiNT--'I~P, BO'I~OM, NAME (MD AND 'IW'D)* 23.WAS DIRECTIONAL Top Sadlerochit 9258'MD 8011'TVD ~ ~URVE¥~ADE Base Sadlerochit 9895'MD 8484'TVD ! Yes ,i 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/FDC/GR/BHCS/Caliper, GR/CCL, GR/CNL/CCL 25. CASING RECORD (Report all strings set in w~ll) 20" 94#-VetcO! H-40 /80' bel pad 240 sx Arcticset cmt 13-3/8" 72#-Butt [ MN-80! 2310' 9-,5/8" 47#-Butt ~ MN-80[ 881~' |&s00-9[ i A~M OI/N-T PULLED 1~-1/2"14300 sx PF II cmt 1 !/4"t 750 sx Class G cmt t27. FUBING RECOPy') SCREEN (MD) SIZE DEPTI-I SET (MD) [ PACIfiER SET (MD) 29. 'ACID,-it OT, ~ C '-' ij CF2~IENT. SQUEEZE ETC. 26. LINER R~E C OI-LI) SIZE [ TOP(MD) I BOTTO5 (MD) SACt(S CE%~ENT* Class G , 9818'-9824' 9610'-9644' 9'J60 ' - 9799'-9809' 9560'-9589' 9310'-9336' 9713' -9748' 9513'-9540' 9265'-92951 N/A 9676'-9696' 9460'-9492' 9404'-9444' w/4 shots per ft. i pump~g--size and type of pump) "' [WELL sTATUs (Producer or DATE FH~ST Pi~ODUCTION [ ~ODUCTION MEtIiO'D (Ftowh]g, gas 1itl t Injection ] N/A DATE OF T~ST. IHOURS TEST~ I~tOXE SIZE [PROD'N FOR OI~BBL. "~A~CF. WATE~BBL. I GAS-OIL R,%TIO Oct. 1977 ~=~ I N/A I ~' 0 ~!~g~O ,l 0 ,I N/A T~q~~~ I ~ G ~ SSU~ICAL~~ OI~BBL. G~[{C~.__ 'WATt--BBL. IOILGRAVITY-~I(CO~.) I N/A J TEST WITNESSgD BY Rei njected Production 0peration 32. LIST OF ATTACHMENT8 SIGNED TITLE District Drilling Engineer i i *(See ~ 'uctions and Spaces [or AdditiOnal Data on" verse Side) INSTRUCTIONS General: This form is designed for submitting a complete arid correct v,..ell completion report er'~d log or'~ all types of lands and leases in Alaska. Item: 16: indicate which elevation is used as reference (whe, e riot otherwise show'r~) for depth measure- ments given ~n ether spaces on this form and in a~'~y att,~J.-'!,:t~e:-~ls Items 20, and 22:: If this well is completed for separc~tc prcc]uction fror~-~ ~'~orc, than or~e i~terval zone (multiple completion), so state ~n item 20, and ~r~ ~tem '22 show the prcJc, c~r~Cl interval, or ~nte~'vals, top(s), bottom(s) and name (s) (if any) for only the interv.~! re~orted ir~ item 30 Submit a sep3rate report (page) on this form, adecl.,~ately identified, for each additior~'~t interval to be separately prodt~ce:"l, show- ing the acf'ditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. · Item 28: Submit a separate completion report on this form for each ~nterval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAHY ()1,' I,'O~.M'ATI(_)N TEST.'4 1N('I.UI)IN(; IN'I'EI{VAL TF~q'F;;I'). |)t{E.'-;-SUHE DATA A_N'D REC'OVEI{IF~N ()F ()IL GAS. 35 {.3 IX)LOG I C' M A R ~]E~L~ WATIe~I~ AND MUD _ Top $~ RSvec 9170' 7~4~' Top Shub]Sk ~220' 7~8] ' Top Sod]ecochS¢ ~258' 801]' Bose Sod]ecochS¢ 98~5' 8484' , ~o~ ~ ~ ,, , ,,, ,r ' ', ', [ , .;., a, .,' . ,, ,, NGI #10 Workover Began WO @ 0600 hrs 1/3/79. ND tree. NU BOP. Unseated tbg hgr & pulled PBR out of barrel. Pulled & LD 7" tbg. RIH w/fishing tools & engaged fish. Rotate off K anchor @ 8304'. Rec outer barrel of PBR. 2 pups & K anchor. Milled out pkr. POH w/pkr & tbg tail. Tstd FO's. RIH w/bit & scraper. CO fill. Wash & rotate down to 9904'. Ran 6" gauge ring & junk bskt to 9893'. Ran & set drillable retainer @ 9255'. Ran 8-1/2" gauge ring & junk bskt to 8523'. Set BP @ 1998'. Tstd OK. Chgd out tbg spool. NU & tstd BOP. Pulled BP. Drld retainer @ 9255'. Displ hole w/lO.8 CaC12. RIH w/7" RTTS & set @ 8660'. Press tstd csg to 3000 psi. Bled back to 2290 psi. Retstd, bled back to 2650 psi. RIH w/9-5/8" RTTS & set @ 8475'. Att to press tst csg. Found leak in FO @ 2487'. Att to close FO. Wouldn't tst. Opened top FO @ 2361'. Att to pump thru w/o success. Closed top FO. Ran gauge ring & junk bskt. Set BP @ 9165'. Ran temp survey. RIH & opened top FO. Could not breakdown. Closed FO. Opened lower FO. Unable to break down. Closed FO. Opened both FO. Circ out bottom FO thru top until returns clean. Closed both FO's. Press tstd w/RTTS. Top FO holding, bottom FO leak- ing. Opened both FO's. Set pkr @ 2471'. Cmtd ann w/60 sx Permafrost C cmt. Closed FO's. Chgd over to 10.8 ppg Dril-S. RIH w/RTTS & set @ 2604'. Press tstd csg to 3125 psi. Bled off to 2725 psi. RIH w/6" bit. Found BP @ 9162', drld out. Pulled up to top of lnr @ 8523'. Displ Dril-S w/lO.8 ppg CaC12. Ran gauge ring & junk bskt. RU & ran 7" tbg w/shear sub @ 8432', pkr @ 8412'. Pulled dummy valve. Ran SSSV & BPV. RU & tstd tree. Displ tbg w/diesel. Dropped ball to set pkr. Pkr didn't set. Att to pull SSSV but WL parted. Left 1000' WL in hole. Fished out WL. Killed well w/lO.8 ppg CaC12. Ran dummy gun/CCL. Displ tbg w/diesel. Att to set pkr. No go. Jar out of shear sub. Tools parted @ top of oil jars, left in hole. RIH & rec fish. Set BPV. ND tree. NU BOP. Rec SSSV. Lost 30 bbls to form. Pumped down tbg w/lO0 bbls 10.8 ppg CaCl2 pill w/20 ppg Dril-S & 20 ppg Safe-seal X. Displ to form w/lO.8 ppg Dril-S pill. RIH & set dummy valve. LD 108 jts 7" tbg. Pkr hung up in FO @ 2461'. Att to free w/o success. Sheared off pkr & POH w/tbg. RIH w/fishing tools. Spear pkr in FO. Jar free. Closed & tstd FO's. DisPl Dril-S w/clean 10.8 ppg CaC12. RIH w/RTTS & set below FO's. Tstd csg. Ran CCL/dummy gun. Found fill @ 9856'. Ran gauge ring & junk bskt to top of lnr. Ran 7" compl assy set @ 8387' & pkr @ 8386'. Press tstd control lines. Pulled dummy valve. Ran dummy gun w/CCL. Ran & set SSSV. Installed BPV. ND BOP. Installed & tstd tree. Pulled BPV. Displ tbg w/diesel Released rig @ 0600 hrs 2/3/79. ' ~,~..~rl~l ~,~:~ql'ican Producing r'~orth Al~sk~ Dish'ic~ Post Offic ~x 360 Anchorage,~laska 995'10 Telephone 907 2775G37 January 31, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 7-9, Permit No. 78-76 DS 13-2, Permit No. 78-61 ._.~ Permit No. 78-64 '<, NGI #i~ Permit No 76-69 Dear Mr. Hamilton' Enclosed find a Monthly Report of Drilling operations for the above-ment, ioned wells. Very truly yours, P A. VanDusen District Drill ing Engineer PAV' cs Enclosure Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20229 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL [~ ~;AS [--] Gas Injection WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 9. WELL NO. 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WEl, l. 137'N & 91 5'E of SW cr Sec l, TllN, R14E, UM NGI #1 0 10. FIELD AND POOL, OR WILDCAT ~rudhoe Bay Field-Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. PERMIT NO. 76-69 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, cA~ING ANDi~CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS F1SHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIF'ICANT CHANGES IN ItOLE CONDITIONS. Report of Operations for the Month of January, 1979. Began WO @ 0600 hrs 1/3/79. ND tree. NU BOP. Unseated tbg hgr & pulled PBR out of barrel. Pulled & LD 7" tbg. RIH w/fishing tools & engaged fish. Rotate off K anchor @ 8304'. Rec outer barrel of PBR, 2 pups & K anchor. Milled out pkr. POH w/pkr & tbg tail. Tstd FO's. RIH w/bit & scraper. CO fill. Wash & rotate down to 9904'. Ran 6" gauge ring & junk bskt to 9893'. Ran & set drillable retainer @ 9255'. Ran 8-1/2" gauge ring & junk bskt to 8523'. Set BP @ 1998'. Tstd OK. Chgd out tbg spool. NU & tstd BOP. Pulled BP. Drld retainer @ 9255'. Displ hole w/lO.8 CaC12. RIH w/7" RTTS & set @ 8660'. Press tstd csg to 3000 psi. Bled back to 2290 psi. Retstd, bled back to 2650 psi. RIH w/9-5/8" RTTS & set @ 8475'. Att to press tst csg. Found leak in FO @ 2487'. Att to close FO. Wouldn't tst. Opened top FO @ 2361'. Att to pump thru w/o success. Closed top FO. Ran gauge ring & junk bskt. Set BP @ 9165'. Ran temp survey. RIH & opened top FO. Could not breakdown. Closed FO. Opened lower FO. Unable to break down. Closed FO. Opened both FO. Circ out bottom FO thru top until returns clean. Closed both FO's. Press tstd w/RTTS. Top FO holding, bottom FO leak- ing. Opened both FO's. Set pkr @ 2471'. Cmtd ann w/60 sx Permafrost C cmt. Closed FO's. Chgd over to 10.8 ppg Dril-S. RIH w/RTTS & set @ 2604'. Press tstd csg to 3125 psi. Bled off to 2725 psi. RIH w/6" bit. Found BP @ 9162', drld out. Pulled up to top of lnr @ 8523'. Displ Dril-S w/lO.8 ppg CaC12. Ran gauge ring & junk bskt. RU & ran 7" tbg w/shear sub @ 8432', pkr @ 8412'. Pulled dummy valve. Ran SSSV & BPV. RU & tstd tree. Displ tbg w/diesel. Dropped ball to set pkr. Pkr didn't set. Att to pull SSSV but WL parted. Left 1000' WL in hole. Fi shed out WL. Killed well w/lO.8 ppg CaC12. Ran dummy gun/CCL. Displ tbg w/diesel. Att to set pkr. No go. Jar out of shear sub. Tools parted @ top of oil jars, left in hole. RIH & rec fish. Set BPV. ND tree. NU BOP. Rec SSSV. Lost 30 bbls to form. Pumped down tbg w/lO0 bbls 10.8 ppg CaC12 pill w/20 ppg Dril-S & 20 ppg Safe-seal X. Displ to form w/lO.8 ppg Dril-S pill. RIH & set dummy valve. LD 108 jts 7" tbg. Pkr hung up in FO @ 2461'. Att to free w/o success. Sheared off pkr & POH w/tbg. RIH w/fishing tools. Spear pkr in FO. Jar free. Closed & tstd FO's. Displ Dril-S w/clean 10.8 ppg CaC12. RIH w/RTTS & set below FO's. Tstd csg. Ran CCL/dummy gun. Found fill @ 9856'. As of January 31, ran gauge ring & junk bskt to top of lnr. RIH w/tbg & pkr. the f egoing ' rue and correct 14. lhereby_~~t ~~ .