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176-068
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 12, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-09 PRUDHOE BAY UNIT NGI-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/12/2022 NGI-09 50-029-20228-00-00 176-068-0 G SPT 7492 1760680 1873 3379 3370 3380 3367 3 4 4 4 4YRTST P Bob Noble 7/4/2022 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-09 Inspection Date: Tubing OA Packer Depth 159 2215 2184 2181IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220704135020 BBL Pumped:4.1 BBL Returned:3.5 Friday, August 12, 2022 Page 1 of 1 5(9,6(' 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.12 15:08:36 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-09 PRUDHOE BAY UNIT NGI-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 NGI-09 50-029-20228-00-00 176-068-0 G SPT 7492 1760680 1873 3379 3379 3380 3367 3 4 4 4 4YRTST P Bob Noble 7/4/2022 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-09 Inspection Date: Tubing OA Packer Depth 189 2206 2184 2181IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220704135020 BBL Pumped:4.1 BBL Returned:3.5 Thursday, July 21, 2022 Page 1 of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NGI-09 FROM: Jeff Jones PRUDHOE BAY UNIT NGI-09 Petroleum Inspector Sre: Inspector Reviewed By:� P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-09 API Well Number 50-029-20228-00-00 Inspector Name: Jeff Jones Permit Number: 176-068-0 Inspection Date: 7/3/2018 Insp Num: mitJJ180809112333 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-09 TType Inj G TVD PTD 1760680 Type Test SPT Test psiL3. I4.8 7492 3 Tubing 3250 3240 3231 3224 3224 IA 32 2500 2493 - 2525 2540 3227 ' 2534 - BBL Pumped BBL Returned:OA 2 1 2 2 2 2 Intervall 4YRTST p/F Notes' The test pressure failed to stabilize, MIT to be re -scheduled when well temps stabilizes. SCANLIE w SEP 2 0'l 016 Thursday, August 09, 2018 Page 1 of 1 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReDATE: Thursday, July 05, 2018 gg �7 l P.I. Supervisor � � %' i �{ t � SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. NGI-09 FROM: Matt Herrera PRUDHOE BAY UNIT NGI-09 Petroleum Inspector Sre: Inspector Reviewed By- P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-09 API Well Number 50-029-20228-00-00 Permit Number: 176-068-0 Insp Num: mitMFH180705145548 Rel Insp Num: Inspector Name: Matt Herrera Inspection Date: 7/5/2018 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-09 --4Type Inl T G TVD 7492 Tubing 3238 239 3237 3236 ' PTD 1760680 BBL Pumped: Type Test SPT Test psi 1873 IA 0 2500 2473 2465 ' 3s BBL Returned: 3.6 OA 0 0 1 1 Interval. 4YRTST �p/F P Notes: IA pressure tested to 2500 per Operator SCANNED IWIG u 91 a6 Thursday, July 05, 2018 Page 1 of 1 MEMORANDUM • TO: Jim Regg �� 7 �� t P.I. Supervisor S FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL 9 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 05, 2018 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. NGI-09 PRUDHOE BAY UNIT NGI-09 Src: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UNIT NGI-09 API Well Number 50-029-20228-00-00 Inspector Name: Guy Cook Permit Number: 176-068-0 Inspection Date: 7/4/2018 Insp Num: mitGDC180704115824 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We111 P D -t NG1-09 1760680 Type Inj 1,Type 'fest G -TVD SPT Test psi 7492 1873 Tubing IA 3192 9 3190 25002489 3195 3206 2521 3209 2550 3213 - 2571 BBL Pumped: 3.6 BBL Returned: 3.4 OA 2 2 2 2 2 2 Interval 4YRTST P/F I Notes: A triplex pump and bleed trailer were used for testing. The IA pressure was bled off to 6 psi instead of 9 after testing was completed to get the BBLs returned. r 't"� d -6 SCANtfifl AUG 0 Thursday, July 05, 2018 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 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate H 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 H 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 176-068 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service H 6. API Number: 50-029-20228-00-00 7. Property Designation(Lease Number): ADL 0028302 8. Well Name and Number: PBU NGI-09 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: RECEIVED Total Depth: measured 10980 feet Plugs measured feet true vertical 8615 feet Junk measured 10399/10855 feet SEP 1 3 2017 Effective Depth: measured 10893 feet Packer measured 9401 feet true vertical 8550 feet Packer true vertical 7495 feet 1k CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 31-111 31-111 1530 520 Surface 2689 13-3/8"72#MN-80 30-2718 30-2718 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1544 7"29#MN-80 9432-10976 7515-8612 8160 7020 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet SCANNED DEC 1 4 20171 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 7"Baker S-3 Packer 9401 7495 true vertical depth) 7"MCX SSSV 2201 2201 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10293-10861'. Treatment descriptions including volumes used and final pressure: 20 Bbls 50/50 Methanol/Water,202 Bbls Diesel/Xylene,580 Fresh Water w/0.02%Surfactant,256 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -183968 220 3379 Subsequent to operation: -167876 220 3210 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ H 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: 317-315 Authorized Name: Oestgaard,Finn Contact Name: Stone,Christopher Authorized Title: ProductionLngineer Challenger Contact Email: Christopher.Stone@bp.com Authorized Signature: — (5...2.‘4 Date: °/'13—17 Contact Phone: +1 907 564 5518 Form 10-404 Revised 04/201 Q/iri7 V +i 101 7"1 T q �`('�/� ��n�!,�' ‘-f'°1 ') s, ?Pi? 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-09, PTD # 176-068 covered under Sundry Approval # 317-315. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. 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ACTUATOR= BAKER 09 OKB.ELEV= 4T, I !/ K BF.ELEV= 4 • KOP= 7 / •j ►moi 2190' H 7-5/8"X 7"XO,D=6.276" Max Angle= 55'@ 8697' Y ♦4 .♦0 20'CONDUCTOR 100' 1 • V 2201' Hr CAMCO DB-6 NP,D=6.00" Datum MD= 11288' 4 •0, �♦ 4 Datum TVD= 8800'SS ♦� • 1,4 7-5/8'TBG-IPC,29 7#L-80,VAMTOP HC, H 2190' 40 ♦ 2212' —T X 7-5l8"XO,D=6.276" • 0459 bpf,D=6.875' ►7i 2256' —I9-5/8'I Gi BSSv CEMENTER 9-5/8"CSG,47#,L-80,TCI 1,ID=8.681' }— 2266' 9-5/8"CSG,47#,SOO-95 XO TO MN-80 f— 2682' 13-3/8"CSG,72#,MN-80,D=12.347" — 2715' Minimum ID = 5.770" @a 9420' 7' HES RN NIPPLE ` 9363' _H7-5/8"X 7"XO,D=6.276" 7-5/8'TBG,29.7#L-80,VAM TOP HC, — 9363' .0459 bpf,U.-,6.875" ' i 9374' —7"HES R NP,D=5.963" 9396' --{9-5/8"X 7"BKR S-3 PKR,D=6.00" 1 II 9420' H7"HES RN M'D=5.770" TOP OF 7"LNR — 9431' 7"TBG,26#,L-80,Tql 0383 bpf,D=6.276" —I 9442' 9442' J-17"WLEG,ID=6.200"(2"ABOVE LEP) 9-5/8"CSG,47#,MN-80,S00-95,D=8.681" f— 9750' aii Haw TT NOT LOGGED FERFORATION s i .t i Y 9431' —19-5/8"X 7"LNR HGR,D=?" RB LOG:BHCS ON 10/11/76 ANGLE AT TOP PERF:43`@ 10293' Note:Refer to Production DB for historical perf data SIZE SPF PITERVAL Opn/Sqz SHOT SQZI 3-3/8" 4 10293-10356 0 07/21/90ill, ?? — FISH-2 METAL BACKUP RINGS(06/30/14) ? ? 10416-10433 0 06/12/77 3-3/8" 4 10433-10453 0 02/27/87 ? ? 10453-10467 0 06112/77 ' 3-3/8" 4 10467-10482 0 02/27/87 7 7 10482- 10502 0 06/12/77 ' 3-3/8" 4 10518- 10529 0 02127/87 7 7 10529- 10552 0 06/12/77 3-3/8" 4 10552- 10570 0 02/27/87I 7 7 10570-10605 0 06/12/77 ? ? 10621- 10646 0 06/12/77 ' 3-3/8" 4 10646- 10656 0 02/27/87 ? 7 10662- 10700 0 06/12/77 3-3/8" 4 10700- 10712 0 02127/87 3-3/8" 4 10726-10736 0 02/27/87 ? 7 10754-10779 0 06/12/77 3-3/8" 4 10779- 10805 0 02/27/87 ? ? 10810 10835 O 06/12/77 41Ikr 108555' --{FISH-IBP DEBRIS(TAGGED 06/05/06) s 7 10851 - 10861 O 06/12/77 PBTD H 10893' 4.....1 TD 10980' 7"LNR 29#,MN-80,.0371 bpf,D=6.184" — 10975' �....`..�� �. .` 4 DATE REV BY COMMENTS DATE REV BY COMMENTS 'ffS PRUDI IOE BAY UNIT 10/23/76 C51 ORIGINAL COMPLETION 07/29/14 MSS/PJC RIL ACX/FISH DH(6130/14) WELL. NGI 09 01/24/91 N2t RWO — — PERMIT Pb:'1760680 06/06/06 Not WJO AFI No 50-029-20228-00 05/25/07 LBS/PJC DRG DRAFT CORRELTION J SEC 1,T11 N,R14E 20'FSL&940'FWL 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE 09/18113 GJB/JMD SET FISH(08/03/13) BP Exploration(Alaska) • OF 7'4 • • ,0),,I y �s, THE STATE Alaska Oil and Gas ti "' �� of TA Conservation Commission AL OM �� 333 West Seventh Avenue 2 C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *ti Main: 907.279.1433 of ALABY) Fax: 907.276.7542 www.aogcc.alaska.gov Christopher Stone SCANNED Ali, 2 020i, DS2and18PE BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU NGI-09 Permit to Drill Number: 176-068 Sundry Number: 317-315 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, LDC:lc----\_.____ Hollis S. French } - Chair J DATED this t 7- day day of July, 2017. RBDMS 1,'JUL 1 3 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIIo�ION APPLICATION FOR SUNDRY APPRW_S 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate EF 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 ®• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 176-068 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 99519-6612 Stratigraphic 0 Service 53• 6. API Number: 50-029-20228-00-00 • 7. If perforating: 8. Well Name and " —: -- What Regulation or Conservation Order governs well spacing in this pool? " ` ' Will planned perforations require a spacing exception? Yes 0 No D PBU NGI-09 9. Property Designation(Lease Number): 10. Field/Pools: ,jU(., 1. Q 2017 ADL 0028302 • PRUDHOE BAY,PRUDHOE OIL • OA 2 j i Z./ 17 11. PRESENT WELL CONDITION SUMMARY ,A()G CC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10980 . 8615 • 10893 8550 10399/10855 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 31-111 31 -111 1530 520 Surface 2689 13-3/8"72#MN-80 30-2718 30-2718 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1544 7"29#MN-80 9432-10976 7515-8612 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: 7"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 9401, 7495 7"MCX SSV 2201, 2201 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program H BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 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 ❑ SPLUG 0 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 SiDS 2& 8 PE Authorized Signature: S) �b Date: 4,/16`i COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31- 315 Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No / Spacing Exception Required? Yes CIL�No Subsequent Form Required: 10 —4o4 APPROVED BYTHE It_. Approved by: — COMMISSIONERit122°-- COMMISSION Dater II. ,1 4 ,< ' RBDMS L L-JUL 1 3 2017 ^ ORIGINAL 1Q. ter.Z 1-1 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate d71117 A15 7.n.1'7 • • • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEiVED Jul_. 1 0 2017 RE: BP Exploration (Alaska), Inc. AOGCC 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-09, PTD # 176-068. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 BP Exploration (Alaska), Inc. P.O. 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ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0, DBR, LHD,EAZ,BPG 10/12/15) General Information Well Name: NGI-09 Well Type: Gas Injection Well API Number: 50-029-20228-00 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 Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting iMscf/Day) Cut(%) (Mscf!Day) (psi) 6/26/2017 0 3,491 Current Status: Operable Flowing Inclination>70°at Depth(ft) N/A Recent H2S (date, ppm) NA 0 ppm Maximum Deviation(Angle and 55° 8,697'MD Depth) Datum depth,ft TVDss 8.800'TVDss Dogleg Severity(Angle and Depth) 5° 4,195' MD Reservoir pressure(date, Est 3,407 psi Minimum ID and Depth 5.770" 9.420' MD psig) Reservoir Temp, F 163° F Shut-in Wellhead Pressure Est. 2525 psi Known mech. integrity None problems(specifics) Last downhole operation(date, operation) 7/1/2014 Set 7"Al SSSV at 2201' Most recent TD tag(date, depth, toolstring OD) 6/22/2012 10.525' MD 3.50"Cent&SB Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, NGI-09 is a gas injector that was originally drilled and completed in October 1976. In June 2006. a RWO background information, was performed to mitigate TxIA communication and replace the upper 9-5/8"casing with premium thread etc: casing cemented on the backside to surface. The last water wash was pumped 9/1/10 and saw a 20 mmscfpd increase in injection rates. The job pumped 50 bbls 60 F diesel/xylene. 560 bbls 100 F fresh water w/0.02% F-103 surfactant. This wash will use D/X to try and mimic and hopefully improve on the success of the September 2010 wash. We are intentionally choosing to increase the temperature of the diesel/xylene solvent to 70 F in an attempt to see if positive results can be achieved. • • Well Intervention Details Please contact the SOR author if 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 injectivity due to depositions. Specific Intervention or Well Objectives: 1 Pump diesel/xylene water wash to restore injectivity by cleaning perfs and tubing. 2 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 In RP: CTU Operations-Fluids outlines heating limits for xylene/diesel. In this it outlines LRS will heat xylene 3 Heating diesel/xylene during pumping process to 70F in a tank and to 100E if kept inside the pipe but no more than 5 deg less than flashpoint.50/50 diesel/xylene has a flashpoint of 87F as per lab testing 9/6/15 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:I 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 1t3t= , 7-1/16'CNV • NGI-09 NOTES: WELL REt31JIRES A SSSV°'< ACTUATOR= BAKER OKB-ELEV= 47' 1 w1 • BF ELEV= 4 ►*4 KOP= 7 j ►i$ 2190' --{7-5/8"X 7"XO,D=6.276" •� g Max Angle= 55' 869T 20'CONDUCTOR — 100' , 1 V 2201' H 7"CAMNI CO DB-6 P,0=6.00" •Datum MD= 11288' "' ►i Datum TVD= 8800'SS *1 ►!f 7-518'TBGAPC.29.7#L-80,VAM TOP HC, H 2190' to ��f 2212' 7"X 7-5/8"X0,D=6.276" 0459 bpf,D=6.875" f 2256' —9-5/8"HES ESSV CEMENTER 9-518"CSG,47#,L-80,TC11,ID=8.681" — 2266' 9-518"CSG,47#,SOO-95 XO TO MN-80 1-- 2682' 13-3/8"CSG,72#,MN-80,0=12347" H 2715' Minimum ID =5.770" @ 9420' 7' HES RN NIPPLE 1 9363' —7-5/8"X 7"XO,D=6.276" 7-5/8'TBG.29 7#L-80,VAM TOP HC, 9363' 0459 bpf,D=6.875" 9374' —f 7"HES R NP,D=5.963" 9396' H9-5/8-X r BKR S-3 PKR D=6.00" 9420' H 7"I- RN NF?D=5.770" 11 1 TOP OF 7'LNR 1— 9431* 7"TBG,26#.L-80,TCN, 0383 bpf,D=6.276" H 9442' 9442' —7"WLEG,D=5.240"(2"A BOV E LTP) 9-5/8'CSG,47#,MN-80,SOO-95,D=8.681' H 9750' i� END TT NOT LOGGED PERFORATION SUMMARY 9431° 9-5/8"X 7"UR HGR,D=?" FIS LOG BRCS ON 10/11/76 ANGLE AT TOP PERF:43'@ 10293' Note:Refer to Production DB for historical pert data SCE SPF IINTERVAL Opn/Sgz SHOT I SOZ I 3-3/8" 4 10293-10356 i 0 07/21 1 1 ?? 1-- FISH-2 METAL BACKUP RINGS(06/30/14) l 7 7 10416-104331 0 06/12/771 3-3/8' 4 10433- 104531 0 02/27/87 7 7 10453- 104671 o 06/12/77 3-3/8" 4 10467- 10482 0 02/27/871 7 10482- 10502 0 06/12/77 3-3/8" 4 10518- 10529 0 02/27/871II 7 7 10529- 10552 0 06/12/771 3-3/8" 4 10552- 10570 0 02/27/87i I 7 7 10570- 10605 0 06/12/77 9 9 10621- 10646 0 06/12/77 3-3/8" 4 10646-10656' 0 02/27/87 9 9 10662-10700 0 06/12/77 3-3/8" 4 10700-107121 0 02/27/87 3-3/8" 1 4 10726- 10736 j 0 02/27/87 9 7 10754-107791 0 06/12/77 3-3/8" 4 10779-10805 0 02/27/87' 7 7 10810- 10835 O 06/12/77 4111Nr 10855' I FISH-CEP DEBRIS(TAGGED 06/05/06) 7 9 10851 -10861 O 06/12/77 I� I PBTD —1 10893' N4.401t4 TD H 10980' 7"LNR,29#,MN-80, 0371. bpf,D=6.184" — 10975' Ca`AkV-4 DATE REV BY COMMENTS DATE REV BY COMIvvrtTS PRIJHOE BAY !.NIT 10/23/76 C51ORIGINAL COMPLETION 07/29/14 MSS/PJC PULL MCX/FISH DH(6/30/14) _ WELL NGI-09 01/24/91 N2ES RWO FERMI No 9760680 06/06/061 N4BS ,RWO AR No: 50-029-20228-00 05/25/07 LBS/PJC DRG DRAFT CORRECTION I SEC 1 T11 N,R14E 20'FSL&940'FVVL 02/11/11 i MB/JMD ADDED SSSV SAFETY NOTE 1 - — 09/18/13 GJB/JMD SET FISH(08/03/13) 1 BP Exploration(Alas Ica) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 15 Min 30 Min 45 Min 60 Min DATE: Friday, July 25, 2014 TO: Jim Regg P.I. Supervisor 1 SUBJECT: Mechanical Integrity Tests TD j 1760680 BP EXPLORATION (ALASKA) INC } a a - NGI-09 FROM: Johnnie Hill PRUDHOE BAY UNIT NGI-09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,�S%� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-09 API Well Number 50-029-20228-00-00 Permit Number: 176-068-0 Insp Num: mitJWH140706161746 Rel Insp Num: Inspector Name: Johnnie Hill Inspection Date: 7/5/2014 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-09 (Type Inj G'TVD 7492 IA 158 2505 2482 2479 TD j 1760680 T e Test SPT Test st 1s73 OA a a } a a - ____�--- Intervalj4YRTST jp/F P Tubing 3360 3359 3358 3357 Notes: 3.1 bbls meth used SCANN� OCT 3 0 2014 Friday, July 25, 2014 Page 1 of 1 • MEMORANDUM To: Jim Regg ~~ ~ -~~Z'7~ l~, P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 27, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC NGI-09 PRUDHOE BAY UNIT NGI-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~-- Comm Well Name: PRUDHOE BAY UNIT NGI-09 Insp Num: mitJCr100722052844 Rel Insp Num: API Well Number: 50-029-20228-00-00 Permit Number: 176-068-0 Inspector Name: John Crisp Inspection Date: 7/21/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-09 ~ Type Inj. G ~ TVD 7492 ~ IA 340 2500 2520 2520 2520 P.T.D 1760680' TypeTest SPT Test psi ~ 1873 ~ OA 20 20 20 20 20 Interval 4YRTST p~Fi P ~ Tubing I 3500 3500 3500 3500 3500 Notes: 3.6 bbls pumped for test. Witnessed test for 45 minutes due to IA pressure increase. kk~t ~: . tiS'~.- ! . », ... Tuesday, July 27, 2010 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanics! Integrity Test Email to:jim.regg~alaska.gov; phcebe.brooks~afaska.gov; tom.maunder~afaska.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: BP F~cploratian (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / NGl Pad DATE: 0721 /10 OPERATOR REP: Torin Roschinger AOGCC REP: John Crisp s Packer Pretest Initial 15 Min. 30 Min. Well NGI-02 T In'. G TVD 7,289' Tu ' 3,000 3,000 3,000 3,000 Interval 4 P.T.D. 1750520 T test P Test 1822.25 500 2,500 2,490 2,520 PIF P Notes: AOGCC MIT-IA to 2500 psi for 4 year tJIC OA 130 148 140 140 45 minute results: T-3000 I-2520 0-140 Pum 2 hbls MEOH to xhieve test i Well NGI-09 T In'. G TVD 7,492' Tut~i 3,500 3,500 3,500 3,500 Interval 4 P.T.D. 1760680 T test P Test 1873 340 2,500 2,520 2,520 PIF P Notes: AOGCC MIT-IA to 2500 psi for 4 year UIC OA ZO 20 20 20 45 minute results: T-3a00 I-2520 0-20 Well NGI-14 T In'. G TVD 7,264 Tu ' 3,550 3,550 3,550 3,450 Interval 4 P.T.D. 1780920 T test P Test 1816 340 2,500 2,430 2,420 P/F P Notes: AOGCC MIT-IA to 2500 psi for 4 year UIC OA 340 1,240 1,360 1,440 Well T In'. TVD Tubi Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD Tu ' Interval P.T.D. T test Test Casi P/F Notes: OA _ t '~ri.~ ~~, ~, ~ :h~,' ~ .~ ~, s.~j _.j TYPE INJ Codes TYPE TEST Codes D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R = Intemal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test f~~~a ~rgl~ '° gla INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU NGI-02, 09, 14 07-21-10.x1s NGI &LPC injector due for UIC ~ing • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, RES GPB East Production Optimization Engineer [AKRESGPBEastProductionOptimizationEngineer@bp.com] Sent: Tuesday, July 13, 2010 8:32 AM To: Maunder, Thomas E (DOA) Subject: RE: NGI &LPC injector due for UIC testing Hello Tiffany, I assume these are the plants the State is referring to. I would take these dates as best estimates. GC1 is online now. LPC 7/14 startup GC1 Online as of 7/10 CGF Shut-down 7/15 - 8/6 Byron Jackson (alt. Ryan Rupert) ~~, , ;~~ ,~~L s ~~ yp GPB East Production Optimization Engineer 907.659.5923 office x2409 harmony AK, RES GPB East Production Optimization Engineer From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 13, 2010 8:25 AM To: AK, D&C Well Integrity Coordinator Cc: AK, RES GPB East Production Optimization Engineer; Brooks, Phoebe L (DOA) Subject: RE: NGI &LPC injector due for UIC testing Thanks Tiffany. What is the anticipated schedule for bringing the plants back on line? Tom Maunder, PE AOGCC From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Monday, July 12, 2010 7:34 PM To: Maunder, Thomas E (DOA); AK, D&C Well Integrity Coordinator Cc: AK, RES GPB East Production Optimization Engineer Subject: NGI &LPC injector due for UIC testing Thomas, Per our conversation, the following injectors are due for UIC compliance testing and shut in due to facility work. The wells will be put back on injection as the plants are brought back on line. Once thermally stable, we will proceed with AOGCC witnessed MIT-IA's. There are no known downhole integrity issues with any of these injectors. NGI Gas Injectors: NGI-02 PTD #1750520) GI-09 (PTD #1760680) NGI-14 (PTD #1780920) 7/13/2010 NGI &LPC injector due for UIC ~ng ~ Page 2 of 2 LPC SWI injector: P1-21 (PTD #1930590) Please contact Well Integrity with any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Gerald Murphy/Torin Roschinger) Projects Well Integrity Engineer phone: (907) 659-5102 cell: (253) 576-6153 tiffg0@bp.com 7/13/2010 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ \ / " \.jt!.t¡· \ \r ¡ DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-09 PRUDHOE BAY UNIT NGI-09 (0 ß \1(0,0 Src: Inspector Reviewed By: ----~ (? P.I. Suprv ~ )f;ì~- Comm FROM: Jeff Jones Petroleum Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT NGI-09 API Well Number 50-029-20228-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060711202100 Permit Number: 1 76-068-0 Inspection Date: 7/6/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! NGI-09 IType Inj. i G ITVD I 7492 I IA I 40 I 2010 i 2080 I 2215 i 2275 i 2305 I i ì P.T. i 1760680 !TypeTest ì SPT i Test psi : 1873 ! OA i 0 i 0 I 7 7 i 7 7 I ! I Interval INITAL P/F F v Tubing! 3500 i 3525 i 3525 ì 3525 i 3525 I 3575 i Notes 2.4 bbls methanol pumped.lA pressure failed to stabilize; injection gas temp- 154 deg F, methanol temp- 45 deg. F. I well house inspected; no exceptions noted. /\·.:L~ j k~"y({ -, (~~{, f .¿.) t.A....; $CJ\.~~f:D ~. .,.., <¡.' ~¡, Wednesday, July 12,2006 Page I of I MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor <"J K&}; ) (l -}", 0"'1'" /,¿....:_) :..