~~ SIGNEI) T, ~. --- _~ T1TLFDistrict Drilling Eng. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 1§th of the succeeding month,unless otherwise directed. ThrU: ~/~SKA OIL ~D GAS OONSF3~3ATIO~-~ ~O~SSION Hoyle H. Hamilton ~issioner, Chairman Harold R. Hawkins Petroleum Ins~or January 8, 1979 ~ltness POP Test Arco }~I ~-7~. 10 vDrkove~r ~, January 2, 1979 - I left Anchorage by Alaska Airlines, Sohio BP charter to Prudhoe Bay at 3:45 ~. I arrived in Prudhoe Bay at 5:15 ~. Britt ~~, ~rco supervisor, set-ap Sohio BP charter for me so ~3nat I could witness NC~I-10 ROP test. He ~ght they would he ready tonight and Wien Air had no seats on their flight. ~hen I arrived on location nippling up BOP's was in pr ~ogress. ~lne~ay, January 3, 1979 - Ken Jones was supervisor for Arco. uusher on _~ig 35 %ms Ed r~phy. Testing of blind rams %~as first on this job. Blinds ~re on bottom, these ~_re tested, frc~ 1:00 ~ to 2:00 ~{. At 7:30 AM tests re~ on rest of BOP's. ADmular ureventer was t~ted to 3000 psi. ~ the upper pipe rams, inside kill valve and inside choke valve %~re tested to 5000 psi. ~qith upper pipe rams still closed, outside P~ll valve and~ outside choke (r{CR valve) ~=_re tested to 5000 psi. The ~ valve on P~ll line and six valves on manifold were tested separately to 5000 psi. The Swaco superchoke was tested last on manifold to 5000 psi. ~.~nere was a manual operated choke that ~)rked freely. ~ne lc~_r pipe rams were tested last on ~cack to 5000 psi. The ac~llator with all power off and closing annular preventer, two sets p'3~e rams and opening HCR valve., failed test. Pressure left was 1100 psi. The ac~z~ulator ~ottles ~re checked and the gauge ~ 960, 500, 750, 975, 700, 925, 500, 925, 500 and 950 psi each. Bach bottle w~s under 1000 required precharge ~ressure. I checked all lines for leaks, all seals on preventers for leaks and found none. The bac~3p nitrogen pressure in each bottle vms 2200, 2200, 2350, 2000 and 2350. ~nere also was a back up air supply, independent of th~ rig power hooked up to the accumulator. Powan pusher re~harged most bottles up to 1000 psi but ~ee nitrogen bladers were shot. These are to be replaced and_ Arco is to call m~ office when this is done. I felt that vRtb. ~%eir ~rg~n~3 bac~ps for the clo~e of ~ ~P's %~re satisfacto~, that it ~lld ~ safe for tb~ to ~ ~head ~ work on this %,~11 until tJ~y. could get to the point of F~atting a ~id~Ca~ plug in and shuttir~ the ~11 in kefore overhauling accumulator. Ken Jones, Arco su~r~rvisor, told me as soon as ~ ac~amulator ~ld ~ %Drk ~n in safety that this would be done. ~ ~ and lc~_r kelly ~re test~ last to 5000 psi. ?here ~as a dart ~~ and ~all valv~ on floor OK. The location %~as clean and free of debris, ~ mud pit ~ q~ bu% %~11 ~ermed. ~.l..~...w~.: I witnessed the BOP te~ for Arc~ on ~I ~. 10. All te~sts on POP's ~,~..re satisfactory with r~ failures ~th t~.e ~cepti~n of the 10 acc~nula~r l~ttles that failed. Attachment ~{:bjr 1/17/79 - I talked to Ken Jones, opera~ for ~. ~ pr~bl~ of ~tor bottles was the valv~ st~s ~. These ~ repla~ed' c~ 1/14/79 and the a~t~r bottles are pre~ ~ 100~i~I and Drlg. Permit No. Operator~ar/-¢ ~F' ~ Satisfactory Type Inspection Yes No Item (X) Location,General ( ) ¢¢() 1. Well Sign (~) ( ) 2. General Housekeeping (~() ( ) 3. Reserve Pit-(~Oopen( )filled (1~') ( ) 4. Rig ( ) Safety Valve Tests ( ) ( ) 5. Surface-No. Wells ( ) ( ) 6. Subsurface-No. Wells ( ) Well Test Data ( ) ( ) 7. Well Nos. , , , ( ) ( ) 8. Hrs. obser , , , ( ) ( ) 9:. BS&W , , , ( ) ( ) 10. Gr. Bbls. , , , ( ) Final Abandonment Al,,'-'4'a Oil and Gas Conservation Commi< :.e Field Inspection Report Wel 1/Platfm Sec T R Represented DY,~'/-¢)~'d~ Name & Number~/~ ~ _,J?~ /~ ..... - .... ~.. ~/¢,,¢ '~/,'.,¢","'-'t Satisfactory Type Inspection No Item (~ BOPE Tests Yes ~I () () () (~ () (~ () () I) () ~) () C~) () 15.&.~.'Cas i ng set 16 1-~st f/uid-(~wtr.---~-~ )mud ~) oil 17 Master Hyd. Control Sys.~psig 18. N? 19o R~mote C'ontroi's 20. Drilling spool- ~l/"outlets 21. Kill Line-(~') Check valve 22 Choke Flowline (l) HCR valve 23. Choke Manifold No. valvs~_~flg~;& 24 Chokes-(~)Remote(~)Pos. (~)'Adj. 25 Test Plug-( )~tellhd( )'cs.o( )none 26. Annular Preventer,9~r¢¢psig 27. B1 ind Rams d-"m¢ms i .q ( ) ( ) ll. P&A Marker (9() ( ) 28. Pipe Rams.tf'mm~psig ( ) ( ) 12. Water well-( )capped( )plugged (b() (,) 29. Kelly & Kelly-cockd'mmmpsi§ ( ) ( ) 13. Clean-up (~) ( ) 30. Lower Kelly valve~omo psig ( ) ( ) 14. Pad leveled ~~ (~) ( ) 31 Safety Floor valves-(~)BV (~)Dart Total inspection observation time ~~/d%ys Total number leaks and/or equip, failures/¢ cc' ~ W/~a ' ~otify in ~ 'aay~ or when .ready ~ Inspected by~~/~5 DateJ~ . -',hfie;dCompan¥ North Ameri- : Producing Division Alaska Re~. Post Office--J~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 13, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #10 Permit No. 76-69 FILE: Dear Sir- Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, L-~.o~Frank M. Brown :' District Drilling Engineer FMB: j h Enclosure F,~rm S'~b..'r,i: "Intentions" in Triplicate & "S..a.~eqaert~ l~epor~s" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COhVv~IT[EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not usc :h:.~ form l'oy .[ :J~zJ_---~ $ to al!il! or to devpen Ute 'Ar2-'~,C.k[ION FUR PEi>._MI'f-2-''' 'for such prot~osals.) ~:ELL ~ wELL __ OTH£R Gas Injection Well 2 N,-'../.!E C)f' OZ>'~Zq--kTC)R Atlantic Richfield Company 2 ADDi'.[SS C,F OPERA. TOR P. 0. Box 360, Anchorage, Alaska 99510 4, LOCATiuN OF WE. LL ^:_~=::-,_c~ 137'N & 915'E of SW cr Sec. 1, TllN, R14E, US At TD 1123'S & 1186'E of NW cr Sec. 1, TllN, R14E, UM !3. ELEVA'FIOXS :Sr. ow whether DF, RT. GR, etc. 18.4' Pad Level 14. Check ~F~riate Box To Indicate Nature of NOtice, Re 5. APl NU3,iF_.R2CAL CODE 50-029-20229 6. LF~kSE DESIGNATION AND SERI.kL NO. ADL 28302 7. IF IN~DL4~Nr. ALLOTTEE OR TRIBE NAx~LE 8. UNIT FARx%I OR LEASE NAME Prudhoe Bay Unit 9. ~,VELL NO. NGI #10 (22-01-11-14) 10. FLELD AND POOL, OR WILDCA. T Prudhoe Bay Fi el d-Prudhoe Oil OELIECTIVE~ Sec. 1, TllN, R14E, UM 12. PEtLMZIT NO. 76-69 ~ort, or Other Dat~ TEST WATER SHUT-OFlr ~ PULL OR ALTKR CA~ING FRACTURE T~EAT ){ULTiPL~ COMPLETE shoot o~ xc:~izr XX 2EPAIR %VgL~ XX' CHANG~ PLAY8 ' Other) SUBSI~'QUENTRI~PORI OP: WATER 8 It[ L'T-OFI? j__: ' REPAIRI.N'O WELL t ? FRACTURE TREATMENT i : ALTERING CASING [ SHOOTING 0R ACIDIZINO }- '~' ABANDONMEN'T* [ [~ (Other) ..... ~ __ ~ (Norz: Report result~ of multiple completiou on Well Completion or Reeompletlon Report and Log form.) Pool '..5 L,K.qrRIBE i'R,Tf~DSED OR C,.?~'.PLETED OPERATIONS /Clearly stare all pert!nent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to repair a downhole tubing leak in this well. A 13-5/8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and operationally tested each trip. A packer and string.of 7" 29# N-80 tubing with provisions for subsurface safety equipment will be rerun. A 5000 psi WP wireline lubricator, tested to working pressure will be utilized with all wireline work. The well will be backflowed to a burn pit to clean out workover fluid, acidized, and backflowed again to clean up. District Dri!!ing Engineer ~T~... (Th!i ipaee for Statg. oflSc~ use) TITLE See Instructions On Reverse Side APproved Returned ,:..;c, si,'.,a ;-tegioi: Posl Olfic3 '- ~ 360 Anti,ora:jo, ,~:ska 99510 Telephone 907 277 5637 Reference: Enclosed are the following logs: D.S. #4-9 Continuous Flow 5" D.S. #7-1 CBL/VDL D.S. #7-1 CNL/GR 5" D.S. #7-1 CNL 2" & 5" together · D.S. #1-4 Gamma Ray Neutron 5" Long Spacing D.S. #1-4 Gamma Ray Neutron 5" Short Spacing D.S. #3-5 Production Log 5" ~ Production Log 5" Run 2 NGI #10 Production Log ' 2" Run 1 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #447 AtlanticR[chfieldCompany North American Producing Division North Alask' ~'istrict Post Office ~.~. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 15, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subj ec t: NGI #2 Permit No. 75-52 NGI #4 Permit No. 75-69 NGI #7 Permit No. 76-38 NGI #9 ~ Permit No 76-68 Dear Sir: Enclosed please find a Completion Report for the abo~e- mentioned wells. Very truly yours, .,...~//, Frank M. Brown District Drilling Engineer FMB:lr Attachments SUBMIT IN DL~PF2CATE* STATE OF ALASKA (Seco(her st ructions on OIL AND GAS CONSERVATION COMMITTEE .... ~,.~ i i i i ii i i i WELL C©MPLETI©N ©R REC©MPLETI©N REP©RT la. TYPE OF WZI. g? m,, ~ 't, as ~ ,,.~:,.,. ,,'~L~ ~ ~ ~ Oth~ Gas Injection b. TYPE OF COMPLE~ON: w~:[.I, Z__J ,~VER ~ EN BACK gESVR. Other Perforated NAME OF t)PERATOP, Atlantic Rich .f.i~ld ADDRESS OF OPERATOR ....... P 0 Box ..60 Anphnwnoo_ Alfalfa 99510 4. Lo(',.'rm.x o~' w~:LL ~Report location C~arl~ and in accordance with any State requirements)* ;~tsllrfaco 137'N &915'E of S~ cr See. 1, TllN-Ri~E, ~ At t,~p prod. Interval reported below 1599'S & 1072'E of ~ cr Sec. 1, TllN-R14E, ~ At total dep~ 1:1. DA.'I'E .'5}'UI)DED 10-26-76 I-IOW 1VI2k~Y* ROTARY TOOLS 9990'ND, 8555'TVD 9904.'ND, 8491'TVD [ Single Ail 9.'). PP,.C)DUCING !NTEHVAL(S~. OF THIS CO~IPLETIO,lq'~TO,P. BOTTOM, NAME (MD AND TVD)* Top Sadlerochit 9258'MD 8011' TVD Base Sadlerochit 9895 ' ~) 8484 ' TVD 5. API N~CAL CODE 50-029-20229 6. LEASE DESIGNATION AIqD SERIAL NO. _ ABI, 28302 7. IF INDIA.N, 7kLLOTTEE OR TRIBE NAME 8. UNIT,FAiL1VI OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI {~10 (22-1-11-14) 10. FIELD A2~D POOL, OR WILDCAT Prudhoe Bay Field/Prudhoe ii. sec., T., R., M., (~OTTOm ~1 Pool OBJEC'FIVE) Sec.1. TllN-R14E,,UM 12. P~RiVIIT lq'o. 1123'S & 1186'E of NW cr Sec.1, TllN-R14E, UM 76-69 }14-DATE T.D. REACHED ! 15. DATE CO~iP SUSP OR, ABAN-D. i 16. E2L,EVATIONS (DF, RKB R,T, GR, ~TC)* p7. EL~V, CASINGHEAD 11-16-76 11-23-76 18' Gravel Pad,, ~ INTERVALS DRILLED BY I CABLE T00I, S None ,23. WAS DIRECTIONAL ! SURVEY 1VIA D E Yes 24. TY1)E EIAq('Ti:IC AND ()TILER LOGS RUN DIL / FDC/GR/BHCS / Ca~, iDer_, GR/CCL, GR/CNL/CCL ., 25. CASING RECORD (Repqrt all strings set in weld '9818'-9824' 9799'-9809' 9713'-9748' 9676'-9696' C/~S12~(_; SIZE WEIGI-IT, LB,'FT, l] ' GRADE ! DEPTH SET (MD) 20" 94#-Vetco H-40'i 80' be,1 pa, 13-3/8" 72#-Butt MN-80 ~2810' 9-5/8" 47#-Butt MN-80 ~8815 ' So0-gh' , 26 LIN ~<;{ R~CO~ } "'°P (>'m' { S°T~'°'"' ':m> ISACKS cmm>'r*7"[ 8523 ' I 9986 ' Class33} SMG 28' PEI't.F()RA"I 'I~NS' OPEN TO ~RODUC~I¢ON ' (interval, size and number) 9610'-9644' .'9360'-9380' ' 9560'-9589' 9310'-9336' 9513'-9540' 9265 '-9295',. "' 9460'-9492' I ~ 0" ' ,t9404'-9444' w/4 shots per ft. ao. PRODUCTION HOLEI SIZE 32" 17½" C'F~\ILNTING I%ECOPd) I £O,'TOUNT PULLED 240 sx Arcticset cmt 4300 sx PF II cmt 750 sx Class G cmt TUBING RE C. OP~D DEP~[X-I SET (MD) ~ PACKEI-t SET (MD) DATE F'It:5;'P [~I:ODUC'i'ION [ PIIODUCT1ON MEIHOD (Flowii;g, ga5 lif[, pumping--size and type of pump) WELL STATUS (Producing or an'aL-in) ...... [ In~ ection N/A 0ct_.~_977 _ .. I__ 24 I N/A I ~' I 0 ! MSCF/D 1, 0 N/A _ . ~ '' ]CAS, I. NG pRESSUE~ [CALC~TD OI~BBL. G ~ lVA~--BBL. OIL inject. Press [ [=4-aou~ ~T~ [ . ~0~00 4~0 n~ I , I ~ [ 0 I MSCF/D I 0 I N/A ~ - 3~, msP(~Svrmx or gas (,Sold, u~ed ]~r fuel vented, etc.) ' " WITNESSED BY ~o~n~o, ptod t Production Operation 32. LI8T OF AT~CHMENT8 :Lq. I heroby certify thlvt the ~Qregotng and attached information is complete and correct as determine~t from all-available records *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lan:Is and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure-~ ments given in cther spaces on this form and in any attachments. Items :20, and :22:: If this well is completed for separatc- production from more than one interval zone (multiple completion), so state ~n item 20, and in item 22 show the prcJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) fcr only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce,d, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUI)IN(; INTERVAL TF, STED. PHE,SSURE DATA A.N'D }LECOVERIF_,S OF OIL. GAS. 35. G ~OL,OG IC WAT~'I AND MUD NAM~ M~AS. D~'PTI{ ~U~ V£RT. Top Sag River 9170' 7942' Top Shublik 9220 ' 7981 Top Sadlerochit 9258 ' 8011 Base Sadlerochit 9895 ' 8484 3~. CO[I.E DATA, Aq'I'ACI! BRjfF' ~DF_~H'i'~.':i~i~k '~)F' LITitOLOG¥. POI~O~.~IT¥. F[tAeTUrtm.' APP,A~NT , ,ti,~nlicI:;:ict~fieluCompany North American Producia9 Division ~'d North Alask~ District Pos~ Of fie )x 300 Anchorage;~Mnska 995'10 .-~ ~x~Telephone 907 277 5637 ',k./. ' ' , ....' ~" ~'" .,, ~.June 26, 1978 ' ' k ,* , Reference' Enclosed are copies of the following cased hole logs' Differential Temperature Log D.S. #3-8 D.S. #4-9. Fluid Density D.S. I13-8 D.S'. #4-9 11 Collar Log D.S. #1-11. D,'S. ~t1-15 D.S. t~1-16 D.S. #1-17 D.S. #4-13 D.S. #4-15. Hydro Log 5" D.S. #3-8 Please sigm and return copy 'of trm~smittal as receipt of data. R.A. Logue North C~}erations Engineering Transmittal #371 Ati~r~tic~.~chfieidCompany North AmerP'an Producing Division North Alasi, istrict Post Office ~× 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 29, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' ~ Permit No. NGI #12, Permit No. Dear Sir: Enclosed please find a Sundry Notice outlining our plans for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAY:cs Enclosure Form 10-403 REV. 1-10.73 Submit "1 ntentlons" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--J' for such proposals.) Ow~LE]] GAs F-1 Gas Injection Well WELL L---J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At,,rface 137'N & 91 5'E of SW cr Sec. 1, TllN, R14E, UM At TD 1123'S & 1186'E of NW cr Sec. l, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4' Pad Level 14. Check Appropriate Box To Indicate Natura of Notice, Re 5. APl NUMERICAL CODE 50-029-20229 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #10 (22-01-11-14) 10, FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Po01 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. l, TllN, R14E, UM 12~ PERMIT NO. 76-69 )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and glve pertinent d&tes, including estimated date of starting any proposed work. The original Sundry Notice dated 9/19/78 specified a 7" 29# N-80 LT&C tubing string would be used to recomplete this well. It is proposed that 7" 29# N-80 LT&C tubing continue to be used below the safety valve nipple at +2200'; and that 7" 26# L-80 IJ4S tubing be used above the safety valve nipple. 16. I hereby certify that the foregoing Is true and correct T,TLE District iDrill in9 Eng. in_ee~_r_ DATE (This space for State office use) NDITION5 OF APPROVAL, If ANY-:-~ .... " I See Instructions On Reverse Side North Alaska District F~gineering TRANSMITTAL Date' July 28, 1977 Well Nane' J A. Rochon~gL~: .... '~" · ....'"' Ri' Jackson NGI #10 Transmitted herewith are the following for the subject well' Run No. Scale B!IC So.nic/Caliper Log N-lC Sonic/Caliper - Gamma Ray Log Bt-lC Sonic/Ganm~a Ray Log Caliper/CCL Cement Bond Log/gDI, Compensated Formation Density Log Compensated Neutron-Formation Densit), Compensated Neutron Log (;ore Analysis - Interval Core No. Core Description (SWC) - Interval. Core Description (Cony.) - Core No. Directional Survey- Gyro Single Shot ~ltishot Dr:i.].l Stem Test - Test No. llml Induction Laterolog Formation Dens:[ty Log Format:i.on ])ensity Log/gmmna Ray ga~nma R%,/CCL Laterolog Location Plat M:i. crolaterol, og Microlog Mucllog- Interval Samp].e Log (A.R. C6.') - Interv-al Synergetic Log TVD-])II, TVl)-Porosity Log .... l_ _ Ca_s.j-ng Collar Log_& Perforating Record S" · .. · ]~eceipt Acknowl.'edged For' Date: . / . ])]_ease return rece:i.pt to' At].m~ I~chfiel. d Con~)any Nort}~laska Engi~leering Manager P. O. Box 360 Anchorage, Alaska 99510 Xerox Sepia BL Line ea. ., / eal #532 AtlanticRichfieldCompany North Ar'--~ican Producing Division North A .... ~ District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 11, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject:~22-01-11-14) Permit No. 76-69 ~-~~T=I(24-31-11-15) Permit No. 76-62 PWDW 2-1 (42-33-11-15) Permit No. 76-63 Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Form ! 