~;. DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1_ ~ NGI-09 I "D 'V 1) PRUDHOE BA Y UNIT NGI-09 (<) to FROM: JeffJones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv . ::J1::--?- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT NGI-09 API Well Number 50-029-20228-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ06071 1204207 Permit Number: 17 6-068-0 Inspection Date: 7/8/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well : NGI-09 ! . : G I I IA I 2010 2010 ¡Type InJ. ! I TVD 7492 ¡ 60 2010 , P.T. ! 1760680 ITypeTest i SPT ! Test psi 1873 lOA I 0 10 10 10 , Interval INIT AL P/F P Tubing: 3500 3500 3500 3500 Notes 2.8 bbls diesel pumped. I well house inspected; no exceptions noted. It~Z--- (.\ t"' 0;0>.. Wednesday, July 12, 2006 Page I of I STATE OF ALASKA RECEIVED ALASKAaIL AND GAS CONSERVATION C_MISSION ..J.UN 2 7 2006 REPORT OF SUNDRY WELL OPERATIONs C-- Alaska Oil & Gas Cons. onmsSIOII 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program ~ Repair Well ~ Pull Tubing o Operation Shutdown o Other o Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028302 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 47' 10980 8615 10893 8549 72' 2715' 9750' 1544' o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension 4. Well Class Before Work: o Development 0 Exploratory o Stratigraphic ~ Service 99519-6612 176-068 6. API Number: 50-029-20228-00-00 9. Well Name and Number: PBU NGI-09 10. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) 10855 feet Size MD TVD Burst Collapse 20" 72' 72' 1530 520 13-3/8" 2715' 2715' 5380 2670 9-5/8" 9750' 7721' 6870 4760 7" 9431' -10975' 7514' - 8611' 8160 7020 i~~ ¿~ 10293' -10861' 8105' - 8525' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl 7-5/8" x 7", 26# x 29.7# L-80 9442' Tubing Size (size, grade, and measured depth): 9396' 9-5/8" x 7" Baker 'S-3' Packer Packers and SSSV (type and measured depth): RBDMS 8Ft JUN 2 8 2006 Treatment description including volumes used and final pressure: Cut and pulled tubing. Cut and pulled about 2269' of 9-5/8" casing. Run new 9-5/8" casing and cement with 151 Bbls (848 cu ft 1731 sx). Run new completion string. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Representative Dail Avera e Production or Injection Data Gas-Met Water-Bbl Casin Pressure Tubin Pressure 15. Well Class after proposed work: o Exploratory 0 Development ~ Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG ~ GINJ 0 WINJ 0 WDSPL t at the oregomg is true and correct to t e best 0 my nowledge. Sundry Number or N/A if C.O. Exempt David Reem, 564-5743 306-170 o Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Well Schematic Diagram Signature Form 10-404 Revised 04/2006 0 RIG I r~ A L I hereby certl Contact Printed Name Terrie Hubble Title Technical Assistant Phone Date DG;/Zð Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 e e NGI-09 Prudhoe Bay Unit 50-029-20228-00 176-068 Accept: Spud: Release: Ri: 05/18/06 NIA 06106106 Nabors 4ES PRE-RIG WORK 05/05/06 RIG UP AND PREP SURFACE EQUIP FOR PRESSURE TEST. 05/06/06 PULLED 7" WRDP-2 (SER #HES-953 W/ (2) SET O.S PKG, (2) PIECES EACH SIDE OF CENTER RINGS), DRIFTED W/ 4.50 CENT, TAGGED TOP OF 41/2" XO AT 9418' SlM, 9444' CORR MD (+ 26' CORR FROM XN- NIP), BRUSHED XN NIP AT 9439' SLM, PUMP TRUCK lOADED WEll, SET 41/2" PXN PLUG BODY AND PRONG ( PRONG 1.75 FN-W/ 3.60 CENT-107" OAl) AT 9439' SlM. MIT-T TO 3000 ( PASSED). T/I/O= 2550/475/480 TEMP = SI ASSIST SLlCKLlNE WI WEll Kill, MIT TBG TO 3000 PSI PASSED (RWO PREP) SPEARED IN W/ 10 BBlS OF 60/40 METH/WATER. FOllOWED UP W/ 360 BBlS OF BRINE/FRESH WATER (MIXTURE 170/190 BBlS), 216 BBlS OF 1% KCl DOWN TBG. FREEZE PROTECT TBG W/ 100 BBlS OF 60/40 METH/WATER. SSl SET PLUG. MIT TBG TO 3000 PSI.. PRESSURE UP TBG WI 42 BBlS OF AMBIENT 60/40 METH WATER 1ST TEST 1ST 15 MIN lOST 40 PSI 2ND 15 MIN lOST 20 PSI FOR A TOTAL OF 60 PSI. 30 MIN UNABLE TO BLEED TBG GAS S-LlNE Will BLEED TBG PSI DOWN FINAL WHP'S 2900/450/470. 05/07/06 T/I/O=420/370/440. TEMP=SI. PRE-CAMERON. (PRE-PPPOT). BOTH IA AND OA CASING VALVES HAVE INTEGRAL FLANGES INSTAllED. 05/08/06 INITIAL T/I/O 400/450/460. JET CUT TUBING AT 9420' WITH 4.15" POWER CUTTER. TIED INTO TUBING TAllY DATED 1-24-91. CUT MID-JOINT IN 6' PUP JOINT ABOVE PACKER AS PER PROGRAM. FINAL T/I/O 500/400/425. WEll SHUT-IN UPON ARRIVAL, lEFT SHUT-IN. 05/11/06 T/I/O = 420/420/40. CMIT TXIA TO 2500 PSI; MIT OA TO 2500 PSI. 05/12/06 CIRC OUT. PUMPED 5 BBl 60/40 METHANOL SPEAR, FOllOWED BY 920 BBlS 1% KCl, FREEZE PROTECT TUBING AND IA WITH 140 BBlS DIESEL. CMIT TXIA TO 2500 PSI. PASSED. PUMPED 6.5 BBlS DIESEL DOWN IA TO REACH TEST PRESSURE. TUBING lOST 100 PSI IN THE 1ST 15 MIN AND 50 PSI IN THE 2ND 15 MIN. IA lOST 110 PSI IN THE 1 ST 15 MIN AND 40 PSI IN THE 2ND 15 MIN. TOTAL lOSS IN 30 MIN= 150 PSI ON THE TUBING/150 PSI ON THE IA. BLEED DOWN TXIA TO 0 PSI. ATTEMPTED TO MIT OA TO 2500 PSI, IA AND TUBING TRACKED WITH OA, CHANGED JOB SCOPE. CMIT TXIAXOA TO 2500 PSI. PASSED. PUMPED 5.5 BBlS OF DIESEL DOWN OA TO REACH TEST PRESSURE. TUBING lOST 0 PSI IN THE 1ST 15 MIN AND 25 PSI IN THE 2ND 15 MIN. IA lOST 20 PSI IN THE 1ST 15 MIN AND 20 PSI IN THE 2ND 15 MIN. OA lOST 20 PSI IN THE 1ST 15 MIN AND 20 PSI IN THE 2ND 15 MIN. TOTAL LOSS IN 30 MIN= 25 PSI ON THE TUBING.l40 PSI ON THE 1A/40 PSI ON THE OA. FINAL WHP'S = 010/0. 05/13/06 WELL HEAD MIT CYCLE ALL LDS AND ALIGNMENT PIN ON TUBING SPOOL. NO SIGNS OF ANY BENT OR BROKEN LOS. TEST TUBING HANGER TO 5000 PSI. FOR 30 MINUTES. CYCLE ALL lDS AND ALIGNMENT PIN ON "B" SECTION AND UPPER SET ON CASING SPOOL. ALL LOS OPERATE SMOOTH. ATTEMPT TO TEST 9-5/8 IC HANGER ON UPPER TEST PORT. UNABLE TO BUILO ANY PRESSURE AFTER PUMPING 1- 1/2 GALLONS FLUID. MOVE TO LOWER PORT BELOW LDS AND PUMP OVER 1-1/2 GALLONS FLUID, NO INCREASE OF PRESSURE. IC HANGER FAILED. e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 61612006 5/17/2006 13:00 - 15:00 2.00 RIGD P PRE Lower Derrick. Rig-down remaining Modules. 15:00 - 18:00 3.00 RIGD N WAIT PRE Wait on Other Rig moves in progress. Wait on Trucks 18:00 - 19:30 1.50 RIGD P PRE Pull sub Base off of Well. Pick-up Mat Boards and Herculite. 19:30 - 00:00 4.50 MOB P PRE Move Rig and Modules from Drill Site 12 to NGI Pad. 5/18/2006 00:00 - 02:30 2.50 MOB P PRE Continue moving from Drill Site 12 to NGI Pad. 02:30 - 03:30 1.00 RIGU P PRE Lay Herculite and Mat Boards. Spot Sub Base, Pipe Shed, Pipe Shed, and Camp (Camp is 120' from the nearest Well). 03:30 - 04:00 0.50 RIGU P PRE Raise and scope Derrick. Accept Rig at 04:00 hrs. 04:00 - 07:30 3.50 RIGU P PRE Continue with Rig-up. Build berm and spot tiger Tank. Lay Lines. Begin to take on Sea Water (100 degs). 07:30 - 08:30 1.00 KILL P DECOMP Pick-up Lubricator. Pull BPV. Lay down same. WHP =0 psi. 08:30 - 09:30 1.00 KILL P DECOMP Test Lines at 250/3500 psi. Continue to take on Sea Water in Pits. 09:30 - 10:00 0.50 KILL P DECOMP PSJM - - well kill with all. 10:00 - 13:00 3.00 KILL P DECOMP Circulate Well bore with 100 deg F. Sea Water at 3 pbm/200 psi. Total Sea Water pumped = 605 bbls. 13:00 - 14:30 1.50 WHSUR P DECOMP Pick-up Lubricator. Install BPV. Lay down Lubricator. 14:30 - 16:00 1.50 WHSUR P DECOMP Nipple down Injection Tree. Cameron installed Dart in BPV. 16:00 - 19:00 3.00 BOPSU P DECOMP Nipple-up Double-Stud-Adaptor. Nipple-up BOP Stack. 19:00 - 20:00 1.00 BOPSU P DECOMP Change out RBRs for 7" casing rams. 20:00 - 00:00 4.00 BOPSU P DECOMP Pressure test BOPE as per BP/ AOGCC requirements. LP 250 psi, HP 4000 psi. No failures. BOP test witnessing waived by John Crisp w/ AOGCC @ 1840 hrs. 5/18/2006. 5/19/2006 00:00 - 00:30 0.50 BOPSU P DECOMP Finish BOP test as per BP/AOGCC requirements. LP 250 psi, HP 4000 psi. No failures. Test waived by John Crisp w/ AOGCC. 00:30 - 01 :00 0.50 BOPSU P DECOMP N/D test equip. Blow down lines. Drain stack. 01 :00 - 02:00 1.00 WHSUR P DECOMP P/U lubricator. Pull test dart & BPV. UD lubricator. 02:00 - 02:30 0.50 WHSUR P DECOMP Circulate out residual diesel from freeze protect. Recovered approx 13 bbls. 02:30 - 03:30 1.00 PULL P DECOMP M/U double spear assy on 1 jt of 3 1/2" DP. . BOLDS. Pull on completion. Hanger pulled free @ 255K. Tubing pulled free @ 270K. While pulling thru stack string was dragging from 225 to 240K. Pulled hanger to floor. 03:30 - 04:30 1.00 PULL P DECOMP Break out & UD spear. & single jt of 31/2" DP. Deadhead control lines & UD hanger. M/U circulating pin on 7" tubing. 04:30 - 07:00 2.50 PULL P DECOMP Rig-up Spooling Unit. Mix 1 bbl of EP lube in 50 bbls & circulate well. 6BPM @ 350 psi. No Losses. 07:00 - 09:00 2.00 PULL P DECOMP Start to lay down 7" 26 Ib/ft L·80 STC Tubing and Control Line. 09:00 - 09:30 0.50 PULL P DECOMP Stop to lay down SSSV. Recovered Control Lines complete and all SS Bands. Rig down Camco Spooling Unit. 09:30 - 15:00 5.50 PULL P DECOMP Finish laying down 7" Tubing. Recovered 217 jts 7" 26 Ib/ft L-80 STC IPC, SSSV, XO, 5 1/2" Jet-Cut stub. 15:00 - 16:00 1.00 PULL P DECOMP Clear and clean Rig Floor 16:00 - 17:00 1.00 PULL P DECOMP Drain BOP stack. Install test plug. 17:00 - 19:30 2.50 BOPSU P DECOMP Change out 7" pipe rams to 3 1/2" x 6" VBRs. Had to retap 4 door bolt holes. 19:30 - 21:00 1.50 BOPSU P DECOMP M/U test jt. Pressure test VBRs.. LP 250 psi, HP 4000 psi, Tested good. UD test jt. RID test equip & pull Test Plug. 21 :00 - 22:00 1.00 PULL P DECOMP Break out & UD 7" Spear Assy. Clear & clean rig floor. 22:00 - 00:00 2.00 PULL P DECOMP P/U BHA # 2 as follows: Bull Nose, 5 1/2" spear, XO, XO, Bumper Sub, Jars, XO, 9 . 6 1/4" DCs, XO, Accelerator, XO, Pump Out Sub. TL = 326.14'. Printed: 6/12/2006 9:40:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 616/2006 5/20/2006 00:00 - 05:00 5.00 FISH P DECOMP P/U 3 1/2" DP 1x1 & RIH w/ BHA #2. Ran hole wi 176 jts. 05:00 - 06:30 1.50 FISH P DECOMP Cut & slip 84' of drilling line. 06:30 - 09:00 2.50 FISH P DECOMP Finish single in with BHA and 3 1/2" Drill Pipe (287 jts). PUW = 140K. SOW = 105K. Park Spear just above Fish. Begin waiting on Vac Trucks with our 10.2 Brine. 09:00 - 12:30 3.50 FISH N WAIT DECOMP Waiting on Vac Trucks. First Vac Truck arrives on loaction at 10:40 hrs. Off-load first Vac and send back to re-Ioad. Second Vack arrives on location. 12:30 - 15:00 2.50 FISH P DECOMP Circulate Well over to 10.2Ib/gal Brine at 4.0 bpm1700 psi. 15:00 - 16:00 1.00 FISH P DECOMP Pick-up Kelly Tag Top of Fish at 9,414'. Plant Spear. Jar Locator Sub and Seal Assembly free. 16:00 - 18:00 2.00 FISH P DECOMP Circulate bottoms up at 5.0 bpm/1500 psi. 18:00 - 18:30 0.50 FISH P DECOMP Monitor well. 18:30 - 21 :30 3.00 FISH P DECOMP POOH & stand back 95 stands odf 31/2" DP. 21 :30 - 22:30 1.00 FISH P DECOMP UD accelerator, stand back 6 1/4" DCs. Pull fish to floor. 22:30 - 23:00 0.50 FISH P DECOMP Break fish out of Spear Assy. UD Spear Assy. Recovered Cut off pup jt 3.38' + Baker G-22 Seal Assy w/ 9 sets of seals. 12.65'. Top of Baker Mod FB-1 packer @ 9419' DPM. 23:00 - 00:00 1.00 FISH P DECOMP Clear & clean rig floor. Hold PJSM. 5/21/2006 00:00 - 01 :30 1.50 FISH P DECOMP M/U BHA # 3 as follows: PRT & Extensions, Pakr MiIITrple Connect, 2 - Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9- 6 1/4" DCs, XO, Accelerator, XO, Pump Out Sub. TL = 345.34'. RIH w/ same. 01 :30 - 04:30 3.00 FISH P DECOMP RIH wI 95 stands of 3 1/2" Drill Pipe + 2 singles. 04:30 - 06:00 1.50 FISH P DECOMP P/U Kelly & break circulation. Tag up 8' in on kelly = 9424'. Rotate & wash down to 18' in on kelly. This puts the mill on the packer @ 9419'. Begin milling packer. P/U Wt = 136K, S/O Wt = 11 OK, Rot Wt = 130K. Circ 3 BPM @ 500 psi. WOB 3-5K, 60 RPMs, Torq 3K. 06:00 - 06:30 0.50 FISH P DECOMP Continue Milling Ops. Lost 100% returns (as in right now, as expected), Pick-up off Packer. Stop rotating. Increase pump rate to 6.1 bbls/min at 1175 psi. Pump 100 bbls at max rate to sweep 7" Liner (Liner volume -55 bbls). Final rate = 6.0 bpm/1700 psi with no returns. 06:30 . 07:00 0.50 FISH P DECOMP Reduce pump rate back to 3.0 bpm/500 psi. Continue Milling Ops to finish milling up PackerlTailpipe Assembly. 07:00 - 10:00 3.00 FISH P DECOMP Push PackerlTailpipe Assembly down to top of 7" Liner at 9,431'. Pull back up hole with no problems. Yo-Yo Fish several times with no problems. Park Fish. Continue to pump 10.2 Ib/gal Brine at 3.0 bpm/500 psi to finish clearing Pits (870 bbls total pumped down hole). Never caught returns with 10.2 Ib/gal Brine (278 psi over balance). Start Sea Water, pumping down the back-side at 4.5 bpm/125 psi, to bring fluid level to surface. Returns to surface after -290 bbls of Sea Water pumped. Reduce rate to 4.0 bpm. Loosing 3.5 bpm. Continue to maintain Pump present rate. Losses now 3.25 bpm. Swap over to Charge Pump. Fluid level dropping slightly at max Charge Pump rate (3.1 bpm). 10:00 - 14:00 4.00 FISH P DECOMP Set back Kelly. Start Trip out with 3 1/2" Drill Pipe, BHA, and Packer Fish. Maintain hole fill with Charge Pump. With 20 stands out. Flow check Well with Rig Pump to catch-up. Pumped 39 bbls = working fluid level -530'. Continue Tripping out and maintain hole fill with Charge Pump. Printed: 6/12/2006 9:40:45 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 61612006 5/21/2006 14:00 - 14:30 0.50 FISH P DECOMP BHA at Surface. No-Joy. Did not recover Fish. Lay down MiIl/PRT. The PRT stop ring was bottomed-out, however it appears that the spear did not "bit" on anything in the MiII-Out-Extention. Charge Pump is keeping hole with sight returns to Pits. Lay down MiII/PRT. 14:30 - 15:30 1.00 FISH P DECOMP Clear and clean Rig Floor. Prep for next BHA. 15:30 - 16:00 0.50 FISH P DECOMP Make-up BHA #4 as follows: 16:00 - 20:00 4.00 FISH P DECOMP RIH wI 95 stands 31/2" DP + 2 singles. 20:00 - 22:00 2.00 FISH P DECOMP P/U kelly break circulation. P/U Wt = 140K, S/O Wt = 110K Wash down & Tag up & engage fish @ 9422'. P/U & attempt to pull free. No joy. Losses to perfs have ceased. Appear to be packed off around packer. Begin jarring on fish & work pipe as follows: 2 licks @ 175K, 4 licks @ 225K, 33 Hits @ 250K. No movement in pipe after jarring & working continuously. Release Spear from fish. 22:00 - 00:00 2.00 FISH P DECOMP Set back kelly & POOH w/3 1/2" DP & BHA #4. 5/22/2006 00:00 - 01 :30 1.50 FISH P DECOMP Con't to POOH & stand back 3 1/2" DP. Took correct fill. No Losses. 01 :30 - 02:30 1.00 FISH P DECOMP Stand back DCs & break out & UD 7" Spear Assy. 02:30 - 03:30 1.00 FISH P DECOMP P/U BHA #5 & RIH as Follows: PRTwl Extensions, 8 1/2" Packer Mill, Triple connection sub, 2 Boot Baskets, Bit, Sub, Bumper Sub, Jars, XO, 9* 61/4" DCs, XO, Accelerator, XO, Pump Out Sub. TL = 345.34'. 03:30 - 07:00 3.50 FISH P DECOMP RIH w/95 stands of 31/2" DP. PUW = 136K. SOW = 107K. 07:00 - 07:30 0.50 FISH P DECOMP Pick-up Kelly. ROTWT = 120K. Bring pump on line at 5 bpm/1175 psi. 07:30 - 09:30 2.00 FISH P DECOMP Tag top of Packer/Tailpipe at 9421' (with Pkr Mill). Resume Milling Ops. Work Packer/Tailpipe back down to 9,122'. No fluid losses. After -30 minutes of milling. Packer/Tailpipe fell 2.5'. Fluid loss now .75 - 1.75 bpm. Continue milling down to 9,425'. 09:30 - 10:00 0.50 FISH P DECOMP Shut down Rig Pump. Line-up Charge Pump down back-side. Work Packer/Tailpipe free. Move up-hole with 20 25K over pull. 10:00 - 14:30 4.50 FISH P DECOMP Set back Kelly. Trip out with 31/2" Drill Pipe. Still have some drag and had to pull 175 K once to get through a Casing Collar. Well drinking Sea Water and Charge Pump can not keep up. Kick in Rig Pump every 20 stands to catch back-up. 14:30 - 15:00 0.50 FISH P DECOMP Lay down BHA #5. Recovered remaining Paker/Tailpipe Assembly. Evidence on Mill-Out-Extention showed that large pieces from the Milled Packer had wedged the Tailpipe between the Casing or Liner top. 15:00 - 16:00 1.00 FISH P DECOMP Clear and clean Rig Floor. Prep for next run. 16:00 - 20:00 4.00 FISH P DECOMP RIH WI 95 stands 31/2" DP. P/U & RIH 15 singles. 20:00 - 20:30 0.50 FISH P DECOMP P/U 24' pup jt of 31/2" DP. RIH & Space out CBP @ 9508'. P/U Wt = 127K, SIO Wt = 100K. Rotate 37 turns. Got 2 turns back. P/U in 15K increments then wait 2 min. Repeat until Tool sheared @ 175K. S/O 20K & insure set. P/U & Prep to CBU. Hole filled while setting CBP. 20:30 - 23:00 2.50 FISH P DECOMP Circulate bottoms up prior to testing plug. Pumped 6 BPM @ 1400 psi. No losses.. Much gas to surface. Slowed pump to 3 BPM @ 7000 strokes, then Increased to 6BPM @ 9500 Strokes. Circulate 12000 strokes. (surf to surf). SID, Well Printed: 6/12/2006 9:40:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 6/612006 5/22/2006 20:30 - 23:00 2.50 FISH P DECOMP static. 23:00 - 23:30 0.50 FISH P DECOMP Close in well & Pressure test CBP to 2500 psi for 15 min. Charted same. Test Good. Bleed off & RID test equip. 23:30 - 00:00 0.50 FISH P DECOMP POOH & UD pup jt & 15 singles. Con't to POH & stand back DP. 5/23/2006 00:00 - 03:00 3.00 FISH P DECOMP POOH & stand back 95 stands of 31/2" DP. 03:00 - 04:00 1.00 FISH P DECOMP M/U BHA # 6 as follows: 8 1/2" Bit, 2 Boot Baskets, 95/8" Csg Scraper, BS, Bumper Sub, Jars, XO, 9* 6 1/4" DCs, XO, XO, Pump Out Sub. TL = 317.96' RIH wI same. 04:00 - 06:00 2.00 FISH P DECOMP RIH wI BHA #6 on 95 stands of 3 1/2" DP & scrape casing. 06:00 - 06:30 0.50 FISH P DECOMP PJSM. Lube rig, inspect derrick, OK. 06:30 - 08:00 1.50 FISH P DECOMP PJSM. Continue in hole, tag TOL @ 9443'. 08:00 - 10:30 2.50 FISH P DECOMP PJSM. Reverse circulate 40 bbls Hi Vis sweep & chase @ 5 1/2 bpm 11290 psi to clean wellbore. 10:30 - 11 :30 1.00 FISH P DECOMP PJSM. Slip & cut 84' of drilling line. 11 :30 - 14:30 3.00 FISH P DECOMP PJSM. POOH w/3 1/2" DP. 14:30 - 15:30 1.00 FISH P DECOMP PJSM. UD bit, scraper & junk subs, scale recovered in junk subs. 15:30 - 16:00 0.50 FISH P DECOMP Clear I clean rig floor. 16:00 - 16:30 0.50 DHB P DECOMP PJSM. M/U Halliburton 95/8" Bridge Plug. 16:30 - 20:00 3.50 DHB P DECOMP PJSM RIH wI 99 stands 3 1/2" DP. 20:00 - 20:30 0.50 DHB DECOMP Space out RBP & set @ 9387' (center of element) Top of prong @ 9383' DPM. SIO 15K & verify set. P/U Wt =135K, SIO Wt = 97K. 20:30 - 21 :30 1.00 DHB P DECOMP MIU circulating pin. Break circulation & get the air out prior to test. RlU test equip. Pressure test RBP to 4000 psi for 30 Min. Tested Good. Charted same. RID test equip. 21 :30 - 00:00 2.50 DHB P DECOMP POOH & stand back 3 1/2" DP. 5/24/2006 00:00 - 01 :00 1.00 EVAL P DECOMP POOH & stand back 99 stands of 31/2" DP. 01 :00 - 02:00 1.00 EVAL P DECOMP NID flow nipple. N/U shooting flange. 02:00 - 04:00 2.00 EVAL P DECOMP Hold PJSM wI all hands. RlU SWS & P/U tools. Pressure test to 500 psi, OK. 04:00 - 09:30 5.50 EVAL P DECOMP RIH & log US IT from 9330' to surf. Top of cement @ 2350' (+ -). 09:30 - 10:30 1.00 EVAL P DECOMP PJSM. Rig down Schlumberger Eline. 10:30 - 13:00 2.50 EVAL P DECOMP PJSM. Rig down shooting flange. Rig up flow nipple, upper & lower air boots. 13:00 - 14:30 1.50 FISH P DECOMP PJSM. M/U Halliburton 95/8" retrievable Bridge Plug & RIH, 42 stands. 67K up wt, 67K down wt. Set @ 3990'..., (middle of element), top of plug @ 3985'. 14:30 - 16:30 2.00 FISH P DECOMP PJSM. Dump 30 sacks river sand down DP. 16:30 - 17:00 0.50 FISH P DECOMP RIH & tag sand @ 3965'. 17:00 - 19:00 2.00 FISH P DECOMP PJSM. POOH w/3 1/2" DP & running tool. UD running tool. 19:00 - 20:00 1.00 FISH P DECOMP M/U BHA # 6 to cut casing as follows: 9 5/8" Multi-string cutter wi 11 1/4" Blades, XO, 87/16" String Stabilizers, XO, 9 * 61/4" DCs, XO,XO. TL = 289.68'. RIH wI BHA. 20:00 - 21 :00 1.00 FISH P DECOMP RIH wI 20 stands & 1 single of 3 1/2" DP. 21 :00 - 22:00 1.00 FISH P DECOMP P/U kelly break circulation & locate casing collar @ 2226' ELM. Space out 24' below collar. 20 stands + BHA + 1 single + 32' of kelly = 2256' DPM. Cut casing @ 2256'. 40 RPMs, 58 STKs @ 780 psi. Torq 2-3K ft-Ibs. Took 13 mins to cut. Pressure dropped to 400 psi. Torq went to O. P/U & verify cut, SIO & Printed: 6/12/2006 9:40:45 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 61612006 5/24/2006 21 :00 - 22:00 1.00 FISH P DECOMP confirm, have 6" gap in casing. All indications of good cut. 22:00 - 00:00 2.00 FISH P DECOMP Close in bag & attempt to circulate. Pressured up to 1500 psi. No bleed off held steady. Open annular & circulate around DP. Heat up circlating seawater to 140 degrees. Circulate 2 BPM @ 260 psi. 5/25/2006 00:00 - 01 :30 1.50 FISH P DECOMP Con't to heat up seawater to 140 degrees in, 100 degrees out. Pumping @ 2 BPM, 260 psi. 01 :30 - 04:30 3.00 FISH P DECOMP Close in annular & pressure up to 1500 psi. Pressure leaked off slightly. Increase pressure to 2000 psi. Pressure now bleeding down slowly but rate increasing. Start circulating @ 1 BPM , 1200 psi. good returns in tiger tank. After 45 min circulating 1 BPM @ 140 psi. getting warm fluid back. SI well & allow to "soak" for 30 min. Resume circulating @ 3 BPM, 900 psi. 5 BPM @ 1800 psi. Pumping 50 bbls & SI for 15 min & repeat process. Getting good Artic-Pac returns. 04:30 - 06:00 1.50 FISH P DECOMP Pump & displace 50 bbls of hot diesel around annulus & allow to soak 1/2 hr. 3 BPM @ 750 psi. Then chase wi 50 bbls of hot seawater. 06:00 - 07:30 1.50 FISH P DECOMP PJSM. Circulate out diesel wi heated seawater @ 5 bpm 11800 psi. Line up & pump (50) bbls heated diesel wi Little Red Services. Chase wi heated seawater, (15 bbls), & spot in 9 5/8" x 133/8" annulus. Close in O/A valve. 07:30 - 08:30 1.00 FISH P DECOMP PJSM. Break off circulating head & POOH w/3 1/2" DP. 08:30 - 09:30 1.00 FISH P DECOMP PJSM. UD Multi String Cutter BHA. Examine blades, wear pattern indicates good cut. 09:30 - 10:00 0.50 BOPSU P DECOMP PJSM. Set test plug. 10:00 - 11 :00 1.00 BOPSU P DECOMP PJSM. CIO piipe rams to 9 5/8". 11:00 - 12:00 1.00 BOPSU P DECOMP M/U test joint & crossovers. Test pipe rams @ 250/3500 psi, 5 min each test. Witnessing of test waived by AOGCC State Rep Jeff Jones. Test witnessed by Nabors Tollpusher Gene Sweatt & Wellsite Leader Paul Haynes. UD test joint & pull test plug. 12:00 - 13:00 1.00 BOPSU P DECOMP PJSM. Close blind rams. Line up & circulate down 9518" casing, taking returns thru cut @ 2259' 7 up 9 5/8" x 13 3/8" annulus, clearing said annulus of diesel & any remaining arctic pack. Circulated 135 bbls @ 5 bpm I 350 psi. 13:00 - 15:30 2.50 BOPSU P DECOMP PJSM. NID 13 5/8" x 5M BOPE. NID Grey tubing spool. Pull top 9 5/8" pack off. 15:30 - 16:30 1.00 FISH P DECOMP PJSM. Pick up spear & RIH (22') & engage same. 16:30 - 17:00 0.50 FISH P DECOMP PJSM. Pull 95/8" casing wi slips & lower pack off to rig floor. 