0-403 Submit "1 ntentions" in Triplicate REV. 1-10-73 -~ & "Subsequent Reports" In Duplicate .... . STATE OF ALASKA 01L AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELLLJ OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 137'N & 915'E of SW cr. Sec. 1, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18 ' Gravel Pad 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20229 6. L~SE DESIGNATION AND SERIAL ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME ?rudhoe Bay 9. WELL NO. NGI-10 (22-01-11-14) 10. FIELD AND POOL. OR WILDCAT Prudhoe Bay Pield - Prudhoe Oil P0ol 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 1123'S & 1186'E of NW cr Sec. 1, TllN, R14E, UM 12. PERMIT NO. 76-69 =ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL SUBSEQUENT REPORT OF: (Other) MULTIPLE COMPLETE FRACTURE TREATMENT ALTER lNG CASING ABANDON* SHOOTING OR AClDIZING ABANDONMENT* CHANGE PLANS (Other) Perforate (NOTEs Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent (letalls, and give pertinent dates, including estimated date of starting any proposed work. Began perf operations @ *0600 'hrS 6/10/77. Tstd tree, csg & wireline BOP's. Pulled dummy valve. Perf'd intervals 9818' - 9824' 9799' 9 ' , - 9824' 9728' - 9~_.9.7_~' , - 9728 ' 9676' - 9696' 9630' - 9644', ~610.' - 9630' 9564' , ................ , - 9589' 9515' - , .~460' - 9472' 9434' 9419' , 9540' 9472 -4492', · -..94.4~', - 9434', ~Q~4' - 9419' 9360' .... ....... . ~ , - 9380' 9310' , - 9335 ' · 9268' - 9293' w/4 shots per ft. Ran Amerada press bombs. Flowed well. Ran & set ball valve. Tstd balance & control lines to 5000 psi, OK. Bled press above ball valve to 0 psi, held OK. Installed& tstd tree cap to 5000 psi OK. Released well to Production Dept @ 2300 hrs 6/15/77. 16. I hereby certify_that the foregoing Is true and correct District Drilling Engineer TITLE -- DATE (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side 0'2-001B STATE of ALASKA TO.' J--- FROM: O. K. Gilbreth, Jr. Director Hoyle H. t~milton Chief Petroleum F~gi~eef '" Petroleum Inspect~)r . ;! DATE :July 7, 1977 SUBJECT: Witness Prover Calibratic~s at Pump Station }~. 1 and ~arface Control Subsurface Safety Valve for Arco ~ %10 ...Tue~/ay, June 14, 1977 - I left Anchor _age at 7:05 AM by an }l}~ska c~ Plane frc~ Era Helicc~ F~rvice and ~itnessed calibration of the prover at Pump Station }-k). 1 at Prudhoe Bay from 10:30 ~4 until 4:30 ~._~. I then went to drill site 9 where I am to witness BOP test. Kirk %~t~, supervisor for Arco, picked [~ up at 7: 30 ~4 and took rae to ~-~ #10 to witness a surface control subsurface safety valve . Tb/s valve wa~ tested before on 6/13/77 but the packing c~ balance side gave way. 5~e valve ~as pLtlled, ~ked and rerL~. ~n I arrived on location the tubing pressL_me was 3375 psi. The ~9C~¢ was open. The c~trol lines were tested, to 5000 psi and held ~OK,. The surface control m~surfaae safety valve was then closed and bled down frc~% 3375 psi to 1500 psi above SCSV. I observed this for one hour. There was no buikl up of p~sure, indicating the SCS~ did not leak. In sun~_ ~r~: I witmessed the calibration on the prover at Pump. Station ~. 1 and also witness~l the surface control subsurface safety, val%~ on NGI %10 ,At~t~aent f:jf' " 'l,i:'h"~:,i\':I,\,::~I~,::,!,,:I::"::~:},:i';::j\ I ',' I \ IT::'¡ &~!":' , !t~;' ) ~~, ,k'¡ ~' , , ,f, ".< .,,,,,,,""'i,,..1 l'" I ~" I I :;';,:!nrJ~g. I P~rmitNoò' J I I I -,' ~ ~1 ' 'Reþres~nted byl/I/?I<~/Í/,f~ 'I, '.' . " '- ---"'-- --:""'-'-"'-'-- -' "" ~"'Op~ra tbr~"r{J' , ""d', Name & ' Numbe r Iv' G I -PLI, It) I \ \, ! :::"SatisfactQry ."""...'" TY~~IrJ\~p~ctiQn ,'. '., SatisfactoY'¥ ". '.. Type Inspe~~ion ~!t" ¥es N'O"!'~'t~nt'!(~:;~':!!:-k(!tt~til;ort:';ije'ner'a~;"'Yes',. "". 'No, ,."Item (..,..' )'SOl'E,Tes'ts ¡~',';:,~ () (l'i!].W~l"l ~tg,~. ..,...,....',"" '. ",< () () 15,. . "Casing set>~, ""'.""""'.,...'....'", '.' ...".. ",'" '...,....' ;'" () (."...),;"",:::.~!.._N",:a;J;£:NøQ!sek;eepi;n"g ""'",""""...,......,," ',(,,')' () 16., Test fluid-(.,.J:wtf;;~k}U1Ud,~,'l'.P!ljl'i'~>~P' elf), '3.,Res~r,y:r~:- (, )open ( If'ill~d, ,f) '('.) 17. Master H,yd. .8?n~r?11~,.Y;~,:{,,,:,!.,~~ig, " , . ,'.' " ,',' ,S~f'et Va,lv~ T~s:ts " !'1y")"",J,,,J, 1!9.~,~m!q,t~lçlpn,trQl~"" ,.),',."""," ',' ,,," '.' ,,(,¡,.) , ( )', 5 . Surface-No .~lell s " ()(l 20 .Qr'ï1.}jng\~pooI:H?ut,1e~?, ' (Xl t) 6. Subsurface-NO.~Jells.x-+-t')' CO) 2.1~ Kill[inë-+C'),Gheckvalv~.,' '. ,,( ). Well Test Data .', J') t,) 22. , C,ho~eFlowl jnel'), HQRVal.v~, (')",:() 7. WelL Nps... . "~'" ." .. " .' '. '. C.J' (.J 23. Ç~?KeManifoldNo.vqlvs~lg$ ~ì~;,: (.,) , {J'. ',lO.Gr~'B~'J"~...,""'.,.,"'..""""'...' ~,'. ,.' """"" ,.,~ ,( ...~'(J, 26. At1r1ylar,,~revent~r,~sig , , r:,'" . ( ) final Abandon~ent ,', , () (..') 2,7. B 1 i nd Rams, ps i9 ~¡¡~J:"") () ,11. P,&A;Márk~,Y" ,,.',' (-.)., () 28. Pi pe Rams ,," ps ig , P-{', () () 12. Wate'rweT'l-( )capped{ )pluggéd () . ( ) 29. Kelly & Kelly-cock psig, \; () (l 13.C If:~ n"1fItJ .. .. .',. ,(.) ( )3ú . Lower Ke llyv a 1 ve (PSi 9 . . '.. ~~'iTòili~ .i~s~êt't;f~ri '1~ê~~~tti~~ù1~JàâyS'.;;t~~t¡Cnfátè;lì ê~k[e:~d5~~q~q~~ ~~e~;; d~~s'J;~?; i :<" . Remarks"~'~$;j.s.I/~ '7~jí¡'tJ'°I!A.&iþ:' 's..:FT~7~~" " 'TõR/A/C ,/,:.5 I ~ 3'?r ,;, ,I J" t:'J.A "~'J7EJ),&"£V'., ',' :", , ,',", V JV~ ..... " , ~J:r' l ¿A~;¡tj.ç .' A~/j.sri.i.i(/"¿JA:SJ>~ï.~!~¡9J.!:,;oAi:íf'J#J;A~/)J~1:'--1'-:?-¿'//~/?,-" ,.,,' :.: :"', ~-STWA'i-""'A7'~.L"''''~'i¡r;t",,,,,,,,,,,,,.:,...,,,;,.: "', ", ", '" "'," """",,;, Ii': cc:' ðil J.I./JlE-s '-,Notify in~',aýs':dr whente,a:d:JL.~--;~',i'~,nspected bY~Date~/.t:t?,1 ~~~"":~:':'~="'~:'~-~=::::::2~:~~'::::=~:~~:~~:='~::~::=::=:'~¡= 02-001B STATE of ALASKA n~P~ cF NA~JI~AL ~SCX]RCES DivisiCm Of Oil and C~s ~ation TO: ~ O. K. Gilbreth, Jr. Director Hoyle H. Hamilton FROM.: Petroleum Inspector DATE 'July 7, 1977 SUBJECT: Ck~trolled Safety_ Valve T~st on Arco' s ~I-10 Saturday, June 11, 1977 - I departed my hc~e at 7:30 ~ for an 8:00 AM ~ ~'-'9:00 ~4 departure via BP charter for Deadh0~se, arrivLng there at 10:30 AM. I was trans~ to Arco's DS 5-8 where BOPE tests w~re initiated at 10:00 PM_.. .Sunday, june 12, 1977 - BOPE tests on Arco's DS 5-8 w~re ocmcluded. y,June 13:1977 - T~st~.~ began at 1:10 P~ with the ~SV set at 2229' shut--in ~in~ ~sure 2250 psig. SCSV was tb~n closed and pressure downstream bled to 1000 psig and monitored fOr five min~. Pressure was then bled to zero and monitored for five ~. SCSV was then opened and SSSV closed. Pres~ was then bled to 1000 psig and monitored for five minutes. Tests were c~ncl~ at 3:30 PM and a field inspection report prepared with the c~iginal given to Kirk Mhi~, a copy mailed to Bob Itin~s and a copy attached to ~is report. Tuesday, June 14,_ 1977 - Tested SSSV's and SCSV's at ~P's G-2, D-3, E-4 ~"' E-2. Sealed ~ valves at Arco' s ODTU. Wednesday ,~ June 15, 1977 - I de~ Deadhorse at 2:30 PM via BP ~ arriving ~ AncO- ~t 4:00 PM and at my hcme at 4:30 PM. Attachment . A 18;( Oil(ind I,GasCQnseryati on. COtTlTliJ(': Field Inspection Report r¡;¡,1ù:lg'PI17:'i. "'= ' ".., ,'., ' ".Hl"" ,.,WeU:tR:18lfln. .' S¡¡,C~T~R.;', ''''''' -,-14 .,:Op~ra tor ,',",'.~i "',..', "',' ". Represented byw"".rlJ!l' Name ",& Number,NG-Z --.I ð , Sati sfacto~,y!,yp~In~peç~ion ,', ,,""," Sati~factory"", " Type InspectiQtl Noltenr( I Location ,General Yes No Item ( ) BOPE Tests () T~eJ1Si9n.", ,,'1',1', " ","", ",,' ',', () (,> ---rs:-""", ",,' ","~asin.?set @ ()2.~~peralHousekeeping , , ' () (,,) 16.'" Test fluid~()wtf7T)mud ( }oi] (, )1:,gÞ~7\verit-(:)0~en(,Ifilled () <, ,) ']. Ma~l~r:,HYd,~"""",Coryt~ol Sys.-, ,>p5i9 () 4.:Rig' ,", ,,',,' '.', , ,'", I"'> "", ",', ,( J () 18. N2 t5t1s.---,_,~" ,psig "t~.saifet¥Valve¡ests (, ,') f., )19. Remo,te ,'Controls (..,..() 5. Surface-No.Wel1s-L- , () () 20. Drilling spool----"outlets (..." () 6. S~~su~face~No.~e11s~ () () 21. Kill Li.ne-() Check valve ('.)WeJITestData " " () () 22. Choke Flowline ( ) HCR, valve () () 7. WelT Nos., ",,' () () 23. Choke~~anifoTdNo. va]vs ,j219S () () 8. ,Hrs. ooser- -:-- -:-- -:-- () {J 24. Chokes- (~emote( , }Pos. (~dð.- () () ,9. B,S&W ,-,-,---:- - f) (J 29. te?tÞlua~{JWellhd{ Jcsg( )fione () () lO~ Gr. Bbls .~" ' ,'- ", '~ () () 26. AnhularPreventer&8~~~1JS;9 ('),Fina1'Abandonmen~t,' (i,)" () 27 ~êltndRams ,1J.;..~:) fi5 i 0 11. P &A Marker , '" ,," ,':, "" (')' '() 28 ~ Pipe. Rams "" ',' "" "', psi q 12. Water wel1-( )capped( )pluggect()() 29. ,K~llY&,Kelly..c()ck.~si~" '",', '13. Clean-up ",:'" "(y'1"."",','¡~'i') 30. l..o~~rK~ll'.x,~~.~ve,","',"~s~g':>; 14. PadleJ/.eled" ,1l""A'I,",' '."',"',." :, ,';;';'" {::,/,?,;!(:,') ,'31 ~ . Sâfe, ty'" Fl óò'r"".",""',V)!"a"",'lv,e~',.~{,,.')"I~V,';{i):"',',~i,g"",.a,.,"';;~:t on observation tinie~hrs/'" Total number leaks and/or equip. failures ,,0 I " U:} -!',,',,\' I I ,"1~:'i I ,', cc:¡fløi; MNUNotify in-"-déJ?Ysoy When,~eadý~Inspected b:«t11~ate~ ;,;,»" ."" ,','" " ",.".,"c.~"~'~"..~""'""""',.,,='"":-~:~:'"'"',., ,.."""<",,'L,, ,.". "" . . ,', ,.,'. .'.'.'..,.,':'.' ,.~'::~:~ AllanticRichfieldCompany % North American Producing Division North Alask"' qistrict Post Office -~ ( 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 ! ONFER: FILE: Su bj ec~ 3- 06-11-15 ) 2-01-11-14) Dear Mr. Hamilton' Permit No. 75-69 Permit No. 76-69 Enclosed please find a Sundry Notice outlining our plans for each above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure For:~n 1 0°403 RE¥.-1-10073 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) o,- F-1 GAS [~] WELL L..-J WELL OTHER Gas Injection 2. NAME OF OPERATOR At]antic Richfield Company 3. ADDRESS OF OPERATOR P.0.B0x 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 137'N & 915'E of SW cr. Sec. 1, T11N, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate 5. APl NUMERICAL CODE 50-029-20229 6, LEASE DESIGNATION ANO SERIAL NO. ADL 28302 7. IF INDIAN~ ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay 9. WELL NO. NGI-IO (22-01-11-14) '10~ FIELD AND POOL, OR wILDCAT Prudhoe Bay- Sadlerochit 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 1123'S & 1186'E of NW cr Sec. 1, T11N, R14E, UM 12. PERMIT NO. 76-69 3orr, or Other Data SUBSEQUENT R EPO RT 'OF = WATER SHUT-OFF : REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Compl®tlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED or COMPLETED OPERATIONS (Clearly state all i~ertinent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. After setting and testing the downhole safety valve, the well will be blown down and flared to the pit for clean up only. A static bottom hole pressure survey will then be taken. Estimated start' June 11, 1977. 16. I hereby certify that the foregoing Is true and correct (This space for State office use) .~/' i! CONDITIONS OF APPROVAL, IF ANY: ~ See Instructions On Reverse Side Approved Eetumed ATLANTIC RICHFIELD _North. , Alaska,District Enoln~_r~no=' == ' =."' TRANSM I.TTAL J. A. Rochon/p. Hellstrom Date' .Apri!' 6,~ 1977 Well N~_~e' · NGI #10 Transmitted herewith are the follm~ing for the subject well: Run No. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log. · BHC Sonic/Caliper 'Gamma Ray Log _ BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Lo~VDL Compensated ~omation Densi.~ty~Lqg~_G~) S" Compensated NeUtron-Formation Density _. S" Compensated Neutron Log Core Analysis - Interval ' Core No. Core Description .C~VC) - Interval Core Description (Cony.) - COre No. Directional Survey- Gyro ' Singl~ Shot i-_ ..-.--- .... Multishot Drill Stem Test - Test No. Dual Induction Laterolog 2" ~ 5" Fomation Density Log Formation Density Log/Gamma Ray ' Gamma Ray/CCL ~ ,, Laterolog . Location Plat Microlaterolog _ . ... Microlog . Mudlog- Interval Sample Log (A.R.Co'.)-Interval) Synergetic Log TVD-DIL · TVD-Porosity Log Receipt Acknowledged For' Date' Please return receipt to' ....... - :u. 7 .... . .-. Atlantic Richfield Company North Alaska Engineering blana~r ...... ' ~:'? C,,i: ~::,: :- , P. O. Box 360 Anchorage, Alaska 99510 ATLANTIC RIChfIELD CO~PA\~F· North Alaska District Engineering_ CONYlDENIIALv R A N S blI T T A L DISTttlBUTED '1'0: STATE OF ALASKk DIV!.S[ON OF OiL & G~ To' From: J.A. Rochon/P. Hellstrom Date' Dec. 14, 1976 Well Name' NGI # 10 Transmitted herewith are the following for the subject well:' Run No. Scale' xerox -.. BHC Sonic/Caliper Log .BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log. Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey- Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gmnma Ray/CCL /Neutron Laterolog Location Plat Microlaterolog Microlog Mudlog- Interval Sample Log (A.R.Co~') -Interval) Synergetic Log TVD-DIL TFD-Porosity Log Sepia BL Line Receipt Acknowledged For' Date' Please return receipt to' By' Atlantic Richfield Company North Alaska Engineering Manager P. O. Box 360 Anchorage, Alaska 99510 # I01 AL, ~.~icRichfieldCompany North American Prod[~cing Division North Alar District Post Office--~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 6, 1976 Mr. Hoyle Hamilton State of A1 aska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #10 (22-1-11-14) Permit No. 76-69 Dear Mr. Hamilton' Enclosed are the completion report, drilling history, and multishot directional survey for the above- mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer CRK/cs Enclosures '~ SUBMIT IN D!~:CATE* STATE OF ALASKA :Se,:.othorln- st FlOC t iOIl.q O~ OIL AND GAS CONSERVATION COMMITTEE ~"~"~ ~<~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ' lal TYrE OF WELL: olI, ~ o^~' ~ ~,VEI, L WELL'~ ~::~ o:~ Gas Injection b. TYPE 0F COMPI,E~ON: ~V E[,I L__.J()VEH ~ EN ~ BACK RESVR. ()thor ~ 2. NAME OF OPERATOR Atlantic Richfield Company ,q. ADDRES,q OF OPERATOR ' P. O. Box 360, Anchorage, AK 99510 4. ~.o(',,'ru~x oF w~:l,L (Report location clearly and in accordance with uny State requiremet~ts)* ,~t~,,m,~ 137'N f 915'E from the SW cc of Sec l, TllN, R14E, UM At ~,~p prod. Interval reported below 1599'S & 1072' E from NW cr of Sec 1, T11N, R14E, UM At total depth 1~23' S & 1186' E from NW cr of Sec 1, T11N, R14E, UM 5. AP1 NUIVLF_,HICAL CODE 50-029-20229 6. LF-.ASE DESIGNATION AND SEI~I. AL biO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAi~I.E 8. UNIT,FA3L1Vi OR LI~kSE NAME _Prudhoe Bay 9. WELL NO. NG: #10 (22-1-11-14) iO,, FIELD AND POOL, OR WILDC&T Prudhoe Bay-Sad] erochit 11. SEC., T., R., M.~' (BOTTOM HOLEr., . OmmCTtVE) P001 sec l, Tl lN, R14E, UM 12. PEI~IIT NO. 76-69 i~;. I'OTAL £)EPTH, MD & TVD[19. PLUG, BACK MD & T'cb~l). I~ N[ULTII-'LE CO1VLPL., 21. I NTER'v'ALS DR [LI, ED BY '/ Vq/ I-{OW.lt,~a~'q.~* ROTARY TOOLS 1--- CABLE TOOLS 9990'MD,8555'TVD 9904'MD, 8491'T single all 112. PIIODUCING !NT~INVAL(S), OF THIS CO.MPLETIO~NF--TO,P,BOTTOM, NAME (MD AND TV'D)' 23. '~VAS DIRECTIONAL , SURVEY MADE Top Sadlerochit 9258'MD 8011 'TVD I Base Sadlerochit 9895' MD 8484'TVD ~ YES ,1 2.1 'rx_q'lC [,;[,E("Vi', lC AND OTtiEI-t LOGS RUN DIL/FDC/GR/BHCS/Calipor, GR/CCL, GR/CNL/CCL _ 25. cv~s~'~o :slzt,: [lb/ft-thd 20" 94# Vetco 72# Butt ! 47# Butt 26 LIN !)]:{ 7" .... l 8523' I 9986' 335 sx [ I ,, l Class G ~8. PI~':'iiF[)'R'A'I lC)NS OPEN TO PRODUC~O~ [interval, size and number) ' 13-3/8" .,. 9-518" ._ CASING RECORD (Report all strings set in well) /'H-40 MN-80 kiN-g0& SOO- 95 i ! 8.0' 32" 240 sx Arcticset cmt 281.0' 117-1/2" i 4300 sx PF II cml 881.5' ll?-l/4"_l 7;50 ~× £1a$~ a cml TUBING R]~ C O PJ~ · i j 30. II I IIII I II ./C,IOUNT PULLED I, SCREEN iR(Dj SIZE DEPTH SET (RID) I PACIfiER SET (}~ID) 7" '" .. 843a'_ [' , a31l' I ,I 29. ACID, Si:CT, FRAC1 GRE, CE._'.I.CN~T SQUEeZe, ETC. DIqpI'IT iXT.E~V.qJ~ (MD) I AMOUNF 2-.~ND IilND OF A,5A[ZEP. IAL USED I DATE <}F TCST, }iUUI{S q ESTE, D [CI!OXE s~ZE [PEOD'N FOg OI~BBL. G-A~ICF. V(ATEg--BBL. ] GAS-OIL RATIO ~ i - IT~.~r Wa:OD .... ~5i~'~:,rLEss. ~I.NG] '~RE'~'~URE [24-HOu~ICALC~T~RATE OI~BBL. OAS--rvICF. WA'~--BBL. ]O:L GRAVITY-~I (COaa.) ~"1. PlSPoSITION OF GAS (Sold, u~ed ~or ue[, uented, etc.) tTEST WITNESSED BY 32. LIST OF ATTACHMENTS ., Dr~ll~n9 a~story and MultJshot d~rect~ona] survey :';2. I horeby certify that the fore/oing and~ttaehed information Is complete and correct as determined from all-available records *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct ,.,,,ell completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as referer~ce (where r~ot otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, prcduction from more than one interval zone (multiple completion), so state in item 20, and ir~ iteq~ 22 show the p~cJuci,.9 interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this w.ell sh,.-,:JId show ;he details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ~'-i' 34. SUMMAItY OF' FOH. MATION TE.