150K up wt, smooth pull, no bobbles. 17:00 - 19:00 2.00 BOPSU P DECOMP N/U BOPE. 19:00 - 19:30 0.50 FISH P DECOMP UD Casing spear & hanger. 19:30 - 00:00 4.50 FISH P DECOMP POOH & UD 9 5/8" casing. Recovered 32 jts & 6 intact centralizers. Casing is torqued up. Needing 36K + ft-Ibs to break loose. Slimey skin of Arctic-Pac on outside of casing, having to wipe jts as they come out of hole. 5/26/2006 00:00 - 05:00 5.00 FISH P DECOMP Con't to POOH & UD 9 5/8" casing. connections torqued up. Needing 36K+ to break connections loose. Wiping Arctic-Pac off while pulling out of hole. Recovered total of 54 jts + 1 - 25.1' cut off jt; + 10 Centralizers. All centralizers were intact. 05:00 - 07:00 2.00 FISH P DECOMP Clear & clean rig floor. RID casing handling equip. 07:00 - 08:00 1.00 FISH P DECOMP PJSM. Rig up Schlumberger Eline. Printed: 6/12/2006 9:40:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 6/612006 5/26/2006 08:00 - 09:00 1.00 FISH P DECOMP RIH wI 10', (3) strands string shot. Tie in & fire string shot fl 2261' - 2271' ELM. POOH wI Eline. 09:00 - 10:00 1.00 FISH P DECOMP PJSM. Rig down Eline. 10:00 - 12:00 2.00 FISH P DECOMP PJSM. Set test plug, change out pipe rams from 9 5/8" to 3 1/2" x 6" variables. 12:00 - 19:00 7.00 BOPSU DECOMP PJSM. Conduct weekly BOPE test wI AOGCC State Rep Jeff Jones witnessing said test. All valves & rams tested @ 250 I 4000 psi, with the exception of the annular preventor which was tested @ 250 I 3500 psi. Performed drawdown test on accumulator & tested kelly. 19:00 - 19:30 0.50 BOPSU DECOMP RID test equip. Blow down lines. Pull & UD test plug. 19:30 - 22:30 3.00 FISH DECOMP RlU tools to handle washpipe. M/U BHA #8 as follows: 121/4" Mill Shoe, 2 jts 11 3/4" WP, Boot Basket, PxP Sub, 133/8" Csg Scraper, Bit Sub, Bumper Sub, Oil Jars, XO, 9 Drill Collars, XO, XO, Pump Out Sub. TL = 374.89'. RIH wI BHA. 22:30 - 00:00 1.50 FISH P DECOMP RIH wI BHA # 8 on stands of 3 1/2" DP & Scrape casing. Going very very slowly due to surge effect of wash pipe. 5/27/2006 00:00 - 03:30 3.50 FISH P DECOMP Con't to RIH wI 10 stands. Drill pipe wanting to flow when going in hole Due to pushing large amount of Arctic-Pac. String taking weight. Try circulating & can only get 10-15' until pipe flows back. P/U dart valve & run in hole to 2183'. Have total of 19 stands in hole. ( dart between stand 10 & 11. ) Fill pipe. 03:30 - 07:30 4.00 FISH P DECOMP M/U head pin & circulate 6 BPM, 400 psi. Getting large amounts of Arctic-Pac back. Working pipe up & down. P/U 50K, SIO 45K. AT 0515 hrs. toolpusher noticed Gray water spill under camp. Reported spill @ 0530 hrs. 07:30 - 08:30 1.00 FISH P DECOMP PJSM. Kelly up. Establish parameters. Up wt 60K, down wt 55K, rotating wt 60K. Pump pressure 450 psi @ 6 bpm. WI 19 stands & (2) singles in the hole, slack off & see top of 9 5/8" casing stub @ 2256', (8' in on kelly). Wash I rotate on down & see collar, (and what may be an unexpected centralizer), 23' in on kelly @ 2271' DPM. Wash & rotate kelly on down to 2282'. Repeat process (3) more times. Make connection & wash I rotate on down to 2314' & bottom out at top of washpipe. Pick up 2' to circulate hole clean. 08:30 - 10:00 1.50 FISH P DECOMP Circulate @ 6 bpm I 450 psi to clean up arctic pack, sending same to tiger tank. 10:00 . 11 :00 1.00 FISH P DECOMP PJSM. POOH w/3 1/2" DP & washover BHA. 11 :00·12:30 1.50 FISH P DECOMP PJSM. UD washpipe & washover BHA. 12:30 - 16:30 4.00 FISH P DECOMP PJSM. Pick up Baker 9 5/8" casing back off tool & associated BHA. 16:30 - 17:30 1.00 FISH P DECOMP RIH wI Back-off BHA. 17:30 - 18:00 0.50 FISH P DECOMP Tagged up @ 2257'. Obstruction l' inside of casing cut off jt. May be junk from undocumented centralizer. Took 4K down weight & would not go. Attempt to turn wI bullnose tried 4 times w/2-8K down weight. No joy. P/U 75K, SIO 75K. 18:00 - 19:00 1.00 FISH P DECOMP POOH wI Back-off BHA & stand back 3 1/2" DP. 19:00 - 21 :00 2.00 FISH P DECOMP Drain & UD Back -off assy. BHA was coated wI Arctic-Pac. 21 :00 - 22:00 1.00 FISH P DECOMP Clear & clean rig floor. 22:00 - 23:00 1.00 FISH P DECOMP M/U milling BHA to clean out as follows: 77/16" Tapered Mill, Bit Sub, XO, 8 1/2" watermellon Mill, PxP Sub, 2 Boot Baskets, Bit Sub, XO, bumper Sub, Jar, XO, 9 * Drill Collars, XO, Pump Out Sub. TL = 330.44'. RIH wI same. Printed: 6/1212006 9:40:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 61612006 5/27/2006 23:00 - 00:00 1.00 FISH P DECOMP RIH wi Milling BHA & 20 stands of 31/2" DP. 5/28/2006 00:00 - 01 :30 1.50 FISH P DECOMP P/U kelly & break circulation. RIH & tag @ 2256'. 20 stands +BHA + 23' of kelly. P/U 60K, SIO 60K, Rot Wt = 60K. 40 RPMs. 3 BPM @ 120 psi. Ream & mill thru top l' wI little or no Torq. Work up & down. Junk was only on very top of cutoff jt. Run upldown wlo rotation. Last 4 times no problem. 01 :30 - 02:30 1.00 FISH P DECOMP RIH to top of sand & make sure all junk on bottom. Tagged @ 3971'. 02:30 - 04:00 1.50 FISH P DECOMP POOH wI milling BHA & stand back 31/2" DP. DP still carring Arctic-Pac. 04:00 - 05:30 1.50 FISH P DECOMP Break out & UD BHA. 05:30 - 06:00 0.50 FISH P DECOMP Clear & clean rig floor. 06:00 - 08:30 2.50 FISH P DECOMP PJSM. Pick up Baker 9 5/8" back off tool & associated BHA. 08:30 - 09:30 1.00 FISH P DECOMP RIH wI back off assembly on 31/2" DP. 09:30 - 11 :00 1.50 FISH P DECOMP PJSM. Space out back off tool. WI 23 stands, (2) jts & a 10' pup. Pick up 9', putting the top of the top anchor @ 2257'. 57K down wt, 58K up wt. Pressure up to 1000 psi to set the bottom anchor. Bleed off pressure. Wait 5 minutes. Slack off 15K, OK. Pressure up to 3500 psi, saw 1/2 turn. Bleed off pressure & set down all but 15K, OK. Wait 5 minutes. Bring up pressure to 2200 psi & observe 1/2 turn to the right indicating torque required to break connection to be 22,000 ftllbs. Bleed off all pressure, wait a minute & repeat, seeing 1/2 turn wI 1100 psi. Repeat process seeing successive 1/2 turns @ 700 - 900 psi. Achieve (6) full turns. Straight pull to release, no overpull. 11 :00 - 12:00 1.00 FISH P DECOMP PJSM. POOH & stand back 3 1/2" DP. 12:00 - 14:00 2.00 FISH P DECOMP PJSM. UD Back off tool. 14:00 - 15:00 1.00 FISH P DECOMP PJSM. Pick up 9 5/8" casing spear BHA. 15:00 - 16:00 1.00 FISH P DECOMP RIH wI spear on 31/2" DP, 23 stands. 40K up wt, 40K down wt. Top of stub @ 2256'. See stop sub tag top of stub wI spear @ 2262'.23 stands & (2) singles. Pick up 10K over to ensure spear is engaged, OK. Slack off to neutral wt. 16:00 - 16:30 0.50 FISH P DECOMP PJSM. Pick up 2 - 3K over up wt to 43K. Set rotary table slips & rotate to the left (6) turns. Pick up & observe slight bobble & pull free, casing stub appears to be fully backed off. 16:30 - 18:30 2.00 FISH P DECOMP PJSM. POOH w/3 1/2" DP. 18:30 - 20:00 1.50 FISH P DECOMP Break out & UD Cut off jt. Inspect cut & threads. Threads looked good no damage. Cut end showed scratches on inside in the 1st foot. TL = 14.84'. UD remainder of BHA. Stand back DCs. Clear & clean rig floor. 20:00 - 21 :30 1.50 FISH P DECOMP P/U mule shoe on end of DP & RIH. Tagged top of 9 5/8" casing @ 2269'.23 stands +double + 19'. Cont to RIH to 3959'. M/U head pin on DP. 21 :30 - 00:00 2.50 FISH P DECOMP Clean pits & take on 9.8 ppg brine. Had truck shortage & needed to round trip truck. 5/29/2006 00:00 - 01 :30 1.50 FISH P DECOMP Clean pits & take on 9.8 ppg brine. 01 :30 - 05:00 3.50 FISH P DECOMP Displace well to 9.8 ppg Brine. Pumped 5.5 BPM @ 650 psi. Pressure increased to 750 psi. Had to shut down after 410 bbls. due to flow line plugging. from Arctic-Pac. Recovered large amounts of Arctic-Pac. Close in annular & took returns directly to tiger tank. Pumped toal of 455 bbls. until clean 9.8 ppg returns. 05:00 - 06:30 1.50 FISH P DECOMP POOH & stand back 31/2" DP. Printed: 6/12/2006 9:40:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 10:30 - 12:30 12:30 - 21 :00 21 :00 - 21 :30 21 :30 - 23:30 2.00 CASRE P INTERV 23:30 - 00:00 0.50 CASRE INTERV 5/30/2006 00:00 - 01 :00 1.00 CASRE INTERV 01 :00 - 03:30 2.50 CASRE P 03:30 - 05:30 2.00 CASRE INTERV 05:30 - 06:00 0.50 CASRE INTERV 06:00 - 07:00 1.00 CASRE INTERV 07:00 - 07:30 0.50 REMCM INTERV 07:30 - 10:00 2.50 REMCM P INTERV Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 616/2006 Clear I clean rig floor, service rig. PJSM. Set test plug, (lower). Change out pipe rams to 9 5/8" PJSM. Fill test joint, test pipe rams @ 250 I 4000 psi, lay down tet joint & pull test plug. INTERV PJSM. Rig up floor to run 9 5/8" casing. Rig up torque turn equipment. INTERV PJSM. Pick up screw in sub, baffle collar wI plug on seat, pup & Halliburton ES Cementer, X/O joint & 9 5/8" TCII 47# L-80 casing. Torquing all TCII connections to 17,000 ftIlbs, using Jet Lube Seal Guard pipe dope. Ran total of 55 jts. Full every 5 jts. Ran centralizer on every jt. INTERV RIH slowly wI 55th jt. Tag 95/8" casing wI Overshot @ 2264'. P/U Wt = 95K, SIO Wt = 95K. Slowly run in while rotating & engage screw-in sub to 9 5/8 collar @ 2267'. M/U threads, got 11 full revolutions. Final torq was 10K. Work string up & down, re-torq to 10K wI no additional rounds. Threads fully engaged. P/U & pull test to 250K, held tight. . RID casing tools. RlU X-Over & Cementing head. Hook up circulating lines & test equip. Take on 200 bbls of 9.8 ppg brine. Pressure test 9 5/8" Tie-back to 2000 psi. Pressure test 9 5/8" Tie-back string to 2000 psi for 30 min. Lost 125 psi in 30 min. Could not find any leaks. May be some air in csg due to top filling. No indication of communication to the 0/A. Con't to pressure up to 2800 psi & open ES-Cementer. INTERV Circulate wll & heat up annulus to 80 degrees. Clean up annulus. Still getting some Arctic-Pac back, however not the volumes previously seen. Pumping 6 BPM @ 200 psi. Heating fluids wI Hot Oiler & pumping 3 BPM @ 60 psi. Return temp is 85 degrees. Arctic-pac Has almost completely cleared up. RID Hot Oilers. Drain stack & blow down lines. NID BOP. P/U to 225 K & set slips. Slack off & set slips wI 175K, OK. Nipple up BOPE. Pre job meeting with all personel involved wI cement job. Emphasis Install Halliburton closing plug in Halliburton cement head. Line up & pump wI Dowell I Schlumberger, 5 bbls fresh water ahead. Pressure test line to 4000 psi, OK. Pump 151 bbls 15.8 ppg class G cement wI GASBLOK. Pump @ average rate of 5.4 bpm, taking 9.8 ppg brine returns thru bleed valve & to mud pits. Pressure while pumping @ 5.4 bpm ranging from 1275 psi initiallly to 800 final. Drop Halliburton ES Cementer Closing Plug. Flush cementing lines wi 5 bbls fresh water, (thus leaving 1 - 2 bbls cement on top of plug), & displace wI rig pump & 9.8 ppg brine @ 6 bpm. Pump 20 bbls & catch cement. See pressure while displacing start @ 6 bpm 11200 psi & go as high as 2200 psi wI 120 bbls away. WI 130 bbls pumped, begin taking returns outside. Observe pressure drop to 1300 psi, (by passing line restrictions). WI 145 bbls away, drop rate to 2 bpm I 900 psi. Getting cement retums now to flow back tank. Observe plug bump wI 167 bbls pumped. Observe indication @ surface of cementer closing ... 1900 psi. Hold for a few minutes & check for flow back, no flow back, cementer is Printed: 6/12/2006 9:40:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 6/612006 closed. CIP @ 09:30. PJSM. Flush all lines, rig down Schlumberger cementing equipment. Rig down cementing head. Drain stack. 12:30 - 15:00 2.50 INTERV PJSM. Split stack. Make cut on 9 5/8" casing using Wachs cutter. UD cut off jt. ..28.49'. Stand BOPE back. 15:00 - 18:00 3.00 WHSUR P INTERV PJSM. Install 95/8" x 13 3/8" pack off. RILDs. N/U 135/8" 5M x 135/8" 5M McEvoy split speedhead. @ 17:00 hrs, compressive strength of cement @ 500 psi. 18:00 - 21 :00 3.00 WHSUR P INTERV Test Tubing Spool to 3800 psi for 30 minutes - good test. Release Cameron. Lab results are in from UCA analysis - compressive strength up to 1500 psi as 19:30 hrs. 21 :00 - 00:00 INTERV PJSM. NU BOP Stack and Test Spool. Fill pits up with 120 degree seawater. 5/31/2006 00:00 - 01 :00 1.00 INTERV Change out Pipe Rams from 9 518" to 31/2" x 6" Variable Bore Rams. Install Test Plug. 01 :00 - 01 :30 0.50 INTERV Pressure test BOPE to 300 psi low and 4000 psi high - good test. Body tested and tested the Pipe Rams. Drain BOPE Stack. 01 :30 - 02:30 INTERV RD Test Equipment. Install 9" Wear Ring. Prepare Floor for TIH with BHA and rig up 3.5" Handling Equipment. 02:30 - 03:00 0.50 CASRE INTERV PJSM to discuss making up of BHA and TIH with Drill Pipe. 03:00 - 04:00 1.00 CASRE INTERV Begin pulling BHA components to Rig Floor. Make up BHA #14 as follows: 8 1/2" Bit, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Oil Jars, XO, 9 Drill Collars, XO, XO, Pump Out Sub. OAL = 314.45'. 04:00 - 05:00 1.00 CASRE P INTERV TIH with BHA #14 on 3.5" DP. In with 20 stands (60 joints) of DP which puts bottom of BHA @ 2218'. Pick up joint 61 to tag top of cement on top of Cement Plug @ 2259'. Tagged top of cement @ 2236'. 05:00 - 06:00 1.00 CASRE P INTERV MU Headpin. Begin circulating 120 degree seawater to displace 9.8 ppg brine at a rate of 4 bpm I 400 psi. Pick up kelly. 06:00 - 09:30 3.50 CASRE P INTERV PJSM. Establish parameters. 59K up wt, 59K down wt. 225 psi @ 4 1/2 bpm. 2000 - 3000 ftllbs of torque off bottom. Rotate @ 80 RPM. Mill medium soft cement F/2236' - 2261'... top of plug. Mill on plug w/5 - 10K WOB. Mill plug f/2261' - 2263'. Circulate 25 bbls Hi Vis sweep. Drop on down & encounter plug in baffle collar. Mill on same, running 3 -5K WOB to try to keep the pieces small. Mill bottom plug F/2268' 2269'. 09:30 - 11 :00 1.50 CASRE INTERV PJSM. Stand back kelly & RIH w/3 1/2" DP to top of sand, tag same @ 3970'. 11:00-12:15 1.25 CASRE INTERV PJSM. Circulate seawater to displace remaining 9.8 ppg brine out of wellbore. 5 bpm I 425 psi, circulate to clean seawater retu rns. 12:15 - 15:00 2.75 CASRE INTERV PJSM. Break off head pin & POOH wI milling assembly. 15:00 - 15:30 0.50 CASRE INTERV PJSM. UD mill, empty junk subs, recovered small amount of aluminum & cement. MIU BHA #15 as follows: 7 7/8" Reverse Circulating Basket, Double Pin Sub, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Oil Jar, XO, 9 Drill Collars, XO, XO, Pump Out Sub. OAL = 320.05'. 15:30 - 18:00 2.50 CASRE P INTERV PJSM. Close blind rams. Pressure test 9 518" casing from surface to 3970' @ 4000 psi. Bled 35 psi in 1 st 15 minutes, 35 psi in 2nd 15 minutes. Isolate all surface equipment, double Printed: 6/12/2006 9:40:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18:00 - 19:00 19:00 - 20:00 20:00 - 21 :30 21 :30 - 22:00 22:00 - 23:00 NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES INTERV INTERV INTERV INTERV 1.00 CASRE P INTERV 23:00 - 00:00 1.00 CASRE P INTERV 6/1/2006 00:00 - 01:00 P INTERV 01 :00 - 03:00 2.00 CASRE P INTERV 03:00 - 05:00 05:00 - 06:00 2.00 CASRE 1.00 CASRE INTERV INTERV 06:00 - 06:30 0.50 CASRE INTERV 06:30 - 08:00 1.50 CASRE INTERV 08:00 - 09:30 1.50 CASRE INTERV 09:30 - 11 :30 2.00 CASRE INTERV 11 :30 - 13:00 1.50 CASRE INTERV 13:00 - 14:00 1.00 CASRE P INTERV Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 61612006 valve chokeline & disconnect kill line after pressuring up and re-test for 30 minutes charted - good test with zero bleed-off. Crew changeout and pre-tour safety meeting. Service rig. Bleed pressure off equipment and re-engage all surface equipment. MU BHA #15 to Drill Collars and XO's prior to TIH. PJSM. Begin TIH with BHA #15 on 3.5" DP from Derrick. In with 38 stands (114 joints) and a 23.87' pup. PU and MU Kelly. UW = 81 K , DW = 76K. Establish working parameters of 40 RPM, RW = 80K, Torque = 90 Amps (1,750 ft-Ibs). Break circulation at 1 bpm I 70 psi to tag. RIH and tagged top of junk at 3969' - approximately 2' of junk on top of sand. PU and increase pump to 2 bpm /160 psi. RIH to clean out. Work in one foot increments. Increase pump to 5 bpm I 630 psi and work pipe to depth of 3972'. Slight torque increases noticed as work pipe down. Circulate seawater around at a rate of 6 bpm I 700 psi to equalize temperature of fluids in the well with fluids in pits to minimize U-tubing up in DP. Cease steam in pits to aid in equalizing the temperature of the fluids. PJSM. Begin TOH with BHA #15 on 3.5" DP while standing back in Derrick. Continue TOH with BHA #15 while standing back 3.5" DP in Derrick. On surface with with BHA #15. Break down components and inspect Junk Basket. Junk Basket was completely packed off with rubber and Arctic Pack. Recovered approximately 1/3 of a 5 gallon bucket of rubber pieces along with the whole bottom cone of the Plug. Both Boot Baskets were filled with Arctic Pack, sand and cement pieces. Washed out baskets with clean water and cleaned up BHA components. Make up BHA #16 with same components as BHA #15 with a 9 5/8" Casing Scraper above the Boot Baskets. PJSM. Begin TIH with BHA #16 on 3.5" DP from Derrick. In with 38 stands (114 joints) of DP and a 23.87' pup. PU and MU Kelly. Dry tag at 3972' which is depth of previous cleanout. Begin to cleanout. Bring on pump @ 6 bpm I 700 psi & rotating @ 30 -40 RPM, 2500 ftllbs torque on bottom, slack off & take wt, circulating & rotating down, maintaining 5K WOB to 3979'. Circulate @ 6 bpm I 700 psi & service rig. PJSM. POOH wI reverse circulating junk basket & 31/2" DP. PJSM. UD 6 1/4" DCs & reverse circulating junk basket. Empty basket, a few small pieces of rubber is all. PJSM. M/U Halliburton retrieving tool & RIH on 31/2" DP. 125 jts in the hole. 61 K up wt, 60K down wt. PJSM. M/U headpin on jt # 126 & reverse circulate @ 5 bpm I 600 psi, washing down to top of bridge plug 26' in on jt # 126, set down 15K on bridge plug & CBU @ 5 bpm I 600 psi. Sand back and got several large chunks of rubber back, plugged off @ elbow in manifold once & had to flush out thru reverse circulating line. Two more large chunks recovered there. Continue to reverse circulate @ 5 bpm until sand cleans up PJSM. Rotate pipe to the right & pick up to engage bridge plug, Printed: 6/1212006 9:40:45 AM (several attempts before successful latch up). Latch up & eventually pulled to 100K to get bridge plug to release. Slack off to 29' in to verify bridge plug is released. INTERV PJSM. Break off head pin & POOH w/3 1/2" DP & bridge plug. Dragging pretty good for awhile, up to 20K over, appears to be a chunk of rubber, work it a little w/17 stands out, & continue out slowly, finally wiped it off wI 25 stands out. INTERV PJSM. UD Halliburton bridge plug. Aluminum pieces recovered wI bridge plug, looks like they were the culprits giving us grief when attempting to latch up. INTERV TIH with Halliburton retrieving tool on 3.5" DP. PU 9 singles from Pipe Shed. In with 296 joints of DP. PU joint 297. MU Headpin. UW = 130K , DW = 95K. Close bag and reverse circulate @ 3 bpm I 400 psi. Wash down to top of bridge plug 28' in on Joint #297 = 9387'. Set down 15K on RBP. INTERV PJSM. Reverse circulate @ 6 bpm 11550 psi until returns cleaned up. Pumped a total of 333 bbls. Saw some sand and scale in returns across Shaker. Clear and clean Rig Floor while reverse circulating clean. INTERV Begin latching process on RBP. Rotate pipe to the right and PU to engage RBP. Had to make several attempts at latching the RBP before being successful. RBP finally came free after pulling up to 165K (35K overpull). RIH to ensure weight doesn't stack out and RBP is free - good. POH with RBP. UW is now 135K so dragging about 5K. Monitor well dead - well is stable as can be. Composite bridge plug below must be holding. PJSM. Break off Headpin. Lay down 9 singles and TOH with RBP on 3.5" DP standing back 96 stands (288 jts). Dragging about 10K as coming out of hole so TOH slowly with caution. Continue TOH with RBP while standing back 3.5" DP in Derrick. RBP still dragging on way out, up to 15K. PJSM. 30 stands (90 jts) out and stood back. Slip and cut 84' of Drilling Line. Continue TOH with RBP while standing back 66 more stands (198 jts) of 3.5" DP in Derrick. PJSM. UD halliburton bridge plug, .... no significant junk captured with this run, .. no damage or missing pieces to bridge plug. Clear I clean rig floor. Pull wear bushing. PJSM. Set test plug. Change out pipe rams to 7 5/8". PJSM. Conduct weekly BOPE test as per AOGCC requirements. Chuck Sheve waived witnessing the test, 24 hour notice given. Test witnessed by Nabors tool pusher & BP company man. Pull test plug RUNCMP Finish racking & strapping 7 5/8" tubing. Prep floor to run completion. Pick up Gator Hawk tools & Nabors casing tongs. RUNCMP PJSM with Nabors, Nabors Casing, GatorHawk and V AM personnel. Begin running 7 5/8" Completion per program. Run 7" Tailpipe Assembly. Verified RHC-M in the "RN" Nipple Assembly. Baker Lok'd "RN" Nipple Assembly to Baker S-3 Packer Assembly. Utilizing Torque Turn Equipment for all connections. 