~TS IN('I. UI)IN(; INTEI].VAL TF_.STED, PItE~SU~E DATA ~ '~OVERI~ OF OIL, GAS, 35. G~GIC MARK~ WAT~{ AND MUD , , NA~ lop Sa~ R~ver 9170' 7942" l°p Shubl~k 9220' 7981' lop Sadl erochTt 9258' 801 Base Sadleroch~t 9895' 8484' 3B. CORE DATA, Aq'I'ACII nRIEF :D~I~O~S OF L1TIIOLOGY, PO:HO~ITY, FRAC~R~, AND 'I)~'~CT~) SII()WS OF OIL, GAS .OI1 . . Drilling History NGI #10 (22-1-11-14) API #50-029-20229, ADL 28302, Permit No. 76-69 Spudded well @ 0430 hrs 10-26-76. Drld 17-1/2" hole to 2853'. Circ & cond hole for csg. Dropped multishot. POH. RU & ran 72 jts 13-3/8" 72# MN-80 Butt csg w/shoe @ 2810', FC @ 2728'. Cmtd 13-3/8" csg w/4300 sx PF II cmt, slurry 14.8 ppg. ND 20" Hydril. Installed & tstd 20" x 13-5/8" csg head & csg pkoff to 2000 psi OK. NU & tstd 13-5/8" BOPE. Meas in hole. Tag FC @ 2728' Drld FC, firm cmt & shoe. Dlrd new form 2863' & press tstd to 0.65 psi/f~ equiv. Trip, PU Dyna-drill. Oriented tools & drld to 3160'. Trip, RIH w/Dyna-drill #3 & drld to 3380'. Trip, PU 12-1/4" BHA. RIH & drld to 8857'. POH. Chgd & press tstd 9-5/8" rams. RU & ran 222 jts 9-5/8" 47# MN-80 & S00-95 butt csg w/shoe @ 8815', FC @ 8732', FOs @ 2484' & 2359' Cmtd csg w/750 sx Class G cmt mixed w/l% CFR-2 & 0.15% HR-7, slurry 15.~ ppg. Displ w/655 bbls mud. Plug did not bump. Floats held OK. Installed & tstd 9-5/8" csg pkoff to 5000 psi OK. Chgd & tstd 5" rams. RIH w/RTTS & shifting tool. Opened lower FO. Break down & pumped 4 BPM @ 250 psi, Preceded cmt w/200 bbls of wtr. Cmtd w/250 sx PF "C" cmt. Closed FO. Opened upper FO & circ 9-5/8" x 13-3/8" anul. Pumped 312 bbls of Arctic Pack w/25 ppg Geltone added preceded by 39 bbls of Arctic Pack spacer. Zero % contamination in final returns. Displ Arctic Pack w/28 bbls mud. Closed & press tstd upper FO to 3000 psi OK. RIH w/8-1/2" bit & drld cmt from 8625-8734', FC & shoe, & new form to 8857'. Press tstd form w/ll.9 ppg equiv mud weight. Drld 8-1/2" hole to 9960'. Ran DI~./FDC/GR/BHCS & Caliper logs. Ran sidewall sample tool from 9894' to 9150' & shot 22 cores. Full rec. Drld to 9990'. Ran 7" lnr w/shoe @ 9986', top of lnr @ 8523'. Cmtd lnr w/335 sx Class G cmt mixed w/l% CFR-2 & 0.2% HR-7 slurry 15.8 ppg. Bumped plug w/3000 psi. Floats held. Chgd & press tstd 5" rams. RIH w/8-1/2" bit & drld cmt 8396-8523'. RIH w/6" bit. Drld cmt 8523-8537'. CO to landing collar @ 9904'. Press tstd csg to 3000 psi. Set pkr @ 8450'. Opened tool w/very lite blow for 10 min, dead balance of 3 hr tst. POH. Rec 15' net rise. Press charts indicate WSO OK. Ran GR/CCL logs. Chgd over from mud to 10.9 ppg CaC12 wtr. Press tstd FO to 3000 psi Ran gauge ring & junk bskt to top of lnr. Chgd & press tstd 7" rams. Ran 260 ~ts 7" 29# L-80 LT&C A-B Mod 8rd tbg completion asbly w/Baker pkr @ 8311', PBR @ 8259', XA sleeve @ 8184', ball valve nipple @ 2229', & shear sub @ 8438'. Installed & press tstd tbg hgr. Ran ~-~-~-u~va-2q-v-e-. Press tstd balance & control lines to 5000 psi. ND BOPE. NU & press tstd xmas tree to 5000 psi OK. Pulled dummy valve. Dropped ball & set pkr. Press tstd tbg to 2000 psi OK. Press tstd tbg csg anul to 2000 psi OK. RIH & opened XA sleeve. Displ CaC12 wtr w/diesel. Closed sliding sleeve. Tstd tbg to 2000 psi OK. Set dummy valve & tstd to 5000 psi OK. RU & tstd lubricator. Ran GR/CNL/CCL & dummy gun. Could not enter top of lnr. POH. PU sinker bars. RIH & pushed object from top of lnr to 9904'PBD. POH. Reran cased hole logs to btm. POH. RU for long term tbg press tst. Released rig @ 2200 hrs 11-23-76. A PETROLANE ~PANY REPORT of SUB-SURFACE D IREC TI ONA L SURVEY Atlantic Rich£ield COMPANY N. G. I. #10 WELL NAME Prudhoe LOCATION JOB NUMBER Al176 S0225 TYPE OF SURVEY Multi-shot DATE 11-19-'76 SURVEY BY Jay Martin OFFICE Alaska R F.-C-OR D --~F--~F~LE--Y_ ........ ALL--CAL~WLAI I_OJ'~S~.. =' ..................... .... ~ F-©R."-,IEL~ BY- -i ~ j'., ' : F~ · ,, ,,: - ,,.- .--, .................................. -TR.U-E- ~LEAS.,_.D R I EZ~C..A.L--______SL~ .... D.R-I F-'r ..... TO-.T-AL--C. 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F-E-E--T--O F--- -5 U-B---,SE: A D'E PTH', ' __ MEASURED ......... ~/_ERI: I.CAL SU9 .. :~D-TVD~ ................ .VER_ZL~.AL O E P T H DE.P_I~. ..... S E A .. D I.F F £ R E ~i~-:-~P~q E C T ! O ¢'4 T O 1:~J.----CO.G~D ~ N-A-T-~S 3_9~_9 '~ 9..4-7., .... 3 9 O0 ....... 21 4_0..7_7 Z+ 0 4 7, ........ .40 C 0 ............ 2-9 418.6 ...................... 41.47, .......... 410_0 ........... 39. 42_9.9 _4.2A_7_, ..... 420 0 ......... 52 4.~.1.5 ................... 4.347_, .......... .4.300 ............. ~.8 .... 453 5 .................... .~7., ............ 440.0 .............. 8_7 ~.7..8. 7_ ................ 4.54 7, .......... ~6.00 ............. 1.~0 g 91_6 .......................... A 74 7, ........... ~.700 ....... 1.68 5Zg: ..... _48 .g._7.,_~..BO0 .... 199 517.7 ........................... 494 7, .........~.90 0 ........ 230 .................................. 3~l ...................................... 1.916 ,. 7-&-.N ............. 2-0.5., 1.-i--~' _5309. .............................. ~ 0 ~ 7., ............. ~G.00 .............. 2 61 2 O ~.2.,. 2.~_:~ ............... 5_4.~ ! ....... ~..L4.7.., ....... 51OD ..... 2~3 .... 32 ~S.~..~ ..... 55.Z~ 52_4.7.., ........... 5200 ............. 3 27 3~ ...................................... 21 ~ ._4 2--~ ......... 1-9 ~ ,--9.2---W ............ 3.7_0_9 ......................... 5 347., ....... 5.300 ....... 362 .......................................... 3.5 22.66.,..6 7._...N 193,0 7 W 5.~..4.4 . 5A~.Z~ .............. 5.40.0 ............ 3 9.6 '<4, 235 7..,_a.4.._.~ ............. 1.90, 5120 .......... 56 4 7., ...... 560 O ~ 73 _~-0 2 54 7_,.3.&: .................. i8_6,3.5 62~.9__ 52AZ, ~_7.00 ........... 5.11 ~ : 8 Z6_~_~..l~ .... ~3.. 63_9_8 5.8_;_7_. ........... 5 ~800 5.51 ....................... _~.~ ~-L~. L,.~ ~' ..... ~-8 i ~ S 3--W. ~.:.:.~ ~_~_~ :. ............ ~.~ o o ........ : ~: ........................... 4.0 ....................................... :: ~.~.. ~ z__~ ............... ~.:~..~ ~.._ .w_ { .::7' 68i.A ...... ~.:~..~_, ...... _6L0_.0 ........... 6.6.7 3_~ 3~..Z9~-~-~ .............. .6.95..I 62_A.2.., ........... 62.C.0 .............. 7.0.~ ............................... 3: ...................................... 3.1-2S~ O~-..-~ .................... 1-7S .,-03 --W .55A_7_, ....... _65_0_0: .............. 81.:1 7_0_8 7_2_2 .~+ ....... 735._8 .... ~ EASUR_E D ...______QEP__T.~ V_EP, ff_I f, AL_$U B ...... ~D-_T~_D. D EP_T-H - ~S EA--B-LEF-E R E N C E - _V_F__~T_I_~ ........ &lS_O. .7J._.4_"'~ ..... 2ZQD.----1-00,3, 82.82 724..7, . 7200 1035 32 ............ ,B 4.12 .................... 2.~.4 7_. ......... _7..30_0 1.065 _:_0 __ ~ 5_~2 7A(+_Tj ...... _7..z+,_0_0____2095 .... .................. -~_5.7_0 _75._~_7_. ....... .7:~0_0 ......... 1_1.23 2_.8 .............. 8 79_8 ................. _7_5_4_7_. ......... ..7_6 O0 .......... i 1.51 Z2 &92.5 ............. _7_7._~2_. ..... _7.7.00 ...... i 17 9 ........................... -2-8 .................. 90.5 ! ................ _71i43.. ............ _7.80. 0 ..... 1 20 ~+ ...................... -2_5 .... ............ 91._7__7 2.9A.:7_. .......... _7 9.0_0 ...... 1 22 9 .... 2. 5 ~-3-0.3 ~.0&-7 -_ 8.QQO .... J.-256 2 7 ............. 9.&.~-3 _8.;L~-?-,,, ........ 8 !00 ....... 12 85 2 ............. 9565 .............................. _8 2_z~,_7., ............ 8200 13 18 92J2.5 --83L4--7" 8-3.00 .... ! ~-5-8 .................. 9.8,~..5. .8_~.~..-7.. ................. :-~00 ..... ~: 9-8 --INT E R P 0 L A T E D ~-¥A t~U ES--FOR-- E V T_RUE MEASURED. ............. DEB.TH__ AER_T~. I CAL .......... .SUB ............................... ,. D ERZkL ............. $EA ............ :.T 0 IA L .... COO R_D. iNAT_ E-5 ................ !000~' g99., ............. 952, .................. 1051,.19---~ .... 22.2-,-98 W ................. 2000_~ ............... ,_19_99, ......1952, .................... 105.5.,80__N .... 215-.-26--W '% ............ .~ ~---'-?_ ~ 000 50.0 O &ODD. ............... 7000.__ 9009 2999. ........ 2952, 3926, ..... 3929, ............ 1263., 79--N .......... 230,48--W ....... ~?- ............................ ~*8_.1 l, .... ~754, ~.aQ ~ ..... 55.13 · ' 2.~ a~.AI--N: _ L85.09--W ' &2 82 · 62 35 · ........ '- =.-31.56 · ~ ~---N ....... l 72 .. ~ 3 ...... W--:~ ..... 2033, ...... 6985, 7~ 08, ..... 