7" Pipe is 26#, L-80 TC-II. 7 5/8" Pipe is 29.7#, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 14:00 - 16:30 16:30 - 17:00 17:00 - 21 :15 21:15 - 22:15 22:15 - 23:00 23:00 - 23:30 0.50 CASRE INTERV 23:30 - 00:00 0.50 CASRE INTERV 61212006 00:00 - 02:00 2.00 CASRE INTERV 02:00 - 03:00 1.00 CASRE INTERV 03:00 - 06:00 3.00 CASRE INTERV 06:00 - 07:30 1.50 CASRE INTERV 07:30 - 08:00 0.50 CASRE INTERV 08:00 - 09:00 1.00 BOPSU RUNCMP 09:00 - 15:30 6.50 BOPSU RUNCMP 15:30 - 19:00 3.50 19:00 - 00:00 5.00 Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 61612006 Printed: 6/12/2006 9:40:45 AM L-80 Vam Top HC. Torqued 7" to 10,100 ft-Ibs and 7 518" to 14,500 ft-Ibs. All joints doped with Jet Lube Seal Guard and used stabbing guide to make up. GatorHawking each 7 5/8" connection to 3800-4000 psi with Nitrogen. V AM representative monitoring each connection. RUNCMP Continue running 7 5/8" Completion per program. RUNCMP Continue to run completion string, torque turning all 7 5/8" TCII L-80 Vam Top HC connections to 14,500 Nibs, using Jet Lube Seal Guard and Gator Hawking each connection to 3800 psi wI nitrogen. Joint # 133 did not shoulder up properly, laid down same and replace with joint from outside. RUNCMP Continue running 7 5/8" Completion per program. Pre-tour safety meeting with night crew at 17:30 hrs at changeout. RUNCMP In with Joint #227. PU Joint #228. Completely buried it without tagging 7" Liner. PU Joint #229 and tag at @ 27.75' in with Joint #229 = 9445.6' Liner top depth. RKB + Hanger Assembly = 24.6'. No space out pups needed. WLEG will be 3.1' above 7" Liner Top at a depth of 9442.4'. PJSM. PU and MU Tubing Hanger. MU Landing Joint to Hanger. RIH 19.8' and land Tubing Hanger. RILDs. PJSM. RD Torque Turn and GatorHawk Equipment. Continue RD of GatorHawk Equipment. Clear and clean Rig Floor. PJSM. Begin reverse circulating at a rate of 3 bpm 1400 psi with 140 degree seawater. Pump a total of 200 bbls followed by 250 bbls of corrosion inhibited seawater. PJSM. Blow down lines. RU Little Red Services to IA. Freeze protect IA with 45 bbls of diesel pumped by Little Red at a rate of 2.5 bpm I 400 psi. Block off Little Red. Break off Headpin. Drop Ball and Rod. Lay down Landing Joint. RU Chart Equipment. Pressure test the Tubing to 4000 psi for 30 minutes and charted - good test. Bleed the Tubing to 1500 psi. Pressure up the IA to 4000 psi with diesel from Little Red. Pressure test the IA to 4000 psi for 30 minutes and charted - good test. Bleed the IA to zero. Bleed the tubing to zero. PJSM. Rig up Schlumberger slickline unit. RIH wI slickline & retrieve ball & rod in RIN Nipple @ 9419'. POOH & UD same. PJSM. RIH wI slickline & retrieve RHC-M plug body from RIN Nipple @ 9419', POOH & UD same. PJSM. Rig down Schlumberger slickline. PJSM. Clear I clean rig floor. Rig up to run 3 1/2" DP. PJSM. Set two way check in tubing hanger. Change out pipe rams to 2 7/8" x 5" variables. PJSM. Pressure test 2 7/8" x 5" variable bore rams @ 250 I 4000 psi, charted, OK. RU Lubricator and pull TWC. PJSM. MU BHA #17 as follows: Mill, Junk Basket, Junk Basket, Bit Sub, Bumper Sub, Oil Jars, 9 Drill Collars, Pump Out Sub. OAL = 312.63'. TIH with BHA #17 on 3.5" DP from Derrick. In with 290 joints of DP. PU and MU Kelly. UW = 142K , DW = 105K. Break circulation at 3 bpm I 600 psi. Kick in Rotary Table Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 6/3/2006 00:00 - 06:00 06:00 - 18:00 6.00 12.00 18:00 - 21 :30 3.50 21 :30 - 22:30 1.00 22:30 - 23:15 0.75 RUNCMP 23:15 - 00:00 0.75 RUNCMP 6/4/2006 00:00 - 00:30 0.50 RUNCMP 00:30 - 03:00 2.50 RUNCMP 03:00 - 03:30 0.50 RUNCMP 03:30 - 04:00 0.50 RUNCMP 04:00 - 06:30 2.50 RUNCMP 06:30 - 08:00 1.50 CLEAN P CLEAN 08:00 - 10:00 2.00 CLEAN P CLEAN 10:00 - 12:30 2.50 CLEAN P CLEAN 12:30 - 13:30 1.00 CLEAN P CLEAN 13:30 - 14:30 1.00 CLEAN P CLEAN 14:30 - 16:00 1.50 BOPSU P CLEAN 16:00 - 17:00 1.00 BOPSU P CLEAN 17:30 - 18:00 0.50 CLEAN P CLEAN 18:00 - 21 :45 3.75 CLEAN P CLEAN 21 :45 - 23:30 1.75 CLEAN P CLEAN Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 6/612006 Printed: 6/12/2006 9:40:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 61612006 6/4/2006 21 :45 - 23:30 1.75 CLEAN P CLEAN at 80 RPM. RW = 118K with Torque = 4,000 ft-Ib (180 Amps). Stop rotation and RIH to tag. Tag Fasdrill Plug @ 9507'. PU and re-tag at same depth. PU 6' and kick in Rotary Table again. RIH to start milling. Taking weight at 9505'. Maintain 5K WOB while milling. Pump a 40 bbl hi-vis sweep around every 45 minutes, first sweep pumped @ 23:00 hrs. 23:30 - 00:00 0.50 CLEAN P CLEAN Milled through Fasdrill Plug. Well went on a big vac. Lost circulation. Regained circulation and returns seem a little gassy but returned to "dead". Continue to TIH with BHA #17 on 3.5" DP from Pipe Shed 1 x 1 to push Fish to bottom. Hole is staying full with charge pump. 6/5/2006 00:00 - 00:45 0.75 CLEAN P CLEAN Continue TIH with BHA #17. Pushing what is left of Fasdrill Plug to bottom. Keeping charge pump running and hole is staying full and dead. Stopping every 5 joints of DP to monitor well. 00:45 - 01 :00 0.25 CLEAN P CLEAN PU Joint #336. UW = 148K , DW = 115K. Ease in and tag bottom with 9' in on Joint #334. Stacked 10K. PU and push fish 2' deeper. Repeat without making any more hole two times (11' in on Joint #334). Final depth of Fish = 10,855'. Monitor well for loss rate, currently losing 6 bpm / 10 minutes or 36 bbls I hour. 01 :00 - 06:00 5.00 CLEAN P CLEAN PJSM. TOH with BHA #17 while laying down DP 1 x 1. 06:00 - 06:30 0.50 CLEAN P CLEAN Crew change / service rig. 06:30 . 09:30 3.00 CLEAN P CLEAN Continue to POOH w/3 1/2" DP & composite bridge plug milling BHA, laying down DP. 09:30 . 10:30 1.00 CLEAN P CLEAN PJSM. UD drill collars & BHA. Empty junk subs, recovered approximately 3/4 gallon of milled up bridge plug & missing piece of aluminum from Halliburton cementing plug. 10:30 - 11 :30 1.00 ZONISO P OTHCMP PJSM. NID flow nipple. N/U shooting flange. 11:30 -13:00 1.50 ZONISO P OTHCMP PJSM w/ Schlumberger. Rig up Schlumberger slickline. 13:00 - 13:30 0.50 ZONISO P OTHCMP PJSM. Pressure test Schlumberger lubricator & BOP against blind rams @ 1500 psi. 1st test failed, replace "0" rings. Changed out "0" rings, re pressure tested @ 1500 psi, OK. 13:30 - 14:30 1.00 ZONISO P OTHCMP PJSM. RIH w/ (5') 2 518" stem, oil jars, spangs, & PRN plug body. Set same in RIN nipple @ 9419', POOH wi slcikline. Constant hole fill wi seawater during this operation, well taking 24 - 27 bbls I hr. 14:30 - 16:30 2.00 ZONISO P OTHCMP PJSM. RIH w/ (5') 2518" stem, oil jars, spangs & prong. RIH & stop @ 9390'. Bullhead 135 bbls diesel down 7 5/8" tubing @ 3 bpm / 1500 psi. Slow pump down to 1 bpm @ 800 psi & set prong. Shear off same & bring pressure up to 1500 psi. Shut down pump & observe pressure, no bleed off in 15 min. Plug on seat & holding, OK. 16:30 - 18:00 1.50 ZONISO P OTHCMP POH with wireline. 18:00 - 19:30 1.50 ZONISO P OTHCMP Pre-tour Safety Meeting with Night Crew. Continue POH with Slickine. RD SWS Slickline. Clear and clean Rig Floor. 19:30 - 20:30 1.00 WHSUR P OTHCMP PJSM. ND Shooting Flange. NU Flow Adapter. 20:30 - 21 :30 1.00 WHSUR P OTHCMP PJSM. PU Lubricator and set TWC. Test to 1000 psi· good test. 21 :30 - 23:30 2.00 BOPSU P OTHCMP PJSM. Drain BOP Stack and blow down lines. ND BOP Stack. 23:30 - 00:00 0.50 WHSUR P OTHCMP PJSM. NU Tree with Cameron present. 6/6/2006 00:00 - 02:30 2.50 WHSUR P OTHCMP Continue NU Tree. Tested Tubing Hanger void to 5000 psi for 30 minutes - good test. Bleed pressure off. Test Tree to 5000 psi - good test. Bleed pressure off. Note: Threads on Tubing Printed: 6/12/2006 9:40:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-09 NGI-09 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/17/2006 Rig Release: 616/2006 Rig Number: Spud Date: 8/24/1976 End: 61612006 6/6/2006 00:00 - 02:30 02:30 - 04:00 2.50 WHSUR P 1.50 WHSUR P 04:00 - 06:00 2.00 RIGD P OTHCMP Hanger are damaged from running Pipe. OTHCMP PJSM. RU Lubricator and pull TWC. Install BPV. RD Drill Site Maintenance. OTHCMP PJSM. Secure location and clean up location around Rig. Release Rig @ 06:00 hrs. on 6/6/2006. Printed: 6/12/2006 9:40:45 AM R-~ c: r t: IVt=: 0 \.1- ut.-I - cÞ~ \~(o - ù-;:-c" Schlumberger , II \ ~\·1 'ì '{ 'ìnnR .~..... ., /..J U Lvl.....U Alaska Data & Consulting Services isStC 2525 Gambell Street, Suite 400 ..\J.(~.~ eii .1 GôS Cens. C.:-mffi ¡ in ~~~~r~~~~AK 99503-2838 Anchc1Bge SCANNED JUN 2 3 2006 Well Job # Log Description Date 07-18 9153238 LDL 01/31/03 C-04A 10649975 SBHP SURVEY 06/26/03 N-11 C 10980595 PRODUCTION PROFILE 08/09/05 MPF-89 11084328 SCMT 11/24/05 D-10 10913021 MULTI-FINGER CALIPER 06/02/05 NGI-09 11212860 USIT OS/23/06 MPH-09 11211412 USIT OS/28/06 MPH-15 11076486 CH EDIT PDC-GR OF USIT 12/15/05 MPS-90 11162721 CH EDIT PDC-GR OF USIT 11/27/05 AGI-07A 11212865 CH EDIT PDC-GR OF USIT OS/28/06 15-20C 11075906 MCNL 08/12/05 18-30 11209593 MCNL 03/25/06 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 c~ \~ 06/20/06 NO. 3854 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 CD Color - 1 1 1 1 Prints sent earlier Prints sent earlier 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • FRANK H. h9URKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ~~~ ~ ~~~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907} 276-7542 CANCELLATION ADMINISTRATIVE APPROVAL AIO 4~C 00~ Mr. Steve Rossberg ~ ~ 20d~ Wells Manager ~`~~~~~'~ ~~N BP Exploration (Alaska) Inc. ~ ~ ~ ~' P.O. Box 196612 Anchorage, AK 99~ 19-6612 RE: Cancellation of Administrative Approval AIO 04C.005 (~~'ell PBU NGI-09) Dear Mr. Rossberg: Pursuant to BP Exploration (Alaska), Inc.'s ("BPXA") request dated May 3, 2006 Alaska Oil and Gas Conservation Commission hereby cancels Administrative Approval AIO 04C.005, which allows gas injection in well PBU NGI-09. This well exhibited IA x OA pressure communication, and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that gas injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Since then, BPXA has determined that PBU NGI-09's condition has deteriorated to the point that safe operation is no longer supported. The well is shut in awaiting a rig work over to repair the annular communication source. Consequently, Administrative Approval AIO 04C.005 no longer applies to operation of this well. Instead, injection in well PBU NGI-09 will be governed by provisions of the underlying Area Injection Order No. 4E. ~ted May 18, 2006. Cathy P. oerster Commissioner s -, 1 ~. ~ 1 -~ s "~ ~ i~ 1 ~ ~ ~ i i j ~- i j ., 't j a r r- l j , I ,- i I { ~ ~ ~ t i ~ ~~ ~ 1 ~ ~~ ~ ~ , L~a7~L~ OIL .Ol`I~ ataa7 COIITSERQATI011T CO1~Il-IISSIOrT January 2~, 2005 1~Ir. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU NGI-09 (PTD 176-068) Request for Administrative Approval Dear Mr. Rossberg: • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alb ~IC.o~ Per Rule 9 of Area Injection Order ("AIO") 004C.000, the Alaska Oil and Gas Conserva- tion Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to inject gas in the subject well. According to information submitted by BPXA, PBU NGI-09 exhibits pressure communi- cation between the well's inner annulus ("IA") and outer annulus ("OA"). AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU NGI-09. The Commission further finds that, based upon reported results of BPXA's diagnostic proce- dures, PBU NGI-09 exhibits two competent physical barriers to the release of well pres- sure. Accordingly, the Commission believes that the well's condition does not compro- mise overall well integrity so as to threaten the environment or human safety, if operated within specified pressure limits. AOGCC's administrative approval to inject gas in PBU NGI-09 is conditioned upon the following: 1. BPXA shall record wellhead tubing, IA and OA pressures and injection rate daily; 2. BPXA shall submit to the Commission a monthly report of well pressures and in- section rates; i ~ ~ Mr. Steve Rossberg i January 2~, 2005 Page 2 of 2 3. BPXA shall perform a CIVIIT - IA x OA every two years to 1.2 times the maxi- mum anticipated well pressure, the results of which shall be provided to the Commission; 4. BPXA shall perform an MIT - IA every two years to 1.2 times the maximum an- ticipated well pressure, the results of which shall be provided to the Commission; 5. BPXA shall install and operate automatic well shut-in or pressure limit equipment on the well's OA; 6. BPXA shall provide the Commission with details of the specific automatic well shut-in or pressure limit equipment selected, and the well pressure operating lim- its, before injecting gas in PBU NGI-09; 7. BPXA shall limit the well's OA operating pressure to 3500 psi; 8. BPXA shall immediately shut in the well and notify the AOGCC if there is any indication of a change in the well's mechanical condition; and 9. After .well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 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 rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23 a following the date of this letter, or the next working day if the 23rd day falls o holid or weekend. A person may not appeal a Commission decision to Su~ri~r C rt u s rehearing has been requested. ,yenrnt. 1~ Orman Chairman e 1~1r!. :.! I. ~.' ¡u¡ ¡r ~w e ~ ¡fU 'ò. '\.. 11.''\) o j~ LA~ FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 11~-O(P~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI -09 Sundry Number: 306-170 Dear Mr. Reem: 8C~Nfn ," c .2. t: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this/~ay of May, 2006 Encl. ø C!lt,E>¡s-.Vk ~~ "3'/J~b~ lfc ),/IS/~ 1IJ4~ s/lsl2-00~ ~ e STATE OF ALASKA e ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~APPLICATION FOR SUNDRY APPROVAL C 20 MC 25.280 ""ile'>,,' 1. Type of Request: 0 Abandon a Repair Well o Plug Perforations o Stimulate o Other u o Alter Casing a Pull Tubing o Perforate New Pool o Waiver o Re-Enter Suspended W o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development 0 Exploratory 176-068 ,,- 1::S. Address: o Stratigraphic 181 Service 6. API Number: /' P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20228-00-00 7. KB Elevation (ft): 47' 9. Well Name and Number: PBU NGI-09 ..- 8. Property Designation: 10. Field / Pool(s): ADL 028302 Prudhoe Bay Field / Prudhoe Bay Pool i" %;,;;;, ~ Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft) Plugs (measured): Junk (measured): 10980 8615 10893 8549 None None CasinQ LenQth Size MD / TVD Burst Collapse Structural Conductor 72' 20" 72' 72' 1530 520 Surface 2715' 13-3/8" 2715' 2715' 5380 2670 Intermediate 9750' 9-5/8" 9750' 7721' 6870 4760 Production Liner 1544' 7" 9431' - 10975' 7514'-8611' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 10293' - 10861' / 8105' - 8525' 7" x 5-1/2" x 4-1/2" L-80 / N-80 9469' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'FB-1' packer / Packers and SSSV MD (ft): 9424' // 12. Attachments: 13. Well Class after proposed work: /' 181 Description Summary of Proposal 0 BOP Sketch o Exploratory o Development 181 Service o Detailed Operations Program 14. Estimated Date for Ma~, 2006 15. Well Status after proposed work: Commencing Operations: oOil o Gas o Plugged o Abandoned 16. Verbal Approval: Me: o WAG 181 GINJ oWINJ o WDSPL Commission Representative: 17. I hereby certif rg:at the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Nam~ avid Reem~ /"\ Title Drilling Engineer K ð.A '-- -j) (v _ JéK-e/}~ Date --5/; c/O" Prepared By Name/Number: Signature Phone 564-5743 Terrie Hubble. 564-4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number~ ~ IJ ...1'1 () o Plug Integrity ~OP Test ~chanicallntegrity Test 0 Location Clearance +0 4000 ~\ RBDMS BFl MA V í {1 20U6 Other: \~ t-~ ßoPE . ...4... Subsequent Form Required: I~~ ~f¡ APPROVED BY Date6~{í IJ h Approved By: COMMISSIONER THE COMMISSION Form 10-403 Revised 07/2005 (rRxt' At- ~bmit,A'n Duplicate IlJ e e Well Status: Shut-in gas injector. Well has confirmed inner x outer annulus / communication. The well is secured with a tubing tail plug. Proiect: Retrieve existing 7",29#, L-80 IPC LTC 8rd completion including the packer and tail-pipe. Cut and pull ~2300' of9-5/8". Tie-back in with 2300' of new 9-5/8", /' 47#/ft, L-80 TC-II casing and cement in place. Re-complete with 7", 26#/ft x 7.625", /// 29.7#/ft, L-80 Vam Top HC IPC tubing, permanent packer with tail-pipe ~2' above existing 7" liner-top packer. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. PRE-RWO · Set TTP in "XN" nipple to secure well. · Jet cut 5-112" tubing in pup joint above the packer. · Circulate the well over to seawater with diesel rreeze protect. CMIT to 2500 psi to verify tubing tail plug integrity. MITOA to 2500 psi to verify 13-3/8" shoe / integrity. Set and test BPV in tubing hanger. RWO 1. MIRU workover rig. Circ out diesel rreeze-protect and verify well is dead. Set TW C in tubing hanger and test. 2. ND tree, NUællY test BOPE per BP and AOGCC regulations (250 psi lo/- pressure test!. 00 I si high pressure test (test the annular to 3500 psi). 3. Pull 7" x 5-1 bing down to the cut. 4. Spear tubing stub and jar seal nipple rree rrom packer. 5. RIH w/packer milling BHA, turn well over to 10.2 ppg brine, mill over packer / and POH with same. 6. RIH and set 7" composite bridge-plug in 7" liner ~50' below liner top. PT plug to /" 2500 psi to prove up barrier. 7. Run 9-5/8" scraper to the liner top. .. 8. Set retrievable 9-5/8" bridge-plug ~30' above 7" liner top. /' 9. Run 9-5/8" USIT to locate top of cement in 9-5/8" x 13-3/8" annulus. 10. Set 9-5/8" RBP ~ 1500' below the TOC indicated on the USIT log. Spot 30' of sand on RBP. 11. Mechanically cut the 9-5/8" casing in the 1 st full joint above the TOe. /' 12. Mobilize and circulate out all Arctic Pack rrom the 9-5/8" x 13-3/8" annulus. 13. Pull 9-5/8" down to the cut. 14. Run wash shoe and 13-3/8" scraper down to the 9-5/8" stub. Ensure wash shoe is able to get beyond the next 9-5/8" collar by ~6'. Reverse circulate the wellbore clean. 15. Back-off 9-5/8" casing stub. / 16. ND BOP and tubing spool. NU BOP on casing head. Test same per step #2. 17. RIH with new 9-5/8", 47#/ft, L-80 TC-II casing, shoe-track and over-shot guide- sub. Screw into existing 9-5/8" casing. Pull test casing to 250K. Pressure up to open ES-cementer. Verify communication up 9-5/8" x 13-3/8" annulus. e e 18. Pull 250K tension on 9-5/8" casing. Split stack below BOPs and install 9-5/8" emergency slips and primary pack-off. Slack off ~ 1 O~K to" n engage slips and energize pack-off. 19. Cement 9-5/8" in place with target top of cement = S RF A . Close ES- cementer. .. 20. Split stack, cut 9-5/8". Set back BOPs. Make final dressing cut on 9-5/8" if required and NU tubing spool with secondary pack-off. NU BOPs. Test spool/BOPs to 4000 psi. 21. Drill out shoe-track down to sand top on RBP. PT casing to 4000 psi. ,.. 22. Retrieve the two 9-5/8" RBPs. Stand back drill-pipe. 23. RIH with 7" WLEG, 7" 26#/ft L-80 tail-pipe, 7" x 9-5/8" L-80 S-3 packer, 7" crossed over to 7", 26#/ft x 7-5/8", 29.7#/ft, L-80, VamTop HC completion. Will have a 7" RQ landing nipple at ~2100' for SCSSSV installation after the rig moves off. 7", 26#/ft, L-80, IPC VamTop HC tubing will extend up from the RQ nipple to surface. 24. Tag top of existing liner-top packer, P/U 2-3', reverse in packer fluid and freeze protection. Set S-3 packer. MIT-T to 4000 psi, MIT-IA to 4000 psi. /' 25. RIH w/5.625" milling assembly on drill pipe to the 7" composite bridge-plug. / Mill up plug. POH and LDDP. 26. RU slickline and set plug in "RN" nipple. Test plug to 1500 psi to prove up,¿ barrier. r 27. Set BPV. ND BOP, NU and PT adapter flange and tree to 5000 psi. 28. RDMO. POST-RWO / · Pull ball&rod from RHC sleeve. Pull RHC sleeve. . Set 7" HES "FXE" SCSSSV in "HRQ" nipple. . Tie-in injection lines, re-set wellhouse and instrumentation. · POI. MIT-IA w/AOGCC witness. TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Ivtax Angle = Datum MO = Datum TVO = ? GRAY AXELSON 47' NGI-09 5 NOTES: THIS WELL IS THE AELD FUEL GAS SUPPL YWELL THAT REQUIRES A SURFACE·CONTROLLED SSSV. ? 55 @ 8697' 11277' 8800' SS 113-3/8" CSG, 72#, MN-80, 10 = 12.347" I 17" TBG-IPC, 26#, L-80, .0383 bpf, 10 = 6.276" I ITOPOF 5-1/2" TBG I Minimum ID = 3.725" @ 9465' OTIS XN NIPPLE 1 TOP OF 7" LNR I 15-1/2" TBG-IPC, 17#, L-80, .0232 bpf, 10 = 4.892" I 1 TOP OF 4-1/2" TBG I 14-1/2" TBG, 12.6#, N-80, .0152 bpf, 10 = 3.958" 1 9469' 19-5/8" CSG, 47#, MN-80, SOO-95, 10 = 8.681" r ÆRFORA TION SUMMARY REF LOG: BHCS ON 10/11/76 ANGLE AT TOP ÆRF: 43 @ 10293' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 3-3/8" 4 10293 - 10356 0 07/02/90 3-3/8" 4 10416 - 10502 0 02/27/87 3-3/8" 4 10518 - 10605 0 02/27/87 3-3/8" 4 10621 - 10656 0 02/27/87 3-3/8" 4 10662 - 10712 0 02/27/87 3-3/8" 4 10726 - 10736 0 02/27/87 3-3/8" 4 10754 - 10805 0 02/27/87 3-3/8" 4 10810 - 10835 0 02/27/87 3-3/8" 4 10851 - 10861 0 02/27/87 PBTD I 10975' 10980' 10893' 17" LNR, 29#, MN-80, .0371 bpf, 10 = 6.184" I [§]-i DATE 10/23/76 01/24/91 09/20/03 12/31/04 01/28/06 04/30/06 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER JRClKK 9-5/8" CSG CORRECTION WJH/TLP ADD SAFETY NOTE JOtvVPJC SCSSSV CORRECTION SKB/PJC WAIVER SFTY NOTE DELETED DATE REV BY e 7" CAMCO BAL-O SSSV NIP, 10 - 5.937" (REQUIRES SCSSSV) -i 5-1/2" BAKER G-22 LOC & SEAL ASSY I -i 9-5/8" X 5-1/2" BAKER FB-1 PKR I -14-1/2" OTIS XN NIP, 10 = 3.725" I /' - 4-1/2" BAKER SHEA ROUT SUB I -i4-1/2" TUBING TAIL I H ELMO TT NOT LOGGED I COMMENTS PRUDHOE BA Y UNrr WELL: NGI-09 ÆRMrr No: '1760680 API No: 50-029-20228-00 SEC 1, T11N, R14E, 3375.1' FEL & 1959.47' FNL BP Exploration (Alaska) .. TREE = waLHEAD= ACTUATOR = KB. B..EV = BF. B..EV = KOP= ? Max Angle = 55 @ 8697' Datum M) = 11277' Datum lVD = 8800' SS 17" TBG-IPC, 26#, L-80, Vam Top He ? S NOTES: THIS WELL IS THE Rae RJB. GAS SUPPL YWELL THAT REQUIRES A SURFACE-CONTROLLED SSSV. GRAY AXB..SON 47' NGI-09 Proposed 9-5/8", 47#, L-80 TC-II Fully cemented to surface from -2300'md. 7" HES RQ SSSV NP, 10 = 5.963" (REQUIRES SCSSSV) /" 113-3/8" CSG, 72#, MN-80, 10 = 12.347" I 17-5/8" TBG-FC, 29.7#, L-80, Vam Top He -9350' I TOP OF 7" LNR I 9431' 7" HES "R" NP, 10 = 5.963" 9-5/8" x 7" BAKER "S-3" PKR, 10=6.00" 7" HES "RN" NP, [) = 5.770" 9-5/8" CSG, 47#, MN-80, S00-95, 10= 8.681" PERFORA TION SUWMARY REF LOG: BHCS ON 10/11/76 ANGLE AT TOP PERF: 43 @ 10293' Note: Refer to Production DB for historical perf data SIZE SPF MERV AL Opn/Sqz DA TE 3-3/8" 4 10293 - 10356 0 07/02/90 3-3/8" 4 10416 - 10502 0 02/27/87 3-3/8" 4 10518 - 10605 0 02/27/87 3-3/8" 4 10621 - 10656 0 02/27/87 3-3/8" 4 10662 - 10712 0 02/27/87 3-3/8" 4 10726 - 10736 0 02/27/87 3-3/8" 4 10754 - 10805 0 02/27/87 3-3/8" 4 10810 - 10835 0 02/27/87 3-3/8" 4 10851 - 10861 0 02/27/87 I PBTO I 7" LNR, 29#, MN-80, .0371 bpf, 10 = 6.184" I I TO I 10975' 10980' 10893' DATE 10/23/76 01/24/91 07/20/01 09/20/03 12/31/04 OS/21/05 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RNITP CORRECTIONS JRClKK 9-5/8" CSG CORRECTION WJI-VTLP ADD SAFETY NOTE JLW/PJC WAIVER DATE REV BY COMMENTS 01/28/06 JDMlPJC SCSSSV CORRECTK>N PRUDHOE BAY UNIT waL: NGI-09 PERMfT No: '"1760680 API No: 50-029-20228-00 SEC 1, T11N, R14E, 3375.1' FB.. & 1959.47' FNL BP exploration (Alaska) .. bp e e ..,. "".t,.I. ~~~ ~~. C'1i ~. .",,,,,. ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 REC~ December 22, 2005 DEC }~2 Z005 Alaska Oil & John K. Norman Chairman Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Äm:;¡10î ;:;g¡¡ Reference: PBU NGI-09'(PTD 176-068) Administrative Approval 3 0 2D05 Dear Mr. Norman: The purpose of this letter and accompanying attachment is to communicate recent diagnostic testing results associated with the subject well. NGI -09 is operating in accordance with the Alaska Oil & Gas Conservation Commission (AOGCC) conditions of administrative approval dated January 25, 2005 and April 6, 2005. The well exhibits annulus pressure communication between the inner annulus (IA) and outer annulus (OA). Recent AOGCC witnessed mechanical integrity tests (MIT) on the IA and IA by OA have passed. The well is operating within allowable IA and OA pressures. See the enclosed tubing by inner annulus by outer annulus (TIO) pressure plot. The wellbore schematic is also enclosed for reference. An inner annulus repressurization test was conducted on November 15, 2005. The results indicate an inner annulus repressurization rate of approximately 30 psi per day. Based upon a review of historical TIO pressures and recent MIT results, this minor repressurization rate does not indicate a change to the mechanical condition of the well. The well is operating within AOGCC prescribed pressures and incompliance with BPXA's internal waiver requirements. We believe the tubing constitutes a competent barrier and the well is safe to continue operations. The repressurization test results did not require the well to be shut in per Rule 8 of the AOGCC's administrative approval. We plan to continue injection operations as outlined in the above mentioned AOGCC conditions of administrative approval and BPXA's internal waiver requirements. If you have any questions, please call me at 564-5637 or Harry Engel at 564-4194. Sincerely, ~ Steve Rossberg BPXA Wells Manager BP Exploration (Alaska) Inc. e e Enclosure: NGI-09 TIO Plot Wellbore Schematic CC: Cismoski/Bixby Anders/Dube Mielke/Reeves Steve Rossberg John Kurz Kemp Copeland AI Schmoyer FS-1 Area Manager Harry Engel 4,000 3,000 2,000 1,000 o 12/21/2004 NGI-09 TIO 2/21/2005 4/21/2005 10/21/2005 12/21/2005 6/21/2005 8/21/2005 iIII Tbg IA OA OOA TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV =., KOP- Max Angle = Datum MD = Datum1VD= ? GRAY AXELSON 47' NGI-09 Arv NOTES: THIS WELL IS THE RELD RJEL èJl'SUPPLYWELL THAT REQUIRES A SURFACE-CONTROLLED SSSV. ***IAxOA COMM. OPERATING LIMITS: MAX lAP = 2000 PSI; MAX OAP= 2000 PSI (05/21/05)*** e ? 55 @ 8697' 11277' 8800' SS It -i 7" CAMCO BAL-O SSSV NIP, ID = 5,937" 113-3/8" CSG, 72#, MN-80, ID = 12.347" I 2715' 17" TBG-IPC, 26#, L-80, .0383 bpf, ID = 6.276" I I TOP OF 5-1/2" TBG I I TOP OF 7" LNR 15-1/2" TBG-IPC, 17#, L-80, ,0232 bpf, ID = 4,892" TOP OF 4-1/2" TBG I 9416' 7" X 5-1/2" XO I Minimum ID = 3.725" @ 9465' OTIS XN NIPPLE 5-1/2" BAKER G-22 LOC & SEAL ASSY 9-5/8" X 5-1/2" BAKER FB-1 PKR I 5-1/2" X 4-1/2" XO I 4-1/2" OTIS XN NIP, ID = 3.725" I 4-1/2" BAKER SHEA ROUT SUB 4-1/2" TUBING TAIL I ELMD TT NOT LOGGED 9444' 14-1/2" TBG, 12.6#, N-80, .0152 bpf, ID = 3,958" 9469' 9-5/8" CSG, 47#, MN-80, SOO-95, ID = 8.681" PERFORA TION SUMMARY REF LOG: BHCS ON 10/11/76 ANGLE AT TOP PERF: 43 @ 10293' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 10293 - 10356 0 07/02/90 3-3/8" 4 10416 - 10502 0 02/27/87 3-3/8" 4 10518 - 10605 0 02/27/87 3-3/8" 4 10621 - 10656 0 02/27/87 3-3/8" 4 10662 - 10712 0 02/27/87 3-3/8" 4 10726 - 10736 0 02/27/87 3-3/8" 4 10754 - 10805 0 02/27/87 3-3/8" 4 10810 - 10835 0 02/27/87 3-3/8" 4 10851-10861 0 02/27/87 I PBTD I 10975' 10980' 10893' 7" LNR, 29#, MN-80, .0371 bpf, ID = 6.184" ITD DATE 10/23/76 01/24/91 07/20/01 09/20/03 12/31/04 OS/21/05 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RN/TP CORRECTIONS JRClKK 9-5/8" CSG CORRECTION WJHlTLP ADD SAFETY NOTE JLW/PJC WAIVER DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: NGI-09 PERMIT No: "1760680 API No: 50-029-20228-00 SEC 1, T11N, R14E, 3375.1' FEL & 1959.47' FNL BP Exploration (Alaska) MEMORANDUM TO: ) Jim Regg 0), 4(''7-¡J,- P.I. Supervisor )<.,l&t1 vICD) FROM: Chuck Scheve Petroleum Inspector Well Name: PRUDHOE BAY UNIT NGl-09 Insp Num: mitCS050412124953 ReI Insp Num: State of Alaska Alaska Oil and Gas Conservation Commi' DATE: Wednesday, April 13, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-09 PRUDHOE BAY UNIT NGI-09 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-20228-00-00 Permit Number: 176-068-0 Packer Depth Pretest Initial Well NGI-09 Type Inj. N TVD 7510 IA 3020 4380 P.T. 1760680 TypeTest SPT Test psi 1877.5 OA 140 4420 Interval OTHER P/F F Tubing I 1060 1060 0" /' · "ofJ6 \ 9 Reviewed By: P.I. Suprv _:jG,L- Comm Inspector Name: Chuck Scheve Inspection Date: 4/11/2005 15 Min. 30 Min. 45 Min. 60 Min. 4360 4360 4400 4400 1060 1020 Notes: MITOA leaks to IA inspection mitCS050412124446 indicates IA holds with no comunication to OA. Test performed for waiver evaluation, Wednesday, April 13,2005 8{;/ftNhìEL" MAY 3 1. 20D5 Page 1 of 1 MEMORANDUM State of Alaska TO: ) Jim Regg V ( J. P.I. Supervisor 1\~~ 4- Zî(Ot:( Alaska Oil and Gas Conservation Commi' . ') DATE: Wednesday, April 13, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-09 PRUDHOE BAY UNIT NGI-09 t" ,..'-./" otft 4,' ....t1 , ,. FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv (jE/l- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT NGl-09 Insp Num: mitCS0504l2124446 ReI Insp Num: API Well Number: 50-029-20228-00-00 Permit Number: 176-068-0 Inspector Name: Chuck Scheve Inspection Date: 4/11/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-09 Type Inj. N TVD 7510 ! IA 60 4400 4380 4380 P.T. 1760680 TypeTest SPT Test psi 1877.5 OA 80 160 160 160 Interval OTHER P/F P Tubing I 1030 1140 1140 1140 Notes: MITIA passed, Test performed for waiver evaluation. SCA,~\n\!E[ Mf\Y ~j. 1 2.00~~ Wednesday, April 13, 2005 Page 1 of 1 ') ) ((ù ''\\'\ \W ¡i""iF) :::::JJ : :1 ¡,...'::J :¡-=3 !iii ¡U~ ,p 'I ' '''':::3 FRANK H. MURKOWSKI, GOVERNOR A.1,A.~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 April 6, 2005 Ms. Maureen Johnson Vice President, Greater Prudhoe Bay BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 "-:({"Ii ~'o.n'¡¡Eu'''~ Af"'¡r}l l' I¡ ;)IJ05 ",)),¡,,,,¡i-\R~b:!l _"~""" ,r n. 4: L ., RE: PBU NGI-09 (PTD 176-068) Automatic Well Shut In System Dear Ms. Johnson: The Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby approves BP Exploration (Alaska) Inc. ("BPXA")'s March 31, 2005 proposal to install and operate automatic shut in equipment on the subject well. By letter dated January 25, 2005, the Commission administratively approved BPXA's re- quest to inject gas in PBU NGI-09. PBU NGI-09 exhibits annulus pressure communica- tion, and the Commission's approval to inject gas was conditioned upon, among other things, installation and operation of automatic well shut in or pressure limit equipment on the well's outer annulus ("OA"). Please be reminded that AOGCC's administrative approval to inject gas in PBU NGI-09 remains conditioned upon the following: 1. BPXA shall record wellhead tubing, IA and OA pressures and injection rate daily; 2. BPXA shall submit to the Commission a monthly report of well pressures and injection rates; 3. BPXA shall perform a CMIT - IA x OA every two years to 1.2 times the maxi- mum anticipated well pressure, the results of which shall be provided to the Commission; 4. BPXA shall perform an MIT - IA every two years to 1.2 times the maximum an- ticipated well pressure, the results of which shall be provided to the Commission; Ms. Maureen Johnson April 14, 2005 Page 2 of2 ) ) 5. BPXA shall install and operate automatic well shut-in or pressure limit equipment on the well's OA; 6. BPXA shall provide the Commission with details of the specific automatic well shut-in or pressure limit equipment selected, and the well pressure operating lim- its, before injecting gas in PBU NGI-09; 7. BPXA shall limit the well's OA operating pressure to 3500 psi; 8. BPXA shall immediately shut in the well and notify the AOGCC if there is any indication of a change in the well's mechanical condition; and 9. after well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 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 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. Sincerely, 0P~ Daniel T. Seamount Commissioner $!~ CommIssioner rJ{.jf - ~ Aw/-.? (bv.tJ ~ RI e. )- ~.~·~j~:çt.;i::~.@.Jj~~.:.i~.riQPp'~~q·.···~.U~Ç)r1J.·~~iS···:W$II·..$6·4~.·.:q#.$.y~~~¡m.·:."·:"··",,,,, ~:r~~.~.··:'·~..Ergral·.,···:hI~r~·.·~"··.4~~.$~·'H·.~~¡B·R.·fo~>. ::," ........ E) ·f):'^'~d,<QpA\ ·····~ØQq·'3:39:q9· f()8()Q;' . . .". ~ Wi nton- This is a follow-up to our telephone conversation yesterday regarding the subject automatic well shut off system. BP is aware and appreciates the fact that injection pressure gas remains at the wellhead when the SSV is closed per the proposed design. This is consistent with the existing high/low pressure shut in system that has been successfully in place for the life of the field. Current operating procedures and response plans reflect this condition. The piping system from the Gas Plants is fully pressure rated to withstand shut in conditions. And finally, the injection header system has received a HAZOP (hazard identification and operability analysis) review, that has validated its design and safety. Please let me know if you have any questions. Harold R. Engel (Harry) GPB Staff Engineer 907 -564-4194 office 907 -564-5510 fax bp ) ) March 31, 2005 Hand-deli vered RECEIVED MAR 3 1 200, Ala~kfi Uil & Gas Cons. Commiss" Anchorage BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 John K. Norman, Chair ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Ave., Suite 100 Anchorage, AK 99501 Re: . Well PBU NGI09 (PTD 176-068) Dear Commissioner Norman: This letter is in response to your letter of January 25, 2005 granting administrative approval to inject gas into the subject well and subsequent letter of February 14, 2005 granting an extension. Conditions of AOGCC's approval require that BPXA install and operate automatic well shut-in or pressure limit equipment on the well's OA and provide the Commission with the details of the equipment selected prior to commencement of injection. In accordance with condition No.6 in the above referenced letter, BPXA is submitting to the AOGCC the details of the automatic well shut system that has been planned for this well. BPXA views the application of automatic well shut in devices for wells with annular pressure as one of a number of potential options to reduce risk associated with annular communication. However, this system is largely untried and unproven in arctic conditions, and system performance must, and will be closely monitored. In this regard, the installation of the automatic well shut in equipment on NGI-09, will provide an opportunity to evaluate this system's reliability and effectiveness in reducing risk of injection operations in wells with annular communication. By evaluating this system, we will be in a better position to assess further applicability of systems of this type to other wells The attached documentation provides detailed engineering discussion and drawings for the planned NGI-09 automatic well shut off system. We are available to meet with your technical staff to describe the system and further discuss issues and concerns. '~' Q John Norman, AOGCC March 31, 2005 Page 2 ) ) Please do not hesitate to contact me at 564-5671, or GPB's Operations Integrity Manager, Bruce Williams at 564-4632, with any questions. Sincerely, BJW /pj Enclosures: System Selection Recommendation for NGI-09/0ther Wells 5/16" Sensor High Pilot diagram Data Sheet for NGI -09 Outer Annulus Project Mechanical Piping and Instrument Diagram North Injection Pad John Norman, AOGCC March 31, 2005 Page 3 ') ) Bcc: Steve Kruse, ConocoPhillips Sonny Rix, ExxonMobil Kemp Copeland, GPB Field Mgr Jack Fritts/Roger Reddin, GPB Ops Mgrs Harry Engel, Drilling Engineer Bradley S. McKim, Legal Randall Buckendorf, Legal Bruce J. Williams, GPB Ops Integrity Steve Rossberg, Drilling Mgr J oe Anders/Anna Dube, Well Integrity Coordinators ) BP Exploration Alaska Inc. ) 31 March 05 NGI-09 Outer Annulus High Pressure Shutdown System System Selection Recommendation for NGI-09 and Other Similar Wells: · A Sigma Valves brand high pressure pilot (HPP), set at ",2000 psig, is recommended as the pressure sensing/trip device. The selected pilot will be fit for service in an H2S/C02 high pressure gas system, and arctic service rated. · The set point was selected per recommendation from the BP Wells Integrity Engineer. · The pilot should be installed on the outer annulus (OA), preferably in the rear area of the wellhead where shielding from potential disturbances such as wire-line work, etc. can be provided by the existing s-riser piping. · The pilot should be wrapped in an insulation blanket, of similar construction as existing flowline low pressure pilot (LPP) blankets - the purpose being to retain the heat of the wellhead to keep the pilot from freezing/hydrating. Note, freezing/hydrating is considered unlikely due to the nature of the annulus media (diesel and dry injection gas). · The pilot should be connected in parallel with the existing LPPs on the well safety system hydraulic panel. See drawing AE60010-002-014-Model. · The pilot should be installed with sufficient isolation and test valves to facilitate field testing of the HPP set point and proper function. · Field functional testing capability - High pressure injection gas, at ",3000+ psig, is available in/near the well house for scheduled maintenance and functional testing. If HP gas is not a viable test option, the HPP vendor has advised that a portable hydraulic hand pump can be used for functional testing. · Equipment familiarity - Connecting the pilot with the existing well safety system hydraulic panel will minimize confusion with a new/different system. Additionally, our contract pilot service provider is familiar with this pilot brand and configuration. · This system provides for the shutdown of the well in the event the annulus pressure exceeds the set point. · This system, as specified, is applicable only to wells of similar design, function and operating parameters as NGI-09. A detailed review of well specific considerations is recommended prior to applying this design to other well types (i.e. producers or water/MI injectors). NGI 09 Shutin Sys Description 050331.doc ~~=--< ~-------- ,-',~~,·""."r....'----.~ Ie - I.... ¡ " =l"'''' ¡. -\ r ,-- ", I ""- I'~ ,- -,0' r.'....--- f" .. ¡;. '.' "-~--~.; "'. '-" '..... ". -"""'.....__.~.Wh·...f.:-___._~ :3/:-~)( 5~: Œ) I :~::' {~(~:, (f~) Q_~) (g, (~I " (1], (~)(í~) ([9,) :~,~! / T /' /¡,.// \, íf1' " i , I !¡ ¡h\ ¡ I \-J~'*T(t';,;:/?'_P~:~,~,w,,,,,,,- -,-... ". F ~, , , "- .,' .! '..\, '~i -.~~'L , -,., ._,,' . "/ '-, ·1 'I 1.1 r~..~-w-,. ...! :'TJ ("1 r· r' i...... ("" 1"'-', ;Î n '-, 0 ,--In ,'1/ / - f" t {l~J'. -- -', '.' " r, ' . . ". .', .'. ..' f .;:::, . -f ·A r·..... r--J ¡,...,) "- ('-j 1 '- ¡"-f ''"''11"''lINL_L'" ,'~. f" ", ". '. ". " . 'í . ! ". f.. 'fT "1" r'-~ .'- ...... L.I_l.....L_! .} i ¡! I.....L ...,¡~-I~~~.~-_.~· ',~-.; --~- '.....,.. . 1'" '. 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SE.ï SCRE.W ~.. it" -, 1Z;:;1;-V~~~~' i~ " -SPÎRÄ~FIINQ-"=-~ f'd ~,~~ m;s.; M'Stt, ,- "1 Ð1\'IDER 7 COl,LAfi r:; r; 5/16'1 SENSOR HIGH PILOT 7.i$~ PACKING [î...çÎ\~ ~~ '~2S~ ARMÄLON ItAc~LIF' 4' ....·r¡·n::....EC'IT: _--,___,__~~~..o-~"- f.~ j"".-"~Y<~~~ 1iC"~Ð z ìÎr.a ~;-¡H-94 "~"'U!:' "2~ 22~8 u..cup ~ï\Ø3N't; ~W' PJStoo SE11~ff S I G M A ENTERPRISES INC. ," 'F - ~~~~~~~~ ~")~ ,~~.~ :ljl.Tr-~ ~-_-_-~~::f- 2: 1 1 -~f..' k~~ - H2:Sand C02 FLm·J 'LINE 229-SUB 5,!1~" LO'HER BODY ~ PART NO, Q'rt. PAAT NA!f~ L_ ....:-::';:<,,~~-~~.~---":.;:.,~ '_''''~_' _,e--~_~___"""'~---'---~---=---"-~-~--<--<~~_._- I !'IP,', AiIi<l"t-:. .HU. ',',w. ....... 22H2~ÞR3'1, ~-=-'''''''~.....~~'''-~-- ,. -- ') o BP Exploration (Alaska), Inc. Data Sheet Number: DAS-II-### Project: NGI-09 OUTER ANNULUS PROJECT Work Order Number: 35308509-01 General 1 Tag Number 2 P & 10 DWG 3 Line No, 4 Description/Service 5 Range - Increasing 6 Range - Decreasing 7 Manufacturer 8 Model 9 10 11 Pressure Element 12 Type 13 Material 14 Connection: Size/Location 15 16 17 Switch 18 Type 19 Quantity/Form 20 Enclosure 21 Conduit Size & Type 22 Rating: Volts Hz or DC 23 Amps / Watts/ HP 24 Load Type 25 Differential 26 Adjustment 27 Contacts 28 29 30 Process 31 Temperature NormaVMaximum 32 Pressure Normal/Maximum 33 Trip Point 34 35 Fluid 36 Fluid 37 Maximium Fluid Velocity 38 39 40 41 42 43 44 45 46 47 48 49 50 ) PRESS SWITCH LOW Revision: Checked By: TMR 00 W09-50HVP AE-6001-0-002 WELL NGI-09 OUTER ANNULUS PRESS SWITCH HIGH - GAS 1050-3650 PSIG N/A SIGMA 22H2SPH32-203 PRESSURE SENSOR STAINLESS STEEL 5/16" NPT / PROCESS; 1/4" NPT / CONTROL PRESSURE ELEMENT N/A N/A N/A N/A N/A N/A N/A FIELD ADJUSTABLE N/A 105 DEG F /130 DEG F 0-1000 PSIG /3500 PSIG 2000 PSIG INCREASING OIL / WATER / GAS N/A Notes: 1) All wetted parts shall meet NACE MR-01-075, 2) Vendor shall provide S,S. tag with set pressure tied to instrument with S.S, tie wire, file: DAS-II-NGI-09-PROJECT 050331 ,xis Approved By: TMR Sheet: 1 of 1 Date: Remarks: 02/10/2005 IFR PER EPT 35308509-01 Ø~ØØ9-3~ N ~ NIM'f'lm I :IJ~~~ ~ tlrl\: ¡ tt'~~ am' I ) .___." ,_ _ ~..'~_"___" .. ... ._.4_'._' ._ _. ~ ... § 8 7 6 5 ) . ___. - _~ "'...._.._ 0 ¡ i ......---, - ... ----..... .. - ---...... .. .- ...-" .. . .....--..... - .. ---- - . - .- -....- .-- .,.......-.. ..-.-.. -, - .---.... .. .. --.-, .- -. _n.__. - -. ...-.---- -.- --....- .. .. .- -. -.--- .- .- -. - ... - - - - - - - - - - - - - ~~~~I{õ~i:I~U~~II~H~gT~~¡ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --I INSTALLED BY ARCO DISTRICT ~.ø 0ø- LOW PRESSURE \ lPV ) w~:' ~ I PILOT //"'-Y ~ ACCUMULA TOR I 2' \ 2SØØ PSI . ~tS~=~~D "~v,Q,"I ~~~ J~--~ ~&~~ ) " HYORAULlC fLUID RESERVOIR TYPICAL HYDRAULIC CONTROL PANEL TAG CPØ1 .61 ---l ~(rÇ:~N(;t nVl1; HII/St-01 tW ._~_._----, ..-. !S) iSi !S) tD I wn «IS¡ IS> Z 01- W <.nW WI ::¡VJ Z ¡:: Z o U ----~ .--.----..-.-----.- - __. ..._0,_'_-" __ _.,._ --------- --.--- --.--.--". "-- ---.-- ~ - -- -- -- -. - --- - - - "'-_... .,-- .--- - . - .-- --..,.,- --- ..-.--- ---..-. --_ _. ----.-----.__._0.._.__-----., _......____...__...___'__..__ ..--,...,-- 74EV, 75EV, 76EV, 79EV,} _________-X " I 8ØEV, 81EV, 82EV, 83EV, ----- ~ ~:~~: ~~~~: ~:~~: ~;~~~ l ~~~~~~~~EVALVE J 8ØfV, 81 fV, 82fV, 83fV, r-- 84fV, 85fV, 86fV, 87fV. '.-----.--_ ,~"·,.Gii~ " 74GV, 75GV, 76GV, 79GV,} '..../ ,., ) ~" 8ØGV, 81GV, 82GV, 83GV, .--.-.-..-..--"," '<~Y.- ~, 84GV, 85GV. 86GV, 87GV.. I I I " ~' L1ß :: ::: i " I I I I I I I I I I TYPICAL INJECTION WELL :: :::: HEAD DETAIL, __-!.. I I " \r;~~~Š.I~)2,3,4,5,8,9,IØ, :" "\ ' I I I, '~- cbjrJ ( >;::;'/ 0\ - -- ~. SUB-SURfACE SAfETY VALVE wfji:")" ~ SET III ^ ~-rl' 5ØØØ PSIGL!.!.:::. $_ fUSIBLE LINK ~~; '- BACK PRESSURE CONTROLLER - - .... -.. -. - -l[ . Z:~~ATED OUTSIDE WELLHEAD BUILDING MANUAL BLEED /.- TO SSV ACTUATOR " RETURN -. " VALVE V~1 f SET III '--'.... 'î' WELL 2 & 9 \.",,~ . ONL Y ~~ r· 5ØØØ PSIG $'_ fUSIBLE LINK ~ '- BACK PRESSURE CONTROLLER 'HIGHER" LOW PRE~~~~~ -"" ----{><I XX~WEUII SEE T~E StLOWl ~vxx- 50 HV" '" HIGH PRESSURE PILO~"- SET @ 2ØØØ PSIG /-TO SSV ACTUATOR 1" Lib 1>-1 Æ TI SENSED .... PRESSURE ..--/ TES T ¢I}- VENT W' WELL HEAD DETAIL fOR GAS PRODUCTION WELL 16 (INITIAL) "{ :V: :W I I 1 I / SURfACE 4 ~~" SAFETY VALVE (Wc7\___....J~ ~V ," 9 ~1 SET C ^ ~rl5ØØØ PSIG L!.!.:::. $ fUSIBLE LINK ~ . \. BACK PRESSURE CON TROLLER ACCUMULA TOR 2SØØ PSI ---(;£ (\1\ & L:~.r-lJ/ ~ ~ & ,.,¿," ~<-----LJ-- HAND " HYDRAULIC PUMP fLUID RESERVOIR - - - ...-- - t .. 7 - . 1 - LOCATED OUTSIDE WELLHEAO 8UILDING MANUAL BLEED ~I I I I : WELL HEAD DETAIL fOR I GAS PRODUCTION WELL 17 ?~-----t~ I . : : ,-- d~1j-:-r L-)~/ (-{~/ L~ "-" SUB-SURfACE L _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ SAf[iY_V~~_ r~~~~:AlJttL§ïr:L:X:2.ø ALVP Blv<' Lib 1 1 "LOWER" LOW PRESSURE PILOT , " ?s? '... ..,. SENSED PRESSURE ~ ~ DUAL PILOT ARRANGEMENT IS TYPICAL fOR WELLS 12, 19, #7 AND #11 SEE DWG. INA-SØ-4Ø93ØI65-Ø1 fOR TUBING DETAIL AND MATERIAL. ~6-0' SVL ACCUMULA TOR 26ØØ PSI L1ß --f.~) wêG=1.ò 1:;:=-~ ~ L1ß -------¡n--ru I" L. LOCATED OUTSIDE ¡ WELLHEAD BUILDING MANUAL BLEED "N~,1 ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ ---.J I I l I I I I I ".. '" --- --_:-=-~~-~=--=~~:-=:~-=-=I=:il~:·-~~" ~A-lli]~ 'ff~;~~Ti~:J~{~,~~:~:,'-:, "'~~:~-=-~-!- ;:~ J~;i-, .= :~::C:I:~' - ;f.!J. I ~~I I cÄh~' 11fv om c.... 1,j¡11o f~~~ cÄh')! '''U:ti~E 10'" . ,.,¿," ~1-LJ- HAND PUMP . HYDRAULIC fLUID RESERVOIR J1 VÆLI NO, WXX-50AL VP 2900PSIG 29øørSI G 29ØØPSIG 29Ø~PSI G 9 7 11 i I ,- - - - -- -- - --------- 1 I NOTES: 1. ALL PIPING AND VALVES SHOWN ON THIS DRAWING PURCHASED BY RMPCO UNLESS OTHERWISE NOTED. fOR fURTHER INfORMATION SEE WBEC REfERENCE DRAWING LlSTEO BELOW AND WBEC BILL Of MATERIALS. 2. ALL PIPING MATERIALS ARE BASED ON ARCO NORTH SLOPE SPEClflCAlIONS f"~ 1>1 6('('(\11['611I('( "'IT" ~~Õl Æ~1'iR~~'¡,g~/~I;: lIi,I~. ~.'¡.,0(~:: II~t:I:I~t~ I;I~ :~.. ' 3. SPACE TO ACCDMDDATE AN ADDITIONAL TWO WELLS HAS ALREADY BEEN PROVIDED IN THE UNIT 18 CONTROL PANEL THE CABLING. BOTH INSTRUMENT AND POWER TO THE NORTH INJECTION SITE NO. 1 SHALL CONTAIN ENOUGH SPARE WIRES TO CARRY THE ADDITIONS AS SHOULD THE i[RMINAL BOXES BEING PROVIDED. /\. 4. NGI-Ø9 TO BE RETROfiTTED WITH HIGH PRESSURE ~ PILOT ON OUTER ANNULUS. ) A1 IS¡ 1ši IS> <.0 I w~ «IS> IS¡ 21- Ow VJW wI ::¡VJ Z ¡::: Z ° U ~'" "',. rORL4: rSI7Eru) MODULE: SØøø UNI1: 61:1 MECHANICAL PIPING Be INSTRUMENT DIAGRAM NORTH INJECTION PAD I"'" :,"~ 10''''"'0 '~E-6ØØ1Ø 1"'''~Ø2 0' 3 "';'5A AREA, NGI OI:Sll;N: ARCO Alaska, Inc. Ic.'