7.75 9 · ~ ~ ~6 ..2 I_N ....... :, . 10.l. ,. 3-7--W. ! - ' ' :- SCALE -,"=, in~ni,., ,., ,.,: ....... ~ .... i ...... . ] - ........... ATLANTIC RICI~FIELD COMPANY ...... ; .......... WELL N.G.I. lO "- -; ......... ~ ...... : ........ :. .......... ........................'- --- ........ i ...... EADIUS OF CURVATURE .......... ! ~ ! ' - i .... MAGNETIC MULTI- SHOT ..... 1 L.:.. : I . - ...... 7200- 6800- 6000 ......... ; 5200 ',! :- ~ ' ' ~ ~oo' l I : i -' i : · - ' ; 4ooo4 ................ ~ ...... '__5 ..... L]..! ............ :.: ........... i ..... i ...... , ~ ..... ! ......... · ............. ALL DEPTHS SHOWN .... ~ ' ' -' ' ~ .... i ....... i ....... :, ..... I .... . ....... · :' ; i ' , -- i ........... '. ~. ............................ :' '] ..... 7__-{ .,~oo ........... . .............. - ...... ~ .......... ~ ................. VERTICAL._ SECTION ......... SCALEI :1OO'0' - · -,I .............. coo ...... ? .... ATLANTIC RICHFIELD: COMPANY .................................... ~_ ....... i___[ ............................... WEkL_N.G.I. !0 .... i --- RADIUS OF CURVATURE , - .............. ~ ...... MAGNETIC MULTI-SHOT 1600 - . _ , ................... ,. ....................... ' ............................. : ....... LL. DEPTHS ~SHOWN~ .............. : .. ~ ~ ~ TVD ; - : ...... ~ TMD= 9960'~ ..... ' ..... ; t ' ~ -' J ' -'l 02~01 B STATE of ALASKA DEPART!gENT OF N2.TUP~L RESOURCES Division of Oil and Gas Conservation To: ~- Hoyle H. Hamilto, n, Di rector~. I ":~"" "' ~' ' Thru~ Lonnie C. Smith Chief Petroleum Engineer FROM: l-larold R. Hawkins Pe~roleu~ ~nspec~ot DATE : November 8, 1976 SUBJECT: ~4itness BOP Test, NGI ~'~ ~10 ARCO, Sec 1, T11 H, RI,fE, Uk~ Pe~nit No. ~.c.. 6~ _.T_hur_sday, October 28, 1976 - I left my house at 7:30 A~ to catch a flight 9 at 9.00-AH to Prudhoe Bay to witness a BOP test at NGI 10 ~or Arco. They said they would be testing early in the evening. When ! arrived they were just finishing up running their 13 3/8. They circulated, then cemented, finishing up at 7-30 PM. They started nipplin¢ up at 11:30 and flooded their cellar with mud and were delayed cleaning up the cellar on Challenger No. 51. Friday, Oct~o~er 29, 1976, ll-O0 AH. They started testing the manifold. i Witne's's~''e~,~,~,~w'''torque, ~ . . . wing valves on the manifold. Sixteen held.~ 5000 psi. One valve was leaking and was repaired later and tested to 5000 psi. There were 32 flanoes, one superchoke that was also tested to 5000 psi. Fianual choke on manifold actuated freely. The lower kelly was tester.! next and leaked, it was replaced by another which tested to 5000 psi and held OK. The BOP was ready to test now. The upper and lot~r pipe rams tested to 5000 psi. The upper kelly was also tested to 5000 Dsi. The inside choke and outside choke were tested to 5000 psi. The inside kill and outside kill valve were tested to 5000 psi OK. The check valve was tested to 5000 psi. The HCR valve did not test. They are to repair or replace it. The ball valve and dart valve were frozen up and they freed them up while I was there. I talked to Kelly Goff who was the operator for Arco and told him that the ball valve and dart valve were behind the draw works on rig floor and he had the rig ,masher put them in front of the draw works for easy access. The fie backup bottles for the BOP were low and Kelly Goff replaced them with Your full bottles which had 2200 psi each. The master gauge had 3000 psi. All controls functioned properly. The mud pit is well berm.~d. They had a steel fuel tank not bermed. The well sign was put up and all data OK. The location is clean of debris and in very good shape. The annular preventer was tested to 3000 psi. The test stem was pulled and the blind rams were tested to 5000 psi. The spool had 3" outlets. In summary: ~,4hen I finished witnessing the tests, the BOP and all components were in place and in good working order except for the HCR valve which Kelly Goff said he would repair or replace and call us in four days. The BOP tests were from 11:00 A~q to 8:00 PM. '~'/~¢~-~'¥~ to call us. I talked to Gil Meyers on Slope about this 11/10/76. He talked to Donnie Fields, pusher on duty at NGI 10. He told us the BCR valve had been replaced. Attachment ¡¥0,'!!: ..' ¡;:ï~!~. "I' . ".'" ..' ""'. .' .'." . ....r" ~',4::k Jil..and..G~s.. Conserva'~;or Commi( "'''''''''.. I '1'L~i,\. Fiøld Ins.pecti()n Report ,>",/ ,;:0'.: ßr.fg."..." 'Re.rmii't"""","~:o...:l;J~..tt'.....',Ç? . ". ........"""""""".."""""'" .,..................,.'.,..,..,........,.,....,...,.,, ...W~Jl.le19,~,fm... .., $~ç} ..T./l¡¿Hi~;¡~wdJ) : Operator /-1 '1) í- (') Represented bY!{FlJ. ý"i;¡;,¡;:ÆName& Number p ~'7/" ~...Ic!) . ... ." I ~ ~LSðtisfðct~~?C .RPe Insp~ction . Sati~fact~ry" TXP~ ,Inspection ~~t Yes No Item ) Locatlon,General Yes No Item () BOPE Tests :¡J:;¡ (X) () ---r:- Well Sign (X) ( J 15./. "casingset@..:?~lð ~1~1~:'" (,..\1 (} 2. General Housekeeping '. .' .(X)()16."fetfluid~~~:tr.(X)mud:{)<lQ:¡fJ :p. (.-tJ () 3. Re~~r~e.~i.Hy>.?pe~( ¡filled (.y) () 17. Master.. Hyd.> Q~tro1Sys~:l<;1(z~H~ig ~~~Þ)1" ,.,,'., (,:1 SatatyValve, Iests, (.\.')() 1,~.ßø.mPtø.Cont(ol..,~, . . " ..,' .' :\'1')'(' () (). .5. Surf~S~i~o ~~!tl ~~~ (X) (.) 20. Drillin~ spool..~"()uFlets :;:'~: ' () () 6. Suþs~rf~ce..f!o~W~lls".-,~ (X) () 21 KillLine~(k)Checkvalve, :;1';;" .," .' .' (.)W~ll Testflata '.. (...) (...11 22. Chqke Flowline (()., HeR Y~,l;¥.~\ ¡ () () 7. Well NOS,----,----,----,---- ~ (~ 23. Choke Manifold No. valV~5'~~gS~ ;:; (~ ()~. Hfs .obser --'~'--'- Çfj () 24. Chokes-{-\') Remote ~) Pos, . Aâ,]. .':':' () () 9. BS&.W ~'~'~'--- {x) ()25. Test P1 ug-W)~Jell. d(. )csg( )none ~i¡~:i. () L) 10. Gr .Bö1s.~,,,--,~,- (X) ( ) 26. An~ular Preventer:5'ðO<Jjsi 9' :'."',,' ( .) F 1 na 1 Aba.ndonmen t (x) () 27. B IlpdR~m.sC~.E.J1Sl 9 , ?\. () () '1. 'P&A.Mar'ker .. . . tv) (.) 28.. Pip~Rams.1ðð{')psig ..' ~' () () 12.. Water well- ( ) capped() pl ugged <x) () 29. Ke l}Y&Kell!,.-cOC,~ðdP~Jg!, ;,>., '. (:). ()13.Gl'ean~up (x-) . () 30. Lower Kelly valve"'ð":PS1~L¡¡,:ir:" . .~'. 'rohli ~s~~ct~~~~b~~~~£~¿~ "tim~&"~'dâys .~lai (h~~be;l ie~k:e:~d~~~O~q~~~ ~e~~i l~~~s~lrt.i ::');."Remarks2FAJifjßE" .f? £PA1}fl:'¡;?l,ð ~/ t.::Æ? J(£.I.LV if E?¡ A£"~:::p Á.tJW TÖ/Ptó~ ..<.I/x>¿~ ~ìi:~ 'Þ:~/: :;,./1 p'A//rl ~ l ll1!J:ß r1ft~'ff"'~~ 1: :::Jfi/:A 1If',<l~4/i' ... '" ;- ~:L~ZJ~~i~;"~X:Z~~~;;~;,~~,~;..,@::1:'(~~~",?i~~~~",. '~:jtiL: c. :,,,.. .' .' '-- . . ; ,,-,,,, L>: :., . . :;,.;,,;. :~.::,,' ri';:!'i~:::.,::::::' ;;;.~~;~/:':~"::~ :;:~,;:i~i~}i..~L":i;¡ i:;',:;,;~::~~:;~ ;J~::t~,r:;::i.; . . · ~ Atlanti;RichfieldCompany North Americ~r~ Producing Division North A~asl ~rict Post Office Anchorage, Alaska 99510 Telephone 907 277 5637 November 2, 1976 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' NGI # 10 (22-1-11-14) Permit No. 76-69 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Si ncerely, C. R. Knowles District Drilling Engineer CRK/jw Enclosures ~n~ ~o. ~'~ STATE OF ALASKA lg~V. ~- I-?0 SUBMIT IN DUPLICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS o,L ~ ~,, []] oT,,, Gas Injection WELL ~'J:LL 2. NAME OF OP~iR. ATOR Atlantic Richfield Company ADDRESS OF OPER3LTOR P. 0. Box 360, Anchorage, Alaska 4. LOCATION OF W 137'N & 91 5'E of SW cr Sec l, TllN, R14E, UM Nu~i~:mc~ coDE 50-029-20229 6 LF-~%SE DESIGNATION A,.~D SE't~IAL HO. ADL 28302 7 IF INDIA~, ALOTTEE OR TRIBE NAME 8. L.~IT FAI%Ai OR LEASE NAME ?rudhoe Bay g WELL NO NGI #10 (22-1-11-14) 10. FLFJ_JD A-ND PC~:JL. Olq. %VILDC.~? __Prudhoe Bay.- Sadlerochit Il. SEC, T., R., 1%~.. (BOT'I'OI%{ HOLE Sec l, Tl lN, R14E, UM 1~.. PElqNiIT NO 76-69 13.REPORT TOTAL DEP'I'H ATEND OF MONTH, CHA. NGF~S IN HOLE SIZE, CASING AiN-DCL'~[ENTING JOBS INCLUDING DEPTH SET A/WI) VOLTLV/V/ES USED. PEiR. FORATIONS, 'VESTS A/NrD ~SULTS FISHING JOB~ JU/N'K IN HOLE A/~D SIDE-T'R.ACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLI~ CONDITIONS Spudded well @ 0430 hrs 10-26-76. Drld 17½" hole to 2853'. Circ & cond hole for csg. Dropped multishot. POH. RU & ran 72 jts 13-3/8" 72# MN-80 Butt csg w/shoe @ 2810', FC @ 2728'. Cmtd 13-3/8" csg w/4300 sx Permafrost II cmt, slurry 14.8 ppg. ND 20" Hydril. Installed & tstd 20" x 13-5/8" csg head & csg pkoff to 2000 psi OK. NU & tstd 13-5/8" BOPE. Meas in hole. Tag FC @ 2728'. Drld FC, firm cmt & shoe. Drld new form 2863' & press tstd to 0.65 psi/ft equiv. Trip, PU Dyna-drill. As of October 31, oriented tools & drld to 3160'. Trip, RIH w/Dyna-drill #3 & drld to 3380'. Trip, PU 12~" BHA. RIH & drld to 4681 '. 