[<~"" .....t'I«(JV,I,l: 4834 ) ) FRANK H. MURKOWSKI. GOVERNOR AltASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. ]TIi AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 January 25,2005 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU NGI-09 (PTD 176-068) Request for Administrative Approval Dear Mr. Rossberg: Per Rule 9 of Area Injection Order ("AIO") 004C.OOO, the Alaska Oil and Gas Conserva- tion Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to inject gas in the subject well. According to information submitted by BPXA, PBU NGI-09 exhibits pressure communi- cation between the well's inner annulus ("IA") and outer annulus ("OA"). AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU NGI-09. The Commission further finds that, based upon reported results of BPXA' s diagnostic proce- dures, PBU NGI-09 exhibits two competent physical barriers to the release of well pres- sure. Accordingly, the Commission believes that the well's condition does not compro- mise overall well integrity so as to threaten the environment or human safety, if operated within specified pressure limits. AOGCC's administrative approval to inject gas in PBU NGI-09 is conditioned upon the following: 1. BPXA shall record wellhead tubing, IA and OA pressures and injection rate daily; 2. BPXA shall submit to the Commission a monthly report of well pressures and in- jection rates; ~ I; f)f\n~ ""'"-~ f"'CG Ií~ n c-LJ ",~, [~, rr" r~NN tJ-JI r LJ)! v .~ ~'Vrt-,.. ) ) Mr. Steve Rossberg January 25, 2005 Page 2 of2 3. BPXA shall perform a CMIT - IA x OA every two years to 1.2 times the maxi- mum anticipated well pressure, the results of which shall be provided to the Commission; 4. BPXA shall perform an MIT - IA every two years to 1.2 times the maximum an- ticipated well pressure, the results of which shall be provided to the Commission; 5. BPXA shall install and operate automatic well shut-in or pressure limit equipment on the well's OA; 6. BPXA shall provide the Commission with details of the specific automatic well shut-in or pressure limit equipment selected, and the well pressure operating lim- its, before injecting gas in PBU NGI-09; 7. BPXA shall limit the well's OA operating pressure to 3500 psi; 8. BPXA shall immediately shut in the well and notify the AOGCC if there is any indication of a change in the well's mechanical condition; and 9. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 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 rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23 ây following the date of this letter, or the next working day if the 23rd day falls 0 holidz..y or weekend. A person may not appeal a Commission decision to Super1~ C rt u s rehearing has been requested. {~' . orman Chairman , ' ') ') Subject: NGI-09 (PTO #1760680) - Requestto return to injection From: IINSU, ADW Well Integrity Engineer".<NSUADWWeUlntegrityEngineer@BP.com> D~!?:.!~~, ,~7::~u~?004,,~ ~ :~1 :29, :?~9.t?~,~, ,"":. ,,:;,.' "",' ".,. ',:,: " "<:"., , ;":~,' ""!""'::'::"'::':'.-.: -.,'. ",,:.,: .:,'.~::.-,-.,:,:'~'"" ,':. >/,::.~" ro~;"" AQGCC:..¡tWmton ,Aubert (E'-mad) ; <wmton" 'aubert@admln';.state-:ak-'us>,..). ,:,':,~.,," ",......:.,;..,,,'.'- ,¡",,;,'-;-"-,ë'en-~-' I-i;-.'-c'''!;,-<-;.r,- " ~~~~~I~~~"&*~~~~~4'~~~.~.~!~Î~~~f.'~¡¡rj0' ,:;¡¡" "',E',-r\.geIH.,',,,',rn., ,@,B,p""c..om" " ,>, "',Reev'"es,.Q" a',n,' ald",."I:C<"':<"D,"",ee',~les, r;\~~, 8,1:1",00' ,',m. >, ',", ''''',''''',''','''',,-''''',',', ',","-''''-,",'','',":C'''', ',,-,: ",",',';"":"',:,'~,-',,'::"',":""'"',""','"","",,,,,"',' ~. ~ ~I ¿ .:v "~ . ~ . .' '," .. . '. '. . J- - ..'. .. . , .":' ..: ,".' :. . ...::.r::;;-,;" ~ . ~,~ '. :,~'. .. ..~~~. J:?!:......'.. ," .,- ~.~ :-:.~.: ":. """:',;'::""" :~~':7':~~.:"" :,'~.~:;:~ :-..," .: -~.":.~"~'''.' .:,~. :~; :, ''''i.'~}'.\:::;', >:':~5'~~~:;":~~ :-.~""~ Winton, NGI-09 (PTD #1760680) has been evaluated for IAxOA communication. When the well is on injection, WHPs are - 3500/900/900. Diagnostic testing was completed by setting a TTP and attempting a MITIA and MITOA to 4400 psi. The MITIA passed to 4400 psi. During the MITOA, pressure bled back to the IA so a CMIT -IAxOA was conducted and passed to 4400 psi. This proves the tubing and surface casing to be competent barriers. A wellbore schematic and the MIT form has been included for reference. We request approval to continue injeciton operations in this well given the information provided above. Please respond to this request with approval to return the well to injection while the sundry application process is being completed. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 «MIT PBU NGI-09 07-09-04.xls» «NGI-09.pdf» Content-Description: MIT PBU NGI-09 07 -09-04.xls PBU NGI-09 07-09-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 .....0"""'''''_--'-'.'.'.'''''.._._....-0.'''''''--''..''.'......-..........'... "".........--'''''''''''''''..........''''''''''''''''-'''-''.-..--"-'.""""'.-""-"""....'-.-.....'-.""".'...-..-..-""'''..''''''''''''-'''''-'-''..''''''''''''......-.......................................................... ""...''''''''.''.''''''.''.'.....-'''''.'' Content-Description: NGI-09.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED OEC 2 3 2004 .' ' /'. ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / NGI 07/09/04 Anna Dube Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well NGI-09 Type Inj. G TVD7,510' Tubing 1,990 2,760 2,760 2,760 Interval P.T.D.1760680 Type test P Test psi 1,878 Casing 0 4,400 4,380 4,380 P/F Notes: IA x OA Comm - Sundryl Waiver Eval - witnessed by AOGCC representative Well NGI-09 Type Inj. G TVD 7,510' P.T.D. 1760680 Type test P Test psi 1,878 Notes: IA x OA Comm - Sundryl Waiver Eval - not witnessed AOGCC Re:>resentative had previous commitment Well Type Inj. TVD P.T.D. Type test Test psi Notes: Tubing Casing OA 2,340 2,780 2,780 2,780 Interval 1,940 4,380 4,340 4,340 P/F 40 4400 4360 4360 0 P Tubing Casing 0 P Interval P/F Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Waiver Compliance Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test r-- Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19102 MIT PBU NGI-09 07-09-04-1.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) ,< ~ ) " _? TRæ= W8.LHEAD = GRA Y ACTUATOR = AXELSON .. ... .' .....'"'''' .... n" KB. ELEV = 47' BF. ELE.V = KOP=' Max Angle = 55 @ 8697' 'baïurriMO';;; ..... "f127i Datum TV D = 8800' SS -_? 113-3/8" CSG, 72#, MN-80, ID= 12.347" H 2715' ~ I 7" TBG-IFÇ, 26#, L-80, 0.0383 bpf, ID = 6.276" H 9416' I TOP OF 5-lIZ' TBG I~ 9416' NGI-09 ) SAFETY NOTES: THS WELL IS HE AELD FUEL GAS SlPPLY WELL. ~ J~ Minimum 10 = 3.725" @ 9465' OTIS XN NIPPLE I lOPOF7" LNR 1-1 9431' ~ 15-1/2"TBG-'FÇ, 17#, L-80, 0.0232 bpf, ID =4.89Z' 1-1 9445' 1 '1 I lOPQF 4-112" TBG H 9445' I 18 { 14-lIZ' TBG-PC, 12.6#, N-80, 0.0152 bpf, ID = 3.958" 1-1 9469' ~ ~ 9-5/8" CSG, 47#, MN-80, SOO-95, ID = 8.681" H 9750' PERFORATION SUWMARY REF LOG: SHCS ON 10/11/76 ANGLEATTOPÆRF: 43@10293' t-bte: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DA.TE 3-3/8" 4 10416-10502 0 02127/87 3-3/8" 4 10518-10605 0 02127/87 3-3/8" 4 10621-10656 0 02127/87 3-3/fJ' 4 10662-10712 0 02127/87 3-3/fJ' 4 10726-10736 0 02127/87 3-3/8" 4 10754-10805 0 02127/87 3-3/8" 4 10810-10835 0 02127/87 3-3/fJ' 4 10851-10861 0 02127/87 3-3/8" 4 10293-10356 0 07/02190 1 FB10 H 10893' I 7" LNR, 29#, rvt-!-80, 0.0371 bpf, ID = 6.184" H 10975' I 10 H 10980' DATE 10/23/76 , 01/24191 07/20/01 09/20/03 DA 1£ REV BY REV BY COMWENTS ORIGINAL COMPLETION LAST WORKOVER CORRECTIONS 9-5/8" CSG CORRB::TION RI'flP JRGlKK t-A . I II ~ COWMENTS 2252' H 7" CAMCO ML-O SSSV NIP, D = 5.937" I 9416' 9423' H 7" X 5-1/2" XO I H 5-112" BAKER G-22 LOG & SEAL ASSY I H 9-5/8" X 5-112" MKERFB-1 PKR I 9424' 9444' H 5-1I2"X4-112"XOI H 4-112" 011S XN NIP, ID = 3.725" 1 H 4-1/2" BAKER SHEAROUT SUB 1 H 4-1/2"TLBING TAIL I H ELMD TT NOT LOGGED I 9465' 9468' 9469' PRUDHOE BAY UNrr WELL: NGI-09 ÆRMT No: 1760680 API lib: 50-029-20228-00 SEC1, T11N, R14E, 3375,1' FEL & 1959.47'FNL BP Exploration (Alaska) [Fwd: NGI-09 (PTD #1760680) - Request to rp) to injection] ) t:Je - f>ri) l?~~ß < . ~ubject: [Fwd: NGI-09 (PTD #1760680) - Request to return to injection] From: Winton Aubert <winton - aubert@admin.state.ak.us> Da.'te: Tue, 17 Aug 200412:40:07 -0800 To::: James'B Regg <jim~regg@adnÜn~siate..ak.us> -------- Original Message -------- Subject: NGI-09 (PTD #1760680) - Request to return to injection Date: Tue, 17 Aug 2004 11:01:29 -0800 From: NSU, ADW Well Integrity Engineer .S.!i§.-g~p~~.~.!...~..!.!.?:!::..~.9.E.~.!:.Y~!.?:.9ineer@BP. cS?~.?.:. To: AOGCC - Winton Aubert (E-mail)<wintonaubert@admin.state.ak.us> CC: NSU, ADW Well Integrity Engineer <NSUADWWellIntegrityEngineer@BP.com>, NSU, ADW Well Operations Supervisor <NSUADWWell0perat.ionsSuperviso~c@BP. com>, Engel, Harry R .:::..ê!.?:.9.~lHR@BP. com>, Reeves, Donald F <ReevesDf@BP. com> Winton, NGI-09 (PTD #1760680) has been evaluated for IAxOA communication. When the well is on injection, WHPs are - 3500/900/900. Diagnostic testing was completed by setting a TTP and attempting a MITIA and MITOA to 4400 psi. The MITIA passed to 4400 psi. During the MITOA, pressure bled back to the IA so a CMIT-IAxOA was conducted and passed to 4400 psi. This proves the tubing and surface casing to be competent barriers. A wellbore schematic and the MIT form has been included for reference. We request approval to continue injeciton operations in this well given the information provided above. Please respond to this request with approval to return the well to injection while the sundry application process is being completed. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 «MIT PBU NGI-09 07-09-04.xls» «NGI-09.pdf» PBU NGI-09 Content-Type: application/vnd.ms-excel Content-Encoding: base64 ----------------..-----....-.-.-.....-...............---.""""''''''''---d''_'__----'-'-'-'''-''''--'--'------------------__--___m_...__------ -.....----.----------.--.--"---....--..-..---.......--...-.----.-.-......----.-------.------..---.---..-........ ----..-.-.-.-.------.--......-.--.---.---..--------..----..---...----..-.-.........- Content-Type: application/octet-stream Content-Encoding: base64 SCANNELl NO\! 1 5 2004 1 of 1 8/18/20048:37 AM -_? GRAY .,..,-................."....._~ AXELSON .. m..... m...... 47' TRæ =1' .." W8.LHEAD = -.-.. ..........,..........".-.... A CfUA TOR = '........................... ... KB. ELEV = BF. ELE:V = kÖp= . Max Angle = ÖatUm"r;.i,ö';;;;'''''' DatumTVD= -_? 55 @ 8697' ..... ''''''112ii 8800' SS 113-3/8" CSG, 72#, MN-80, 10= 12.347" H 2715' ~ I 7" TBG-IR:;, 26#, L-80, 0.0383 bpf, 10 = 6.276" l-f 9416' 1 TOP OF 5-112" TBG I~ 9416' NGI-09 SAFETY NOTES: THS WELL IS HE RELD FUEL GAS SlPPLY WELL. J 1 ~ Minimum ID = 3.725" @ 9465' OTIS XN NIPPLE 1 TOPOF7" LNR 1-1 9431' ~ 15-1/2"TBG-IR:;, 17#, L-80, 0.0232 bpf,lD =4.892" 1-1 9445' 1 1 TOPOF4-1/2"TBG 1-1 9445' 1 J { 14-1/2" TBG-PC, 12.6#, N-80, 0.0152 bpf, 10 = 3.958" 1-1 9469' , 9-5/8" CSG, 47#, MN-80, Soo-95, 10 = 8.681" H 9750' PERFORATION SUIVMARY REF LOG: BHCS ON 10/11/76 ANGLEATTOP ÆRF: 43@ 10293' t-k>te: Refer to Production DB for historical perf data SIZE SPF ImER\! AL OpnlSqz )6. TE 3-3/8" 4 10416-10502 0 02127/87 3-3/8" 4 10518-10605 0 02127/87 3-3/8" 4 10621-10656 0 02127/87 3-3/8" 4 10662-10712 0 02127/87 3-3/8" 4 10726-10736 0 02127/87 3-3/8" 4 10754-10805 0 02127/87 3-3/8" 4 10810-10835 0 02127/87 3-3/8" 4 10851-10861 0 02127/87 3-3/8" 4 10293-10356 0 07/02190 1 PBlDl-i l 7" LNR, 29#, NN-80, 0.0371 bpf, 10= 6.184" 1-1 I lD H 10893' 10975' 10980' 2252' H 7" CAMCO M.L-O SSSV NIP, D = 5.937" I ~ 9416' 9423' 9424' 1'1 9444' 9465' 9468' 9469' ~ r-4 ~ DATE REV BY COMfv'ENTS DAlE REV BY CO~ENTS 10/23/76 ORIGINAL COMPLETION 01/24/91 LAST WORKOVER 07/20/01 RI'flP CORRECfIONS 09/20/03 JRC'KK 9-5/8" CSG CORRECTION H 7" X 5-1/2" XO 1 H 5-1/2" BAKER G-22 LOG & SEAL ASSY 1 H 9-5/8" X 5-112" M.KER FB-1 PKR 1 H 5-1/2"X4-1f2" XO 1 H 4-1/2" 011S XN NIP, 10 = 3.725" 1 H 4-1/2" BAKER SHEAROUTSUB I H 4-1/2"TUBINGTAIL I H ELMO TT NOT LOGGED I SCANNED NO\! 1 5 200~. PRU[)- OE BAY UNrr WELL: NGI-09 ÆRMTNo: 1760680 APII'Ð: 50-029-20228-00 SEC 1, T11 N, R14E; 3375.1' ÆL & 1959.47' FNL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Consen..ation Commission TO: Jim Regg hêt1/J 11'JIl)4- P.I. Supervisor T l DATE: Wednesday, July 14.2004 SUBJECT: l\.1echamcallmegnl) Tests BP EXPLORA nON f ALASK..l\ I INC FROM: Chuck Scheve Petroleum Inspector NGI-09 PRUDHOE SA Y UNIT NGI-09 Src: Inspector Reviewed By: ,.--.-, C- P.I. Supn'- , Þ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BA Y UNIT NGI-09 Insp Num: mitCS040711090307 Rei Insp Num: API Well Number: 50-029-20228-00-00 Permit Number: 176-068-0 Inspector Name: Chuck Scheve Inspection Date: 7/9/200-1 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. \Ve II NGI-09 Type Inj. N TVD 8615 I IA 0 ..\..\00 ..\380 ..\380 P.T. 1760680 T~'peTest SPT Test psi 18775 lOA 30 30 30 30 Inten'al OTHER PIF P Tu bing 1990 ~760 ~760 2760 Notes: Test performed for IA x OA waiver evaluation. No leak apparent during this 30 minute test. Wednesday, July 1-1,2004 Page 1 of 1 MEMORANDUM State of ~aska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair DATE: June 1,2002 THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector SUBJECT: Mechanical Integrity Tests ''!~,t,~O-~"' 07,09,13 & 14 Prudhoe Bay Field Prudhoe Bay Unit NON- CONFIDENTIAL '" WellJ NGI-07 P.T.D.I 1760380 Notes: WellI NGI-09 I P.T.D.I 1760680 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. J Type lnj. J G J T.V.D. J 7398 I Tubingl 3360 J 3360 I 3360 J 3360 I lntervall 4 I Type testI P I Testpsil 1850 1CasingI 280 I 20401 20301 20301 P/F I P I Type lnj.I O I T.V.D. ]7510 J Tubing 13550 J3550 1355O 1355O I lntervall 4 Type testl, P I Testpsil 1878 ICasingI 3oo I 245o1 24501 245o1 P/F I P ",' P.T.D.I 1780910 ITYpetestl P ITestpsil 1836 I Casingl 80 I 25001 2490 I 25001 P/F I P Notes: WellI NGI-14 I Typelnj. I G I T.V.D. [7171 I Tubing I 3550 I 3550 I 3550 I 3550 [IntervalI 4 , P.T.D.I 1780920 ITypetestl P I Testpsil 1793 I Casingl 50 I 25601 2330 I 23001 PIE I P-- Notes: We,I I TypeInj. P.T.D. I Type test Notes: 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 during Workover O= Other (describe in notes) Test's Details I traveled to BP's Prudhoe Bay Field NGI Pad to witness 4 year MIT's. Good tests, no failures or problems witnessed. M.I.T.'s performed: 4 Attachments: Number of Failures: 0 Total Time during tests: 3 hrs. CC: MIT report form 5/12/00 L.G. MIT PBU NGI 06-0t-02jc.xls 6/4/02 ~,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI~0N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Stimulate Plugging m Perforate Alter casing ~ Repair well Pull tubing X Other X Workover 2. Name of Operator 5. Type of Well' 6. Datum elevation (DF or KB) Development ARCO Alaska. Inc. Exploratory __ 47' RKB feet 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 20' FSL, 940' FWL, Sec. 1, T11N, R14E, UM NGI-09 At top of productive interval 9. Permit number ~, 2205' FNL, 2197' FWL, Sec. 2, T11N, R14E, UM 76-68 / f~o-87,~' At effective depth 10. APl number 1997' FNL, 1946' FWL, Sec. 2, T11N, R14E, UM 50-029-20228 At total depth 11. Field/Pool Prudhoe Bay Field 1960' FNL, 1903' FWL, Sec. 2, T11 N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 1 0980' feet Plugs (measured) None true vertical 861 5' feet Effective depth: measured 10893' feet Junk (measured) Fill @ 10819' true vertical 8549' feet Casing Length Size Cemented Measured depth True vertical depth Conductor 7 6' 2 0" 240 sx AS cmt 1 0 0' 1 0 0' Surface 2691' 1 3-3/8" 3150 sx PF II 271 5' 271 5' Intermediate 9726' 9-5/8" 750 sx Class G & 9750' 7685' 275 sx PF 'C' Liner 1544' 7" 630 sx Class G 9431'-10975' 7480'-8573' Perforation depth: measured 10293'-10356', 10416'-10502', 10518'- 10605', 10621 '-10656', 10662'-10712', 10726'-10736', 10754'-10805', 10810'-10835', 10851'-10861' true vertical 8105'-8151', 8195'-8258', 8270'-8334', 8346'-8372', 8376'-8414', 8424'-8431', 8445'-8483', 8487'-8506', 8518'-8525' Tubing (size, grade, and measured depth 7" , L-80, tubing w/ tail @ 9469' Packers and SSSV (type and measured depth)~) ~ CE IVED Camco 'BaI-O' sssv @ 2252', Baker 'FB-I' pkr @ 9424' ~,,,, ,_. 13. Stimulation or cement squeeze summary N/A [~ u 1991 Intervals treated (measured) .0il & Gas Cons. Treatment description including volumes used and final pressure "~,~Ctl01'8.~.'. '~'~' ..... 14. N/A Representative Daily Averaae Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments *Workover Well History 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X* Oil Gas Suspended Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~, ~/}q,4/,_/ ~_~_ .c/F,.A~ Title Drilling Analyst Date Form 10-¢t~, Rev 05/17/89 · SUBMIT IN DUPLICATE ARCO Oil m.-~rGa. C4mpany O '~ Well History - Initial Report - Daily Inatmctlona: Prepare and submit tile ',~ 11190~' on the first Wednesday after a well is spudded or workover operations are st~ed. Daily wore p~or ~ ~'~ be summarized on the form giving inclusive dates only. District ARCO · : ..... NORT~ SLOPE ~[ease or U,~t ADL 28302 ~e~d PR~HOE BAY : Auth. o, W.O. n~s 4061 ~T~t~e WO~OVER IState AK API: 50-029-20228 Operator ARCO cpu dded ° r W'(~(~]~¢~ T IDate 01/08/91 IH°ur I ARCO W.I. 0130 HRS IPri°r status 21.7800 if a W.O. Date and depth as of 8:00 a,m. 01/08/91 ( TD: 0 PB:10893 SUPV:DCS/GTG 01/09/91 ( TD: 0 PB:10893 SUPV:DCS/GT( 01/10/91 ( TD: 0 PB:10893 SUPV:HMP/RJ~ 01/11/91 ( TD: 0 PB:10893 Comple, ...... d [~lt~d~, 1) 2) R/U HARDLINE. MOVE RIG TO NGI-9. HARDLINE. MW: 0.0 RIG ACCEPTED @ 01:30 HRS, 1/08/91. R/U DAILY:S15,842 CUM:$15,842 ETD:S15,842 EFC:$1,101,000 DISP WELL W/ 9.0 PPG NACL. MW: 9.0 NSC1 TEST TREE & LUB. PULL BPV. BEGIN LUB/BLEED PROC. PUMPED 481 BBLS NACL BRINE R/U ATLAS. RIH. SHOOT 10 HOLES @ 9140'-9142'. CIRC. POOH W/ GUN. R/D ATLAS. ALL SHOTS FIRED. BLEED TBG GAS. DISP WELL W/ 9.0 PPG NACL BRINE. DAILY:S32,870 CUM:$48,712 ETD:S48,712 EFC:$1,101,000 L/D TBG. DISP WELL W/ 9.0 PPG NACL. SET BPV. TEST SAME. PULL BPV. SPEAR HGR, PBR. MW: 9.0 NaC1 N/D TREE. N/U BOPE. POOH. L/D TBG. DAILY:S23,370 CUM:$72,082 ETD:S72,082 EFC:$1,101,000 4) L/D BHA #1. MW: 9.0 NaCl L/D 73' TBG. L/D BHA #1. SUPV:J%MP/RJ~ ~ .~:!~.DAILY:$29,244 CUM:$101,326 ETD:S101,326 EFC:$1,101,000 01/12/91 (i~':i!'OOH. MW: 9.0 ,aCl' TD: 0 1'3~i~IH W/ BHA #2 TO 8647'. REV CIRC. RIH TO 9156'. REV CIRC PB:10893 / [00 BBLS HEC SWEEP POOH. RIH W/ aHA #3. SPEAR FISH. CSU. DAILY:S25,049 CUM:$126,375 ETD:S126,375 EFC:$1,101,000 01/13/91 (6) TD: 0 PB:10893 SUPV:HMP/RJ~ 01/14/91 (7) TD: 0 PB:10893 SUPV:HMP/RJ~ 01/15/91 ( ) TD: 0 PB:10893 SUPV:HMP/RJ~ The al3ove is corral){ For for~Dre~aretlon Bcd distribution. see Procedures Manual. Section 10, Drilling. Pages 86 and 87. PREP TO POOH. MW: 9.4 NaCl POOH. RIH W/ BHA #4. TAG FISH @ 9162'. CBU. WELL FLOWING. SHUT IN. CIRC THRU CHOKE. WT UP TO 9.4 PPG W/ SALT. OPEN WELL. CBU. PREP TO POOH. DAILY:S23,370 CUM:$149,745 ETD:S149,745 EFC:$1,101,000 UNSEAT RTTS. - MW: 9.4 NaC1 POOH. RECOVER PBR. L/D BHA #4. RIH W/ BHA #5 RBP. SET @ 9100'. TEST CSG. TEST BOPE. UNSEAT RBP. PREP TO CBU. DAILY:$33t034 CUM:$182,779 ETD:S182,779 EFC:$1,101,000 ATTEMPT 2ND BACKOFF. MW: 9.4 NaCl POOH. CBU. POOH. P/O RTTS. RIH. SET @ 830'. POOH. P/U RBP. RIH. SET @ 635'. POOH. DUMP SAND ON RBP. RIH TO 480'. DISPLACE HOLE W/ DIESEL. POOH. M/U CSG CUTTER. CUT ,oo . ,oo AR3B-459-1 -D INumber all daily well hiatos, forms consecutively aa they are prepared for each well. iPage no. ARCO Oi~-~d Gas Company 4) "~ Daily Well History--lnterir Irletl~,;;c,~,~; This form is used during drilling or workover operations. If testing, Coring or perforating, show formation name in describing work Oerf0rmed. Number all drill stem tilts ~uentlllly. Altech de~cr piton of all cores. Work performed by Producing Section will be reported on "lflleHm" sheets until final completion. Report official or representative te~t off "Filtel" form. 1) Submit "llttertm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string ie set. Submit weekly for workovers and following setting of oil strin§ until completion. Oistrict JCounty or Parish ~ie~d _~_pcr~ ~T.~r~ TNC. J NORTH SLOPE I Lease or Unit NGI-9 Date and Complete record for each day while drilling or workover in progress as of 8:00 a.m. NABORS 2E~ IState AK Well no. 01/16/91 ( TD: 0 PB:10893 SUPV:HMP/RJB 01/17/91 ( 1~ ) TD: 0 PB:10893 SUPV:LAP/DBJ 01/18/91 ( 1 ) TD: 0 PB:10893 SUPV:LAP/DBJ 01/.19/91 ( 1~) TD: 0 PB:10893 SUPV:LAP RIH. DAILY:S24,529 CUM:$207,308 ETD:S207,308 EFC:$1,101,000 RIH W/ STRING SHOT. MW: 9.4 NaCl SET BACKOUT TOOL #2. ATTEMPT TO BACKOUT. NO GO. POOH. RIH. SET TOOL. ATTEPT TO BACKOUT. NO GO. POOH. SET BACK TOOL. P/U CSG CUTTER. RIH. POOH. P/U BACKOUT TOOL. RIH. SET TOOL @ 117' NO GO. POOH. SET BACK TOOL RIH W/ SPEAR. SET & VIBRATE ABOVE COLLAR. POOH. P/U BACKOUT TOOL. RIH. SET @ 80'. NO GO. POOH. RIH W/ SPEAR. SET SPEAR & TORQUE. RIH W/ 240 GR STRING SHOT. DAILY:S23,370 CUM:$230,678 ETD:S230,678 EFC:$1,101,000 N/D BOP TO CUT 9-5/8" TIEBACK. MW: 9.4 NaC1 RIH W/ 5' STRING SHOT (240 GR/FT). ATTEMPT TO EST LEFT HD TORQ PRIOR TO FIRING. NO TORQ. POOH. R/D W/L. POOH W/ SPEAR. FOUND TANG (ANTI-ROT STOP) ON GRAPPLE. REPLACE SPEAR. RIH. SET IN STUB. R/U W/L. RIH W/ STRING SHOT. NO TORQ. FIRED SHOT. UNABLE TO POOH W/ W/L. POOH W/ DP. P/U TSA HYD BACKOFF TOOL. RIH. SET TOOL. UNSUCCESSFUL. POOH. RIH W/ SPEAR. SET SAME. RIH W/ STRING SHOT. EST LEFT HD TORQ. FIRED SHOT. NO MOVEMENT. POOH W/ W/L RIH. REPEAT W/ 400 GR/FT SHOT. FIRED. TORQ RELEASED. POOH. RIH W/ BACKOFF TOOL. BROKE CONNECTION. POOH. L/D TOOL. RIH W/ SPEAR. ENGAGE STUB. POOH W/ STUB & 1 JT 9-5/8" CSG. RIH W/ 9-5/8" CSG. TEST C-SG~.--N~D-BOPE~ DAILY:S35,914 CUM:$266,592 ETD:S266,592 EFC:$1,101,000 B/D BHA. MW: 9.4 NaC1 N/D BOPE. INSTALL EMERGENCY SLIPS. DRESSED, CUT & PACKOFF AREA. TEST SEALS. N/U BOPE. TEST SAME. M/U BHA. RIH. TAG SAND @ 622'. ATTEMPT TO REV CIRC. NO GO. POOH. JUNK BASKET FULL OF SAND. RECOVERED GRAFFLE. DAILY:S25,370 CUM:$291,962 ETD:S291,962 EFC:$1,101,000 POOH W/ RBP. MW: 9.4 NaC1 RIH W/ RBP RETRIEVING TOOL. WASH SAND F/ 585'-635' RELEASE RBP. POOH. L/D SAME. RIH. ENGAGE RTTS. RELEASE. PUMP 30 BBLS HIGH VIS SWEEP. ENGAGE RTTS. RELEASE. POOH. RIH W/ OIL JARS. WASH. POOH. RIH. ROTATE INTO STORM VALVE. POOH W/ RTTS. L/D SAME. RIH. ENGAGE BP @ 9100'. CBU. POOH. CBU. POOH. DAILY:S35,352 CUM:$327,314 ETD:S327,314 EFC:$1,101,000 The above is correct Drilling Supt. For form P~psreflon ~'~d distribution see PrOcldurll Manual Section I0, Drilling, Pages 86 and 87 AR38-459-2-8 NumOer all dady well history ~orms consecutively ~,~ce ~ as they are prepared lot eacll well. ARCO Oil al~ Gas Company O .... Daily Well History--Interim Inllnlcll~ltl: Thai foffn il umd during drilling or ~oi'kovlr ol~retionl. If testing, coring, or perforating, show formatiofl name in describing work performed. Number all drill stem tilts sequentlllly. Attlc~ dllcriptiofl of all cores. Work performed by Producing Section will be reported on "lltllrtat" sheets until final completion. Report official or reprele~ltetlvl tilt off "FNIII" form. t) Submit "lnteril~l" sheets when filled out but not less frequently than every 30 days, or (2) on Wednelcley of the week in which oil ltrin~ Ii mt. Submit weekly for workovers and following Setting Of oil strin~ until completion. DIst,ic, Ircounty~ or Pari,h i Stete ARCO ALASKA ]:NC, NORTH SLOPE: Field ~ Leem or Unit lWell no. I ?~TDHQE BAY ' NGI-9 'Complete record for each day while drilling or workover in progress Date and de~il al of 8:00 a.m. 01/20/91 (3) TD: 0 PB:10893 SUPV:LAP/RW~ 01/21/91 (4) TD: 0 PB:10893 SUPV:LAP/RW 01/22/91 (]5) TD: 0 PB:10893 SUPV:LAP/RW( 01/23/91 (6) TD: 0 PB:10893 SUPV:LAP/RW 01/24/91 (7) TD: 0 PB:10893 SUPV:HMP NABORS 2ES POOH W/ PKR MILL. MW: 9.0 NaC1 POOH W/ 9-5/8" RBP. L/D SAME. M/U BHA #20. RIH. CIRC & REDUCE F/ 9.4 PPG TO 9.0 PPG. MILL PKR @ 9202' MILL TO 9210' CBU. RIH TO 9419'. CIRC. PUMP TEMPBLOCK. POOH W/ PKR MILL. DAILY:S46,127 CUM:$373,441. ETD:S373,441 EFC:$1,101,000 P/U DRILLPIPE. MW: 9.0 NaCl POOH W/ BHA #20. RIH W/ BHA #21. ENGAGE PKR @ 9443' POOH 12 STDS. CBU. POOH. L/D PKR & TAILPIPE. RIH W/ BHA #22. DAILY:S102,629 - CUM:$476,070 ETD:S476,070 EFC:$1,101,000 L/D BHA. MW: 9.0 NaC1 RIH. CBU. PUMP 50 BBLS HEC SWEEP. CLEAN OUT FILL F/ 10865'-10891' PUMP 50 BBLS HEC SWEEP. POOH. M/U BHA #23. RIH. TAG TOL @ 9447'. CIRC. PUMP 50 BBLS HEC SWEEP. POOH. L/D BHA. DAILY:S99,163 CUM:$575,233 ETD:S575,233 EFC:$1,101,000 POOH. MW: 9.0 NaC1 L/D DC. P/U RTTS & RIH. SET @ 9427' TEST CSG. CBU. POOH. P/U BAKER 9-5/8" 'FB-i' PKR W/ 4-1/2" TT. TIH. SET PKR @ 9424'. TEST PKR. CBU. POOH. DAILY:S31,802 CUM:$607,035 ETD:S607,035 EFC:$1,101,000 DISP WELL W/ DIESEL. POOH. L/D PKR RUNNING TOOLS. STING INTO PKR. TEST LINES. MW: 8.4 Seawater CHANGE RAMS. RUN 7" COMP. DISP WELL W/ 125 BBLS DIESEL. DAILY:S295,552 CUM:$902,587 ETD:S902,587 EFC:$1,101,000 The ebove ia correct . ~ , For form'"praparation end distribution see Procedural MI.'~ull Section 10, Drilling, Pagll 86 and 87 AR38-459-2-8 NumDer all dally well history forms consecutively as they are prepared for each well. · ARCO O-~T~and Gas Company '~, '~ Daily Well History-Final Report Instructions: Prepare and submit ~~.~.a~.~the first Wednesday after allowable has been assigned or welt is Plugged, Abandoned or Sold. "Final Report" should be subfaiHil~ .~/~ _~etatlOl~a are ~spended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion' re~ :~~' ~ntati~ test data in blocks provided. The "Final Report" form may be used for repoding the entire operation if space is available. ~ , [ACcounting cost center code ARCO A NORTH SLOPE District Field AS4 061 ~L ...... Unit WORKOVER ~ Well no. "~I- 9 Imitle API: 50-029-2022B Auth. or W.O. no. ARCO Opsrator ACCEPT Spudded or W.O. begun IA.R.Co. I Date NABORSI 2ES Date and depth Complete record for each day reported 21.7800 w.I. 01/08/91 Iotal number of wells (active or inactive) on this, dst center prior to plugging and I bandonment of this/~t~ft u~c, our ....... '~Prior status if a W.O. / as°f8:00a'm'01/25/91 ' 18) TD- 0 PB:10893 SUPV:HMP/FJB RIG RELEASED @ 20:00 HRs. MW: 8.4 Seawater LAND TBG. TEST SAME. INSTALL'BPV. C/O RAMS. N/D BOPE. TEST HGR. N/U TREE TEST SAME. PULL TEST PLUG. TEST TBG. INSTALL BPV. SECURE WELL. RIG RELEASED @ 20:00 HRS, ~ 1/24/91. CAMCO 'BAL-O' SSSV @ 2252', BAKER 'FB-i' 9-5/8" PERM PKR @ 9424', TT @ 9469'. CUM:$975,456 DAILY:S72,869 ETD:S975,456 EFC:$1,101,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method INew TD Date PB Depth IK nd of r g IType completion (single, dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CdR Gravity Allowable Effective date corrected The above is co~ect For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all dally well history forms consecutively as they. are prepared for each well. no. ARCO AI_ASKA, INC. !::'.0. BOX ~O(')Z~60 .......... ANC;H[)F;,'A[;Ei, AI...A,.~K A ~?'.".~; ~ '0 Fit E F:' E F:,' IE N CIE · A F: (] 0 C A S Ii"' D H 0 I.. El F: i N A I.. 5' F:' )} I,':.' .... i (:.." (').," [:' i F:' I::', C ()t:;: R,. ,S: .I. b 1'1 ~-'~ F:' D K .... i (') ~.~:'.,"' i) I F:'i::'~ C 0 F;..' i:;.'. ., .'.':..' 16 H A C B 't" C E. 'l" F' f::~ (:'; I< Ii:.: F;: S Iii: 'l" l" I N 6 I:(' Ii"' C 0 F: D F:' E Iq: F' F:' Ii:.: F;: F F:' Iii: F: F:' I:;..' Ii!: C 0 !:;.: D I::' Ii!: F,' F:' F;,' I:Z C [)F;,' D C I:.1 I... I... A C [! I._ I... A C: i".! I... C 0 L. I... f:".'~ C [J t... I... A F;.: :.'"' F-' Iii: I:;: F:' F:' 1... Iii: A S E :!;' ! C. N A N i) F:.: !ii: 'T' L! I:;: i",! 'i" H Iii: A 'i" '!"A [::: I"1 Iii: I) C 0 F:' ¥ !:;.' F:' [": F' 'j ~,,.' i~:: L:' i:': Y' . ....... ~._.~..,_,.:...... .'? l..i A F< 0 r'.~ t~..~ .I.I....::. U r..~ A :":.: I:;,' Ii!: [::: Iii: .[ F:' T' 0 F: D A'i"A, i;' I ,? i" I:',' J. t:: I..J'i']: 0 N :il: C Iii: N 'Y' F;: A I... I::' :1: I... Iii: 5' · ,,.'"' C: I..I Iii: V F;.: ~"i.. i',! i) & H .II: Iii; X 'i" Iii: i"-! .'."E..' i [) N Iii: X I::' I... 0 R' A 'i" I [) i".l :~ E X X ['t.. N .,. "~ t';i A F;: A T I.-I C! N :,",: I'i [) :(.? ]: I... 1::' I"11 L L. I F:' .:";' F:'B W I:.i. 1... i... i:;: & Bf:'X $"I'A'I' E UF l' E X A C. 0 I::' I I... t!i. S j~N 1 B 1991 Alaska Oil & ..r..~.S Cons. Goinmissioll STATE OF ALASKA ~ AL.A,~ OIL AND GAS CONSERVATION COMMISSION 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 X Variance _ Perforate _ Other Workover 2. Name of Operator ARCO Alaska, In~, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 20' FSL, 940' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 2205' FNL, 2197' FWL, Sec. 2, T11N, R14E, UM At effective depth 1997' FNL, 1946' FWL, Sec. 2, T11N, R14E, UM At total depth 1960' FNL, 1903' FWL, Sec. 2, T11N, R14E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 47' 7, Unit or Property name Prudhoe Bay Unit feet 8. Well number NGI-09 9. Permit number 76-68 10. APl number 50-029-20228 11. Field/Pool Prudhoe Bay Field Prud bge_.Ba_y ~iL ~o~o! 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Intermediate 10980' feet Plugs (measured) 861 5' feet Liner 10893' feet Junk (measured) 8 5 4 9' feet Length Size Cemented 76' 20" 240 sx AS cmt 2691' 13-3/8" 3150 sx PF II 9726' 9-5/8" 750 sx Class G & 275 sx PF 'C' 1 544' 7" 630 sx Class G K LEIVEI None DEC 2 o 1990 Fill @ 10819' ,.~ Cons. Measured depth True ve~ical depth 100' 100' 2715' 2715' 9750' 7685' 9431'-10975' 7480'-8573' Perforation depth: measured 10293'-1 0356', 10416'-10502', 10518'-10605', 10621 '-10656', 10662'-10712', 10726'-10736', 10754'-10805', 10810'-10835', 10851'-10861' true vertical 8105'-8151', 8195'-8258', 8270'-8334°, 8346'-8372', 8376'-8414', 8424'-8431', 8445'-8483', 8487'-8506', 8518'-8525' Tubing (size, grade, and measured depth 7" / 5-1/2" / 4-1/2" , L-80/L-80/N-80, tubing w/ tail @ 9344' Packers and SSSV (type and measured depth) Otis 'RB' sssv @ 2201', Baker 'SAB' pkr @ 9204' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch X_ 14. Estimated date for commencing operation Ja, nuary 1, 1991. 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas _ Suspended Service Gas Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ .~~UL~ Title Drilling Analyst ) FOR COMMISSION USE ONLY Conditions of approval' Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mechanical Integrity Test .~ Subsequent form require Approved by the order of the Commission --orm 10-403 Rev 06/15/88 OP, iGiNAL SIGNED E, LONNIE C. SMITH 10- /Jr <-~ ~ IIAppr°val No~) .~ ~.~,~ Commissioner Date / .~-.-/~---~'C~ SUBMIT IN TRIPLICATE Approvea Copy NGI 9 Workover Cost Est~ate Page 2 Pre-Riq Operations , Rig up a slickline unit. Test the lubricator to 5000 psi. RIH and pull the Otis SSSV at 2201'. RIH and set an X lock and a PN prong in the 4-1/2" X nipple at 9279'. Rig down the slickline unit. Rig up dill site maintenance to bleed down the gas pressure on the well. Bleed the surface down 500 psi. Monitor the well for 30 minutes to test the PXN plug. Rig up the a lubricator and test it to 5000 psi. Set a BPV in the tubing hanger. Bleed off the gas in the tree to test the BPV. Rig Operations , . . . o o . o MIRU. RU lubricator. Test the lubricator to 5000 psi. Pull BPV. Lubricate seawater into tubing. Bleed off gas. Confirm that the well is dead. Test the wireline plug to 4000 psi. Set BPV. ND tree. NU BOPE. Pull BPV and set test plug. Test BOPE. Pull test plug. RU landing joint. RU TIW valve on top of landing joint. Pull tubing hanger free. Circulate the well with seawater. Circulate well with 8.9 ppg NaCI brine. Spot HEC pill on top of packer. POOH and LD the tubing string. Have tubing inspected for corrosion and NORM. PU a 9-5/8" RTTS. Set the packer at 100'. Test the 9-5/8" casing and both stage collars to 4000 psi. Run enough ddll collars underthe RTTS to hold it down. If the casing leaks, test the backside to 4000 psi to confirm that the wellhead seals are good. Reposition the RTTS to locate the leak. a. The most likely place for the 9-5/8" to 13-3/8" leak is through the 9-5/8" wellhead packoff, This packoff has leaked before. In 1985 the wellhead was packed with epoxy resin and it cannot be tested to confirm that it is the leak source. b. If the 9-5/8" is leaking somewhere other than at the wellhead, contact the Anchorage office. Depending on the depth of the leak, either a cement squeeze or a cut and pull will be performed. Set a 9-5/8" RBP at 3000' and a 9-5/8" storm packer at 2100'. ND the BOPE and tubinghead. Change out the 9-5/8" packoff. NU the BOPE and tubinghead and retest the BOPE. Pull the storm packer and RBP. CBU after pulling each packer. Run the new string of 7" tubing. Space out tubing. Freeze protect the well. Land the tubing string. Test the tubing and casing to 4000 psi. a. Contact AOGCC 24 hours in advance to witness the MIT tests on the well. Fill out the required MIT forms and include them with your handover forms. NGI 9 Workover Cost Est~.~ate Page 3 9. Set the BPV. ND the BOPE. NU the tree and test it to 5000 psi. 10. Release the rig. Pull the BPV. Post Rig Operations 1. Rig up a slickline unit. Test the lubricator to 5000 psi. RIH and pull the plug in the 4-1/2" X nipple at 9279'. Rig down the slickline unit. David A. Crockett Senior Drilling Engineer 13-5/8" 5000 PSI BOP STACK ANNULAR PREVENTER 7 PIPE RAMS 6 BLIND RAMS 5 DRILLING SPOOL PIPE RAMS 3 TUBING HEAD 2 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 CAPACITY 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. BOP ,.,gTA(;;K 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 PSI 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/$9 BOP SCH (FOR: NAB 2ES) STATE OF ALASKA ALASK/ 'IL AND GAS CONSERVATION C 'MISSION REPORT SUNDRY WELL OP 'RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull ~ubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 20' N, 940' E of SW cr. Sec. 1, T11 N, R14E, UM At top of productive interval At effective depth At total depth 1960' S, 1903'E of NW cr, Sec. 2, T11N, R14E, UM X 6. Datum of elevation(DF or KB) 47 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-9 (22-2-11-14) 9. Permit number/approval number 76-68/90-301 10. APl number 50 - 029-20228 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10980 feet Plugs(measured) 8577 feet Effective depth: measured 10819 feet true vertical 8558 feet Fill (measured) 10819 Casing Length Size Cemented Measured depth True vertical depth Conductor 76' 20" 240 sx Arctic Set 100' 100' Sudace 2691' 13-3/8" 3150 sx Permafrost II 2715' 2715' Intermediate 9726' 9-5/8" 750 sx Class G 9750' 7685' Liner 1544' 7" 630 sx Class G 9431-10975' 7480-8573' Perforation depth: measured 10293-1 O356'; 10416-10433'; 10453-10467"; 10482-10502'; 10529-10552'; 10570-10605'; 10621-10646'; 10662-10700'; 10754-10779'; 10810-10835'; 10851-10861' true vertical 8067-8113'; 8157-8170'; 8184-8195'; 8206-8220'; 8240-8257'; 8270-8296'; 8308-8326'; 8338-8366'; 8407-8426'; 8436-8468'; 8480-8488' Tubing (size, grade, and measured depth) 7', 29#, L-80, ABM, 8rd @ 6863' 5-1/2", 17#, L-80, MOD 8rd @ 6863'-9205' 4-1/2", 12.6#, N-80, BTC @ 9205'-9341 Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure - - 206M .... 215M Reference Tubing Pressure 3900 3900 15. Attachments Copies of Logs and Surveys run . Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas Suspended Service Gas Injection 17. I hereb~if~the~,or~eg/oi~ is~rect to the best of my knowledge. Signed "~ (~'~-~. ~///L,/,~,~ Title Senior Area Engineer Form 1%L-~04 Rev 06/15/88 SUBMIT IN DUPLICATE NGI-9 Proposed Additional Perforations On July 2, 1990 the following perforations were added in Well NGI-9. Interval, MD (BHCS 10/11/76) Interval Length Formation Name SPF 10293-10356' 63' Sag River 4 ARCO AI_A,S'KA, INC,. F', 0,. BOX AN Cf-lO RA r; E: ALA D A T E · 7 -7 .- 9 ¢o i'-..! (..) I .... 2 ,4 .... 2 8 - 9,;3, C O t_ L A F.:,.."' F' E R I::' N (:; ]: - S 6 - 2 9 - 9 ,.'!) C 0 L L. A Fi: ,.--" F:' E R F:' i'.J. (; I -- 4 6 .... 2 '? - '-';' ('2, C ('J L. t_ A R /F'E R F' N [.i I .... 6 6 - .T.-'~ ,:?' - 9 (:.:, C: 0 I._ I_ A I:;.: /t::' E R F' N (.'; I -'~ 7 7 - 'i '- 9 (.:;' C 0 L. L A IR / F' E I;..' F N (~; I - iii ", ....... ~ - 9,:') C 0 I.. L A R,,' F'E R F'" N i.; I '- 'i;' ? "- 2 '- 9 '.':} C 0 L L A R /F:' E R I:: N (:.;- I .... i ,':.} '7 - 4 - 9 ,.'_::, C'.' 0 t. L. A F;.: /i-'-" E R t::' R U N 'i: 5" IRtJN 'i, .5" R UN 'i, 5." tRt. jNi., 5" RUN 'i ,5: ~ RUN i , 5' F;.'.UNi , 5;" i:;,IiNi , ~'- ~ RUN i , 5:" A;~~ RECFIF'i" 0i:' DA'i'A~ I-IA"..:E A NICE DAY! ,?ALI...'"r' I-tOFFECKER A "t- O - i 5 2 9 JUL 101990 _ ,, · :~-' ':;:F1VE'D ~ Alaska Oil & C as Cons. .:. ,L -.:: .. 't~chorag~ ~ N ~ r-~ :i' :.. v,~,. 2";" 2 D ! ,S' T R I B U T ]: 0 N · ',": (3 IE N T I;..' A I_ F I 1~ E ;S" ,,.~'. F:. .... I-I E V R O N .. [: .... I E N,.'.~ i 0 N E X P I.. 0 R A "f' I 0 N · ~ EXXON MARATHON · "' MOB 'r L ~ F'H]:LL I F'3.' F'B WELL F']:L.E:Z R & D .,Ii. · ,. BPX · "' ST~'I"E OF ALAZKA TEXACO STATE OF ALASKA ALASK )IL AND GAS CONSERVATION L......vlMISSION ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator' ARCO Alaska, Inc. Abandon d Alter casing Repair well Change approved program 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 20' N, 940' E of SW cr. Sec. 1, T11N, R14E, UM At top of productive interval At effective depth At total depth 1960' S, 1903' E of NW ct, Sec. 2, T11 N, R14E, UM Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development Exploratory Stratigraphic Service X Re-enter suspended well Time extension Stimulate Perforate x Other 6. Datum of elevation(DF or KB) 47 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-9 (22-2-11-14) 9. Permit number 76-68 10. APl number 50 - 029-20228 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10980 feet Plugs(measured) None :':ii~ ~_ ,~ ..... true vertical 8577 feet Effective depth: measured 10893 feet '" ¢'-~ .... ~ true vertical 8612 feet Junk(measured) None Casing Length Size Cemented Measured depth Tr~8~ depth Conductor 76' 20" 240 sx Arctic Set 100' 100' Sudace 2691' 13-3/8" 3150 sx Permafrost II 2715' 2715' Intermediate 9726' 9-5/8" 750 sx Class G 9750' 7685' Liner 1544' 7" 630 sx Class G 9431 '-10975' 7480'-8573' Perforation depth: measured 10416-10433'; 10453-10467'; 10482-10502'; 10529-10552'; 10570-10605'; 10621-10646'; 10662-10700'; 10754-10779'; 10810-10835'; 10851-10861' true vertical 8157-8170'; 8184-8195'; 8206-8220'; 8240-8257'; 8270-8296'; 8308-8326'; 8338-8366'; 8407-8426'; 8436-8468'; 8480-8488' Tubing (size, grade, and measured depth) 7", 29#, L-80, ABM, 8rd @ 6863' 5-1/2", 17#, L-80, MOD, 8rd @ 6863'-9205' 4-1/2", 12.6#, N-80, BTC @ 9205'-9341' Packers and SSSV (type and measured depth) 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 Name of approver Date approved Service gas injection I17. I hereby.,c~ertify that the fp~regoing is true and correct to the best of my knowledge. I // Signed ~:r(' ~¢,~~¢ ,,,~~ Title Operations Engineering Manager 15. Status of well classification as: Oil Gas Suspended FOR COMMI~RION IJSE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- 'Y~¥ Approved by order of the Commissioner Origlnal Signed B~: David W. Approval No. ff ~~/ Commissioner Date Form 10-403 Rev 06/15/88 Approved O,:.,.,y Returned SUBMIT IN TRIPLICATE NGI-9 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations in Well NGI-9. The proposed perforation intervals are as follows' Interval, MD Interval, MD Interval Formation (BHCS 10/11/76) (Tie-in) Length Name 10293-10356' 10294-10357' 63' Sag River 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 load fluid being displaced into the wellbore formation. No flaring is anticipated. 1. 5000 PS1 ?" WELLHEAD CONNECTOR FLANOE 2. 5000 PS1 WIRE:LINE RAMS (VARIABLE .3. 5000 PS1 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 H ! REL ! NE BOP EQU ! PMENT _ ARCO Alaska, Inc Prudhoe BaY Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 25, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: NGI-9, 13 & 14 Approval Nos. 7-477, 7-476 & 7-478 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations performed on the above-referenced wells. Very truly yours, D. F. Scheve DFS/PVL/jp At tachment cc: Standard Alaska Production Company Pi (NGI-9) W1-3 Pi (NGI-13)W1-3 P1 (NGI-14)W1-3 detailing work RECEIVED SEP 2 8 1987 Alaska 0tl & Gas Cons. Commission Anchorage WELLS / 117 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALA$~A OIL AND GAS CONSERVATION COM-.-~-tSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post 0ffice Box 100360, Anchorage, AK 99510 4. Location of well at surface 20'N, 940' E of SW cr, Sec. At top of productive interval 1, T11N, R14E, UM At effective depth Atlt¢~¢eCt, h 1903' E of NW cr, Sec. 2, T11N, R14E, UM 5. Datum elevation (DF or KB) RKB 47' 6. Unit or Property name Prudhoe Bay Unit 7. Well r~u~b_e~ (22-2-11-14) 8. Approval number 7-477 9. APl number 50-- 029-20228 10. Pool Sadlerochit Feet 11. Present well condition summary Total depth: measured true vertical 10980 feet Plugs (measured) 8577 feet Effective depth: measured 10893 feet Junk (measured) true vertical 8612 feet None None Casing Length Size Cemented Measured depth ~ue Vertical depth Conductor 76' 20" 240 sx Arctic Set 100' 100' Surface 2691' 13-3/8" 3150 sx Permafrost II 2715' 2715' Intermediate 9726' 9-5/8" 750 sx Class G 9750' 7685' 7480'-8573' Liner 1544' 7" 630 sx Class G 9431'-10975' Perforation depth: measured 10416-10433', 10453-10467', 10482-10502', 10529-10552', 10570-10, 10621-10646', 10662-10700', 10754-10779', 10810-10835', 10851-10861' true vertical 8157-8170', 8184-8195', 8206-8220', 8240-8257', 8270-8296', 8308-8326', 8338-8366', 8407-8426', 8436-8468', 8480-8488' Tubing (size, grade and measured depth) 7", 29#, L-80, ABM, 8rd @ 6863' 5~-" 17# L-80 MOD 8rd @ 6863'-9205' 2 , , , ~ Packers and SSSV (type and measured depth) 4½", 12.6#, N-80, BTC @ 9205' 9-5/8" Baker SAB Pkr O 9204'/otis RB ball valvP 0 ??~11' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure -I EiVED SEP 2 8 ].987 Alaska 0il & Gas Cons. Commission Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Gas-Mcf Bbl Casing Pressure 140 -- 182 14. Attachments Daily Report of Well Operations E~ COpies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Signed ~)~ ~~~ Title Operations Engineering Mana.qer Form 10-404 Rev. 12-1-85 NGI-9/STAT16 P. V. Lantero (263-4312) ;05' Injection Pressut'e 3900 3900 Date '~/g~'-'/~' ~ Submit in Duplicate DRILL SITE NGI-9 SELECTIVE STIMULATION On August 22, 1987, the following treatment was performed on NGI-9: 1. MI and RU pump truck and transports. 2. Rolled all acid compartments. 3. Pumped the following fluids: A. B. C. D. E. F. G. H. I. O. K. L. M. N. 2000 gals of xylene 2000 gals of 15% HC1 w/additives 4500 gals of 12% HC1-3% HF w/additives 4500 gals of 2% NH4Cl water w/additives 1300 gals of 2% NH,C1 water gelled to a viscosity of 100 cp w/CMHEC and 1300 lbs of benzoic acid flakes 2000 gals of 15% HC1 w/additives 4500 gals of 12% HCl-3% HF w/additives 4500 gals of 2% NHAC1 water w/additives 1300 gals of 2% NH',C1 water gelled to a viscosity of 100 cp w/CMHEC and 1300 lbs of benzoic acid flakes 3500 gals of 15% HC1 w/additives 7500 gals of 12% HC1-3% HF w/additives 7500 gals of 2% NHaCl water w/additives 2000 gals of 2% NH~C1 water gelled to a viscosity of 100 cp w/CMHEC and 2000 lbs of benzoic acid flakes 1000 gals of 15% HCl w/additives 2000 gals of 12% HC1-3% HF w/additives 2000 gals of 2% NH,C1 water w/additives 100 bbls of methanol 4. RD and released equipment and returned well to injection immediately. 5. Tested well for new injection rate. RECEIVED o 198 Alaska Oil & Gas Cons, Commission Anchorage 2 WELL S / 117 STATE OF ALASKA OIL AND GAS CONSERVATION COl~.~-ilSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging,[] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360~ Anchoraqe~ AK 99510 4. Location of well at surface 20'FSL & 940'FWL, Sec. 1, T11N, R14E, UM At top of productive interval 2205'FNL & 2197'FWL, Sec. 2, T11N, R14E, UM At effective depth 2064'FNL & 1979'FWL, Sec. 2, T11N, R14E, UM At total depth 1960'FNL & 1903 FWL, Sec. 2~ T11N~ R14E~ UM 11. Present well condition summary Total depth: measured 10980' feet true vertical 8577' feet 5. Datum elevation (DF or KB) RKB 47' 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-9 (22-2-11-14) 8. Approval number 9. APl number 50-- 029-20228 10. Pool Sadlerochit Plugs (measured) None Feet Effective depth: measured 10828 true vertical 8498 Casing Length Size Conductor 76' 20" Surface 2691' 13-3/8" Intermediate 9726' 9-5/8" feet Junk (measured) ].0828' feet Cemented Measured depth 240 SX Arctic Set 100' 3150 sx Permafrost II 27i5' 750 sx Class G 9750' - Fill True Vertical depth 100' 2715' 7685' Liner 1544' 7" 630 sx Class G 9431'-10975' 7480'-8573' Perforation depth: measured 10416-10502', 10518-10605', 10621-10656', 10662-10712', 10726-10736', 10754-10805', 10810-10835', 10851-10861' true vertical8195-8258', 8270-8334', 8346-8372', 8376-8414', 8424-8431', 8445-8483', 8487-8506', 8518-8525' Tubing (size, grade and measured depth) 7" 29# L-80 ABM 8rd @ 6863' 5~'' 17# L-80 MOD 8rd @ 6863'-9205' 2 , , , , Packers and SSSV (type and measured depth) 4½", 12.6#, N-80, BTC @ 9205'-9341' 9-5/8" Baker SAB Pkr @ 9204'/0tis RB ball valve @ 2201' · 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2/24/87 -- 111,639 .... Prior to well operation Subsequent to operation3/2/87 -- 148,508 .... Tubing Pressure 3679 3666 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Operations Engineering Manager Submit in Duplicate Form 10-4~4 Rev. 12-1-85 STAT17/NGI-9 M. R. Olson (265-6810) NGI-9 Daily Report of Well Operations Add Perfs 2/26/87 PT 4500 PSI. OK. Pump in Xylene/diesel wash. Pump in methanol/water (60/40). RIH w/CCL, GR, 3-3/8" dummy gun. Tag bottom @ 10828'. POH. PT to 4000 PSI. OK. RIH w/gun #1, 6', 3-3/8", 120° phasing. Shoot 10,799 to 10,805'. POH - all shots fired. PT. OK. RIH w/gun #2. Shoot 10779' to 10799'. POH - all shots fired. PT. OK. RIH w/gun #3. 