14. I hereby certify that the fo/egoing is t~e and correct .,'"m ~ Y[ ~ _ /I/~ ~ NOTE --Report on fbi, form is required for eoch colendor month% regQrdles, of tho ;~l~,~us of operotio~;, Qfld mUSt I~ filed in duplicofe with the oil and gOl COOlervotion committee by the 15th of tho succeeding month, ullleu otherwise directed. Division of Oil and Gas 3001 Porcupine Drive, ANchorage, Alaska 99501 August 16, 1976 Re: Prudhoe Bay NGI No. l0 (22-1-11-14) Atlantic Rich(t~tld Company State Permit No. 76-69 C. R. Knowles District Drilling Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section l, Township llN, Range 14E, U.M. Well samples, core chips and a mud log are not required. A directional survey is required. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder {Title 5, Alaska Administrative Code). Prior to comnenctng operations you may be contacted by the Habitat Coordinator's office, Depart- merit of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations promulgated thereunder {Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the Division may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. C. R. Knowles August 16, lg76 In the event of suspension or abandonment please give this office adequate advance notification so that we may have a witness present. Ilhos. R. Marshall, Jr. Executive Secretary Alaska Oil and Gas Conservation Conlnittee IRM:bjm Enclosure cc- Department of Fish and Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. Department of Labor, Supervisor, Labor Law Compliance Division w/ encl. At~ntic~ichfieMCornp~ny . August 3, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 RE- North Gas Injection Well No. l0 (22-1-11-14) Sec 1, TllN, R14E, UM Dear Sir' Enclosed is our Application for Permit to Drill the above- mentioned well, together with the $100 application fee and required survey plat. Since this is the tenth well drilled from this drill site, we request the waiver of the double diverter line requirement of CO 137, Rule 4. This well will be directionally drilled. The surface and bottomhole locations are located on lease 28302, having an effective date of October 1, 1975 and a termination date of March 27, 1984. The information in the above paragraph will be helpful to the State Department of Labor. Very truly yours, C. R. Knowles District Drilling Engineer CRK/MAM/jr Enclosure Form IO-401' REV, 1-1-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK' DRILL [] DEEPEN F-1 b. TYPE OF WELL OIL GAS WELL[-] WELL[--] OT.ER Gas !njection 2. NAME OF OPERATOR Atlantic Richfield Company 3. Al)DRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 4. LOCATION OF WELL At surface 99510 SUBMIT IN TRIPLK.~"~E (Other instructions on reverse side) 137'N & 915'E from the SW cr of Sec l, TllN, R14E, UM At proposed prod. zonc @ -8800 ss Tarqet' 1400'S & 1350'E from NW cr Sec l, TllN, R14E, API #'50-029-20229 , 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approx 8 miles northwest of Deadhorse LEASE DESIGNATION AND SERIAL NO. ADL 28302 IF INDIAN, ALLO~EE OR TffiBE NAME UNIT FARM OR LEASE NAME Prudhoe Bay ~LL sO. NGI No 10 ~ · ,, ,~/ FIELD AND ~OL; OR WIL~AT Prudhoe Bag - Sadleroch~t SEC., T., R., M., (BOTTOM HOLE OBJE~IVE) Sec 1, 111~, R14[, ~M ~2. ; 14. BOND INFORMATION: nE Statewidesurety,,d/orNo. Federal Insurance Co. #80113840 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 1400I (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION '1'O NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2650' (NGI #5) 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 18' Gravel Pad ~ou.t $100,000 - 16. No. OF ACRES IN LEASE 2560 19. PROPOSED DEPTH" 8597'TVD (9703'MD) 17. Nd,ACRES ASSIGNED ' TO THIS WELL ' · ': 320 20. ROTARY OR CABLE TOOLS Rd tary 22. APPROX. DATE WORK WILL START November 15, 1976 **See 'below** 23. PROPOSED CASING AND CEMENTING PROGRAM , , , . SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement , , 32" 20,' 94# H-40 100'MD Circ to surf +.GOO .~× Pormafrnnt 17½" 13-3/8" 72~ N-80 2700'MD Circ tn _~llrf +406)0 _~× 'Permafrost 12¼ q-`G/F~" 47~ MN-80 ~R6F~I'MI1 !+l~F1F)' r~m~nf--rnll~mn lcf Kfmna +7 & S00-95 ~qnn, ~,~ ~,,~, ~ ~=~ .~7 v~ v~,.,~,, ~ ~v · ~.,,,, ~,,~ .~. ,..,,,,..;~.,, ~..., 8~ 7" liner ?q~ MN-~O TD +]300' cement column + 250 sx SX Atlantic Richfield Company proposed to directionally drill this well to 8597'TVD, 9703'MD for future use as a gas injection well into the Sadlerochit gas cap. Logs will be run over selected intervals. A 20-3/4" Hydril and a single 4" diverter line will be used on the 20" conductor. A 13-5/8" 5000 psi Hydril .and' 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be tested weekly and'operationally checked on each trip. A non-freezing fluid will be left in all uncemented annuli in the permafrost interval. Seven inch 29# MN-80 tubing with a Baker "SAB" packer assembly and a 7" safety valve landing nipple will be run as completion assembly. This well will be completed in an overbalanced condition using 10.9 ppg Calcium Chloride. _ThiS well will be shut in pen~-~n~n~*inn **NOTE: Th~s work could start approx. September 25, 1976.. '~ ~VLP'S~/{Ck~S'~R'~I~ES¥~(~POSED PROGILAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dbectionaBy, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. SIGNED_ - ,...t DATE. (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE elixir; REQUIRED [] v~s ~] No DIP. ECTIONAL SURVEY REQUIRED ~ YES O NO MUD LOG D Y~S ~] ~o OTHER REQUIREMENTS: A.P.i. NUMERICAL (:ODE 50-029-20229 PERMIT NO. APPOVED BY / APPROVAL DATE August 16 1976 ~' Exec. Secretary · ~/' ( , TITLE DATE AlJaU~t 16. lq76 · See Instruction On Reverse Side SECTION i 915 section 965' ! 989 1014' 1039 1064 1089' -1114 SECTION t2 CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. OCT 4, 1975 ~ ,. DATE S URVE YOR A,~,,.,BUILT WELL NO, I LAT. 70°19'36.129'' LONG. 148°28'50.016" WELL NO. 2 J- A T: 70° 19' 37.284" LONG. 148° 28'50.762" WELL NO. 3 LAT. 70° 19'38.441" LONG. 148°28'51.493'' WELL NO. 4 LAT. 70° 19'39.596" LONG. I48° 28'52.223" WELL NO. 5 LAT 70° 19'40.749" LONG. 148028'52.947`' WELL NO. 6 LAT. 70° t9' 41.908" LONG. 148° 28'53.68Z' WELL I~t0. 7 LAT. 70c 19',43.052" LONG. 148°28 54.412" WELL NO. 8 LAT. 70° 19' 44.210" LONG. !48°28'55.t26'' WELL NO. 9 LAT. 70° 19' 45.370" LONG. !,48°28'55.850'' WELL NO. I0 LAT. 70° 19'46.5!9" LONG. t48°28'56.589'' Y 5 971 400.07 Y 5 97t 516 90 X 687 322.06 .Y 5 97'1 6,33.76 X 687 294:09 Y 5 971 750.62 X 687 266.18 Y 5 971 867.11 X 687 2.58.47 Y 5 971 984.28 X 687 210.34 Y 5 972 099.94 X 687 182.47 Y 5 972 217.07 X .68 7,..,t ~ 5.06 Y 5 972 334.31 X 687 127.31 Y 5 972 ¢50.53 X 687 099.14 EXISTING WELL CT~R' CONDUCTOR PIPE WELL NO. t TOP pAD ELEV. -- 18.4 FT. MLLW ARCO# AFE 292265 HVL#. . ' -. .... ATLANTIC RICHFIELD CO. AS -BUILT WELL I ,HUR I0 NORTH INJECTION SITE LOCATED IN PROTRACTED SECTIONS, I 8,12, T II,N,i RI,4E,, U.M~ PREPARED BY HEW/TT V. LOUNSBURY ~ ASSOC. 72~ W. 6TH.AVE., ANCHORAGE~ AL'ASKA DATE OCT 9., 1975 SCALE I : 300' LOOSE CHKD. BY G. D. FIELD BK LEAF £HECK LIST FOR NEW WELL PERi.tiTS _ I-s the permit fee attached . ...... .%,~,!. Lease ,. ~, ,~ ,_ Yes Ho Remarks (,i~.I Is well to be located in a defined pool Is a registered survey plat attached ....... Is well located oroper distance from property line ~_ Is well located proper d~stance from other wells . ~_ Is sufficient undedicated acreage available in this pool - i~; ;.;ell to be deviated . . Is operator the only affected party _ Can permit be approved before ten-day wait Does operator have a bond in force . i. Is a conservation order needed . . 2_ Is administrative approval needed . 3. Is conductor string provided . . Is enoumh cement used to c'ircu~ate on conductor and surface 'ill cement tie ~n surface and intermediate or production strings · ). Will cement cover all known productive horizons . ? Will surface casing protect fresh wa~r zonos · , , ~. Will all casing give adecuate safety in collapse, tension & burst :~,. Does BOPE have suffici~nt~ pressure rating /.'~=~:,~. c. . ~,., ~ .... .... dali tional Requirements- P. pproval Recom~en~eJ: Geel oav Enair. eerina' ,_ TR,v~ HWK ~-J~o~.. OKG HHH JAL (?,~" ',, ,, LCS JCM ~ Revised 1/15/75