2/27/87 Shoot 10726 - 10736', 10700 - 10712'. POH - all shots fired. PT. OK. RIH w/gun #4. Shoot 10646' to 10656', 10518' to 10529'. POH - all shots fired. PT to 4000 PSI. OK. RIH w/gun #5. Shoot 10552' to 10570'. POH - all shots fired. PT to 4000 PSI. OK. RIH w/gun #6. Shoot 10467' - 10482'. POH - all shots fired PT to 4000 PSI. OK. RIH w/gun #7. Shoot 10433; to 10453'. POH - no shots fired. PT to 4000 PSI. OK. RIH w/gun #7. Shoot 10433' to 10453'. POH - all shots fired. STATE OF ALASKA ALASKA-OIL AND GAS CONSERVATION C~:::)MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Gas Injection OIL [] GAS~ SUSPENDED [] ABANDONED [] SERVICE~ 2. Name of Operator/ 7. Permit Number ARCO Alaska, Inc. 76-68 ~ 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20228 4. Location of well at surface 9. Unit or Lease Name 20'FSL & 940 FWL, Sec. 1, TllN, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2205'FNL & 2197' FWL, Sec. 2, Ti]N, R14E, UM NGI-9 (22-2-11-14) At Total Depth 1 1. Field and Pool 1960'FNL & 1903'FWL, Sec. 2, TllN, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool /+7 ' R~ ADL 28302 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/24/76 10/12/76 10/23/76 N/A feet MSL Single 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10980'MD, 8615'TVD 10893'MD, 8549'TVD YES ~ NO []I 2201 feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/GR~ BHC/GR~ CFD/CNL/GR~ GR/VDC/CBL, GR/CNL/CCL, & Caliper 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 9M~ Vetco H-40 Surf 72' 32" 240 sx Arctic Set Cmt 13-3/8" 72# Butt MN-80 Surf 2715' 17~" 3150 sx PF II Cmt 9-5/8" 47# Butt MN-80 Surf 9750' 12¼" 750 sx Class G Cmt & SO0- 95 7" 295A MN-80 9431' 10975' 630 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10416-10502', 10518-10605 ' , 10621-10656' , 7" 9344' 9204' 10662-10712' , 10726-10736' , 10754-10805' , 10810-10835', 10851-10861'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 10/77 Gas Injection Well Date of Test Hours Tested iPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 03/02/1~7 24 TEST PERIOD I~ __ 1/+8,508 ...... Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co/r) Press. __ 24-HOUR RATE ~' -_ 148~508 .... 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Top Sadlerochit Base Sadlerochit 10406 ' 10948 ' 8188 ' 8591' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, In, Prudhoe Ba¥~ Engineering Post Office Box 100360 Anchorage~ Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 27, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: NGI-9 & 14 Permit Nos. 76-68 & 78-92 Dear Mr. Chatterton: Attached is the Application for Sundry performed on the above-referenced wells. Very truly yours, D. F. Scheve DFS/PVL/jp At t a chment cc: Standard Alaska Production Company P 1 (NGI-9) W1-3 P1 (NGI- 14)W1-3 Approval detailing work to be WELL S / 117 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 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 iq. Alter casing % Time extension ~ Change approved program [] Plugging [] Stimulate ~ Pull tubing ~ Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 20'N, g40' E of SW cr, Sec. At top of productive interval 1, T11N, R14E, UM At effective depth At total de_pth 1960' S, 1903' E of NW cr, Sec. 2, T11N, R14E, UM 5. Datum elevation (DF or KB) RKB 47' 6. Unit or Property name 'Prudhoe Bay Unit 7. Well number NGI-9 (22-2-11-14) 8. Permit number 76-68 9. APl number 5o-- 029-20228 10. Pool Sadlerochit feet 11. Present well condition summary Total depth: measured true vertical 10980 feet Plugs (measured) 8577 feet Effective depth: measured 10893 feet Junk (measured) true vertical 8612 feet None None Casing Length Size Cemented Measured depth True Vertical depth 6onductor 76' 20" 240 sx Arctic Set 100' 100' Surface 2691' 13-3/8" 3150 sx Permafrost II 2715' 2715' Intermediate 9726' 9-5/8" 750 sx Class G 9750' 7685' Liner 1544' 7" 630 sx Class G 9431'-10975' 7480'-8573' measured 10416-10433', 10453 10467', 10482-10502', 10529-10552', 10570-i0( ~)~Tti~t~6c~eb'P;th,: 10662-10700', 10754-10779', ;0810-10835', 10851-10861' 8157-8170', 8184-8195', 8206-8220', 8240-8257', 8270-8296' true vertical 8308-8326', 8338-8366', 8407-8426', 8436-8468', 8480-8488' 7", 29¢, L-80, ABM, 8rd @ 6863' Tubing (size, grade and measured depth) 5½", 17¢, L-80, MOD, 8rd @ 6863'-9205' z,, 12 6¢ N-80 BTC @ 9205' -9341' 2 , · , Packer~ and S.SSV (type and measured depth) -5/8" Baker SAB Pkr @ 9204'/0tis RB ball valve @ 2201' 12.Attachments Description summary of proposal [] Detailed operations progra~,,..~ B(;)P,Sket,c~h~.[] 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approv~-;¢;~; :~,!~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~--~. 2~ ~ ,~.~ S¢/-,,~,c, Title Operations Engineering Manager Commission Use Only Conditions of approval Date Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI ~ -- ....' by order of ~. ~1~ Commissioner the commission Date Form 10-403 Rev 124-85 Submit in triplicate DRILL SITE NGI-9 SELECTIVE STIMULATION PROCEDURE 1. MI and RU pump truck and transports. , . . Stimulate the well as follows: me Ce g. h. i. j · ne 2000 gals of xylene 2000 gals of 15% HC1 w/additives 4500 gals of 12% HCl-3% HF w/additives 4500 gals of 2% NHAC1 water w/additives 1300 gals of 2% NH]Cl water gelled to a viscosity of 100 cp w/CMHEC and 1300 lbs of benzoic acid flakes 2000 gals of 15% HC1 w/additives 4500 gals of 12% HCl-3% HF w/additives 4500 gals of 2% NHAC1 water w/additives 1300 gals of 2% NHlCl water gelled to a viscosity of 100 cp w/CMHEC and 1300 lbs of benzoic acid flakes 3500 gals of 15% HC1 w/additives 7500 gals of 12% HCl-3% HF w/additives 7500 gals of 2% NHAC1 water w/additives 2000 gals of 2% NH,C1 water gelled to a viscosity of 100 cp w/CMHEC and 2000 lbs of benzoic acid flakes 1000 gals of 15% HC1 w/additives 2000 gals of 12% HCl-3% HF w/additives 2000 gals of 2% NH,Cl water w/additives 100 bbls of methangl Volume of tubing/liner to top of perforations: Volume of tubing/liner to bottom of perforations: 351 bbls 368 bbls RD and release equipment and return well to injection immediately. Test well for new injection capacity. PVL/543 Aritho, rage, AI.a~ka 99S · "~ ~ 987 D A"I" E M ,.'.~ r c h ,... 4, C: a s' e d I..I o I. e F:' i n a I. [!:va L u.a t i on Run S, Run ~ , Run t , R u n I , R un i , 5:" 5" 5" 5" 5" S c h Dr e .'...: .'..~' Dr es' s' Dr e .'...~ .'..r Dr e .s' ~' A I:) I:.~ r' 0,7 e (:1 ................ i~I ........................................................................ D I ,~:': '1" R I B U 'F I 0 N o f d a i' a., STATE OF ALASKA ALAS,-,,~. OIL AND GAS CONSERVATION COMI~r,~SION 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 5. Datum elevation (DF or KB) ARCO Alaska: ];nc, RKB 47' feet 3. Address 6. Unit or Property name Post Office Box 100360~ Anchoraqe, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 7. Well number 20'N, 940' E of SW cr, Sec. 1, T11N, R14E, UM NGI-9 (22-2-11-14) At top of productive interval 8. Permit number 7¢; At effective depth 9. APl number 50-- 029-2022R At total depth ' iO. Pool 1960' Ss 1903' E of NW cr~ Sec. 2~ TZ1N~ R14E~ UM Sadlerochit 11. Present well condition summary None Total depth: measured 10980 feet Plugs (measured) true vertical 8577 feet Effective depth: measured 10893 feet Junk (measured) None true vertical 8612 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 76' 20" 240 sx Arctic Set 100' 100' Sur~r.~ 2691' 13-3/8" 3150 sx Permafrost II 2715' 2715' Intermediate 9726' 9-5/8" 750 sx Class G 9750' 7685' 7480'-8573' Liner ~ 1544' 7" 630 sx Class G 9431 '-10975' Perforation depth: measured 10416-10433' 10453-10467' 10482-10502' 10529-10552' 10570-10 ;05' 10621-10646' 10662-10700' 10754-10779' 10810-10835' 10851-10861' true vertical 8157-8170' 8184-8195' 8206-8220' 8240-8257' 8270-8296' 8308-8326' 8338-8366' 8407-8426' 8436-8468' 8480-8488' Tubing (size, grade and measured depth) 7", 29#, L-80, ABM, 8rd @ 6863' 5½" 17# L-80 HOD 8rd @ 6863'-9205' Packers and SSSV (type and measured depth) 4½", 12.6#, N-80, BTC @ 9205'-9341' 9-5/8" Baker $^B Pkr @ 9204'/0tis RB ball valve fa 12.Attachments Description summary of proposal J~ Detailed operations program [] BOP sketCh J~ . · · 13. Estimated date for commencing operation . . December 20, 1986 14. If proposal was verbally approved . : ?. - . : :: Name of approver Date approved 15. I hereb/y~ertify tha~,,~he f..oreg.qing is true and correct to the best of my knowledge Signed ~'~~~/~~ Title Operations Engineering Mana.qer Date /~/'~1"" Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ~/"~,~ [] Plug integrity [] BOP Test [] Location clearance, .... . :.:', /.~ ~....~.-~-?'-~¢P~' by order of Approved by Commissioner the commission Date/~2--¢3-~ Form 10-403 Rev 12-1-85 WJP(263-4511 ) Submit in triplicate NGI-9 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well NGI-9. The proposed perforation intervals are as follows- Existing Perforations 10416-10433 (17') 10453-10467 (14') 10482-10502 (20') 10529-10552 (23') 10570-10605 (35') 10621-10646 (25') 10662-10700 (38') 10754-10779 (25') 10810-10835 (25') 10851-10861 (10') ...Proposed Perforations 10433-10453 (20') 10467-10482 (15') 10518-10529 (11') 10552-10570 (18') 10646-10656 (10') 10700-10712 (12') 10726-10736 (10') 10779-10805 (26') 10835-10851 (16') Reference BHCS of 10/11/76 TOTAL = 232' TOTAL = 138' 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. The wells wil be loaded with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the formation. No flaring is anticipated. l 4 ! 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSi 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H I REL I NE BOP EQU I PMENT L ii iii i i~ i ii 51008~006 REV.I Atta n'dc~:-;~c;',; eldCor~;pany North American ~:'~o,_:ucll;B Alaska Regio Post Off:ice . 380 Anchorage, ~]~aska 99.510 Telephone 907 277 5637 September 15, 1978 Reference: Enclosed are copies of the following Cased Hole Logs: ~~D. S. ~7-2 ~D.S. ~5-2 Compensated Neutron 1 il/16 GR/N/CCL 2" & 5" 21! /NGI fi2 Engineered Producti~o,n Log 2" & 5" 6-3-78 (v'~v' C'~NG I fi2 Engineered Production ~og 2" & 5" 5-31-78 ~w~v-- Engineered Production Log 2" & 5" / Please sign and return attached copy of transmittal as receipt of data. Very truly yours, .. R. A. Logue North Alaska Operations Engineering Transmit tal /~461 AtlanticF;ichfie]dCom2any North A~,'n¢ Producing Division Alaska Regi'O~ Post O'lfica Box 360 Anchara§e, ,~.faska 99510 Telephone 907 277 5637 September 13, · Reference: 1978 Enclosed is a copy of Engineering Production Log, #NGI 9. · Please sign attached copy of transmittal as receipt~' of data. Very truly yours, R.A. Logue North Alaska Engineering Transmittal #456 AtlanticRichhetdCompany North American Producing Division North Alask ;strict Post Office b,"~-~x 360 Anchorage, Alaska 99510 Telephone 907 277 5,~37 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 Subject: NGI #2 Permit No. 75-52 NGI #4 Permit No. 75-69 ..... N,GI._.~.~7 Permit No. 76-38 Permit No. 76-68 "~~~ Permit No. 76-69 Dear Sir: Enclosed please find a Completion Report for the above'- mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB: ir Attachments SUBMIT IN DU'~'CATE* STATE OF ALASKA (See other st ructions on OIL AND GAS CONSERVATION COMMITTEE ~¢,,¢,,~e WELL COMPLETION OR RECOMPLETION REPORT AND LOG* I i iii i i ii · · lea. 'TYD]~ 0Y ,V~.LL: o1I, ~ GAS % El,I, W ELL DR ¥ Other b. TYPE OF' COMPLETION: \v~:~.L ~i ~,vmt rx BaCK BP, Syn. Other Parforate_d. _ 2. NAME OF OPERATOR Atlantic R±c..h£±e.!d Company 3. ADI)B. ES8 OF OPERATOR P 0 Box 360 Anchorage~ Alaska 99510 4, I,o('.,'rloN oF WELt, iRt'port location clearly and in accordance with any State requirements)* At surface 20~N & 940~E of SW cr Sec. 1, T1]N-R14E, UM At top prod. Interval reported below 2205~S & 2197~E of NW cr Sec. 2, TllN-R14E, UM At total depth 1960'S & 1903'E of NW cr Sec. 2~ TllN-R14E, UM 5. API NUSVLF,~CA~ CODE 5~-~2q-20228 6. LEASE D~IGNA~ON A_ND SER~L NO. ADL 28302 7. IF INDIA. N, ALLOTTEE OR TRIBE NA_M.E 8. UNIT,FAIt2VI OR LF.~kSE NAME Prudhoe Bay Unit 9. WEiLL NO. NGI No.9 (22-2-11-14) 10. FIELD A2'qP POOL, OR WII~DC.&T .Prudhoe Bay Field/Prudhoe 11. SEC., T., R., M., (BOTTOM ~o~1 Pool OBJECTIVE) Sec. 2, TllN, R14E, UM 12. PE'R~IIT NO. 76-68 1:~ D:'JfE 5t'U DD£D ]14'. i>ATE T.D, REACHED 115. DATE COMP SUSP OR ABAND. ]16. IgLEVATIONS <DP, RKB, P~T, GR, ~I'C>* 117. ELEV. CASINGItEAD ,,8-9/,-?~ I 10-1 2-7fi ! 1fl-23-76 ] 18' ~rave! pad 1~;. FO~'JL DI~wI'I{. MD & TVD~9. PLUG, BACK MD & ~D~. ~ ~ULT~LE CO~L., [ 2~ 'INTERVALS DRILLED BY [ [ ~OW ~Y* { ROTARY TOOLS V ---CAHI, E TOOLS 10980'~, 8615"TVD ]10893'~, 8549'TVD/ S~ngle I All [, :~. PRODUCING IN2~I<VAU(S), OF THIS COMP~TIO~TO,P, BOSOM, NA~IE (MD AND ~)* 123. XVAS D-REC~IONAL Top 8adlerochit 10,406'~ 8188'TVD Base Sadlerochit 10,948'~ 8591' TVD ~ Yes 24. 'I'Yf'E Ek,tq('TiI l(! AND oT}tF~. LOGS RUN DIL/GR, BHC/GR, CFD/CNL/GR, 20" ___1~-3/~" , 9-5/8"_ ,r [ 4#-veto° / H-4'0'[ 72' bei pa,~ ,,72#.Butt pm-80 [ 2715' ' 47# Butt IMN-80 /9750 [ - al,sQ,o,gsi , , 26 LIN Eli{ H.ECOHJ~ ~'Z['I } TOF' (2, ID} t i~.OTTOA'i (A'~D) IsA. cIc~S CEME~T* 7" [ %3~' ! '10'.975'1630, sx c~a I , t,' [, 28. PEHFO;{'A'~ ~'ONS OPeN TO P~ODUC~O~ (interval, size and number) 10,851'-10,861' ~ ~ ?10,810 ' -10,835 ' 10,754'-10,784' ' 10,664'-10,702' .10,622'-10,648' 30. OR/' VDC / CBL, - ' CASING RECO~D (Report all strings set in Well) HOLE SIZE 32" 17~" 12~", GR/CNL/CCL & Caliper ,,! CP-.\~[LNTING i%ECOFdD z'~,¢OUNT PULLED 2405x Arctic Set cmt 3150 sx PF II cmt .. 750 sx Class ,G cmt 27. TUBING REC O P~.D SCi-tEEN (5:D) SIZE DEPTH SZT (.ReD) ~ PACKER SET (~d[D) ~s G ,~ 7". 9344. ', [ 9204' 29. ACID, SHOT, IFiiACI UtlE, C~'4ENT SQUEEZE, ~TC. :10,572'-10,607' '~10,531'-10,554' ~10,483'-10,511' ~10,454'-10,468' w/4 shot ~10,417'-10,434' per ft. P~ODUCTION DF~'~Ttl 1NTF2~.V.q~L (MD) N/A ASiOUNF £~qD I~i!ND OF 5IATE?.iAL US'ED I)A'I'I.; F'II~ET ['I:ODUCI'iON I PIIODUCT1ON MEI[{OD (Flowh~g, gag lift, pumping--size and type of pump~ [%VELL ST'~TUS'(ProdUcing Pr -: L'~ ',i/' (5,'[~, } ~ ,%njectiqD ,,~ ..... I , . , ~ 0c~_1972 _[ .... 24 [ N/A [ ~' inject. ~res~ [2~-~ou~ ~z~ ] , , 4~00 n~J I . I -" ~ ,k 0 : -..MSCF/D I 0 I N/A 31. b~Posm'mx oF oas (Sold, u~ed IDr ]ueL vented, etc.) ...... -'~- TEST ~VITNESSED BY Reinjectgd t Production Operation 32. I.IST OF ATTACHMENTS I hereby certify that the foregoing and attached information is complete and correct as determined from 'all available records SIGN . ' J~/, TITLE nfstrict D~!ing Engineer DATE *(S,, [n~*ruaion~ ~nd S~cce~ [or Addifionc[ Oc~ on Rev,r~e Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well complet,on report and log on all types of lanJs and !eases 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 attach,','nents. Items 20, and 22:: If this well is completed for separatc prcduction from more than one interval zone (multiple completion), so state ,n item 20, and ir'~ item 22 show the p, cJucing 'i'~'terval, or intervals, top(,;), bottom(s) and name (s) (if any) for only the intervJ! reported ,r~ ,tern 30. Submit a separate report (page) on this form, adequately identified, for each adciitior~al in~'e~val to be seperately produceJ, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ 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. SUMMARY OF [~'()I{MA'I"i~)N 'rEs'~"s IN('L.UI)IN(; INTEI[VAL TF~S'FED. t~t{lg~SUIIE DATA AND I~I~COVERIE.S OF OILi GAS. 35. G I~OI_,OG I C MARK~ WATEll AND MUD NAMI~ , Top Sag River 10,291 8103' Top Shublik 10,358' 8152' Top Sadlerochit 10,406 ' 8188' Base I~adlerochit 10,948 ' 8591 ' . , , , i .i, [, ,, , ,,. . [ , ,, . . , , ,, i [[ [.in ,,, 3~. COF(E DATA, Aq'I'ACII B'R1E'¢ D~_~qCl~[lffI-q?ION$ OF LITI/OLOG¥, POI~OSITY, FRACTURES', APPA:I~NT AND D~ICECq.'E.I~) SII(..)WS OF (')IL, GA.S O'R WATEIi. North Alaska District Engineering T RAN S ld I T T A L 3. &:".'~Rocli6i~/{D'J 'R. Jacl<son Well Name' 'l'ran~;n'Li. tted ]~erewJ.th are the fo[LlowS.ng for the subject well' Run No. Scale ];!-lC Sonic/Caliper Log Bt-lC Sonic/Caliper - Gamma Ray Log Bt-lC Sonic/Gamma Ray' Log Caliper/CCL Cement Bond I.,og/VDL Compensated Fo'nnation DansS. ty I,og Comp en s at ed Neutron- Fo'nnat ion Dens ity Compensated Neutron Log - Core Analysis - Inte'~ral Core No, Core Description (SWg) -- Interval Core l~:~zcrS.ption (Cony.) - gore No. D:i.rectS.onal Survey - Single Shot Multishot DrS.]l Stem Test - Test Dual Induct:i. on La. terolog Formation Density Log Formation Density .Log/gamma Ray Gamma I~ay/CCL Latero]_og Loca'tion Plat Nic~olaterolog M:i. crolog Nud]_og--Inte~w'al Samp].e Log (A.R. CoT)-- Interval Synergetic Log TVD--I)IL 'I.'Vt)- Porosity Log ..... ] ...... T~!~)perature Record ~C~j_.ng Collar Log and Perforating .... Record 11 f~ece.'i.pl; Acknow].edged For: P].ea~.;e return roteS.pt to' At].antffc RS. chfield -' Company North A].a. slm EngJ_neeri:ng Nanager P. O. Box 360 Anchorage, Alaska 99510 Xerox Sepia BL Line ea. - :L ea. I ea. . / __ea- #531 AtlanticRichfieldCompany North Ame' q Producing Division North Alasks-~Oistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 1, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #9 (22-2-11-14) Permit No. 76-68 Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Form 10-403 Submit "1 ntentions" in Triplicate REV. 1-10-73 ....... & "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,L [---1 GAS El OTHER Gas Injection WELL! I WELL 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 20'N & 940'E of NW cr Sec. l, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 8' GR Level 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20228 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay 9. WELL NO. NGI 9 (22-2-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, TllN, R14E, UM 12. PERMIT NO. 76-68 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF g---J pULL OR ALTER CASING L__.a 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 AClDI71NG L.~ ABANDONMENT* (Other) Perforate (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 give pertinent dates, including estimated date of starting any proposed work. iBeig,,an, p..eir,,f 9iperations @ 2400 hrs 6/12/77. Tstd tree, csg, & wireline BOP's. Pulled dummy valve. Perf'd intervals 10,851' - 10,861', 10,810' - 10,835', 10,754' - 10,779', 10,680' - 10,700', 10,662' - 10,680', 10,621' - 10,641', 10,585' - 10,605', 10,570' - 10,585', 10,525' - 10,552', 10,482~' - 10,507', 10,45'2' - 10,466', 10,4i5' - 10,432' w/ 4 shots per foot. Ran Amerada press bombs. Flowed well. Ran & set bali valve. Tstd bal & cont 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 Department @ 0200 hrs 6/16/77. D!visJo~i (:~ (]ii ~:',,~j ('-;~.:~.:: ......... i/ti:);? 16. I hereby certify.that the foregoing is true and correct SIGNED '~/~ ,~[ ..... TITLE District Drilling Engineer DATE. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side 02-001B STATE Division of Oil and Gas Cons~-rvatio~ TO: ~-- FROM: O. K. Gilbreth, Jr. Director Hoyle ti. Hamil~ ~ff~ Chief Petrole~m~ Eng~~' _ Harold R. Hawkins DATE : July 7, 1977 SUBJECT: Witness ~%kLrfa~ Cantrol SubsxIrface Safety Valve and Surface Cantrol Safety Valve for ~zoo ~ $9 Wed~sday_,. June 15, 1977 - Paul Er~[ck, emg~ for Arco, picked ~ up at' bs-9 ar~ took n~ to NGI 1~. 9 where 1%~tnessed a ~ and a SCSSV v~lve. Tests started, at 1:30 PM. Tubing pressure was 2500 psi. Surface c~n~ subsurface safety valve was open. The surfac~ safety valve w~s ~ closed and pressure above the SSV was bled to zero and b~ld OK. I observed this for 20 minutes. ~he surf~ ocmtrol subsurface safety %~lve was then closed and pres~e was bled do~n above SCSSV to 1000 psi. I cbserv~ this pressure for 30 mintfces. ~nere was no buil~ cf pressure, indicating In ~: I vn[tnessed the surfaoe safety valve and surf~ c~ntrol ~subsurface safety vmlve c~ ~-K"'-,..I S9 for ~rco. _~ests ~,~L~'e satisfactory. Attachment :'~ ~7 '~ ~,~f ,~ ' '..' '- ..~ ;'-~,w~?. ~.:--::.E '~,~.~-~: ~%, 3~~. . .~ - · " ~( . , . Ali }.Oil and '""~'~"~",,. ~'~" ' ' Field T - +~ ~nsvec~,on '""}~O'O~r~}~F~"~:' = : '."' '~:~:': Represented -:....' .'- '-:' . . - · Satisfactory . Type Inspection ' · Yes' No Item (~) Location,General () () () () () () () () () ~ .() () () () () () () () () 1. Well .Sign 2. General Housekeeping 3. Reserve Pit-( )open( Jfilled 4. Rig ~') Safety, Valve Tests 5. S~rface-N6. Wells ~ 6 Subsurface-No. Wells~ ( ) Well Test Data 7. Well'Nos. , , 8. Hrs. obser , , 9. BS&W , , , 10. Gr. Bbls. Satisfactory Ty~6~ Inspection Yes No Item ( )~'~i'BOPE TeSts ( ) ( ) 1'5. ~"Casing set @ ( ) ( ) 16.' Test' fluid-( )wtr.-E~-~. )mud ( ) oil ( ) ( ) 17. Master Hyd. Control Sys.- psig ( ) ( ) 18 N?'~btls:' , , ' , psig ( ) ' ( ) 19 R~mote Contro~' ( ) ()~ ~,0. Drilling spool- "outl~s (.) ( ) t-~l Kill Line-(~--) Check valve ( ) ( ) 22. Choke F10wline ( ) HCR valve ( ) ( ) 23. Choke Manifold No. valvs flas ( ) ( ) 24. Chokes-( )Remote( )Pos.(~dj. ( ) ( ) 25. Test Plug-.( )Wellhd( )csg( )none () () , , , 26. Annular Preventer, __~_sia () Final Abandonment -- ( ) ( ) 27.~,..'~. ams, ~..~'3~~B~.~'r ( ) ( ) '"~1. P&A Marker ( ) ( ) 28./ P~'~rams - pslg' " ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psig ( ) ( ) 14. Pad' leveled ~-~ ( ) ( ) 31. Safety Floor valves-( )BV ( )Dart Total inspect~o.n~t~rvation time/~2..(hr_~days Total number leaks and/or equip, failures~_~ Remarks . ,_.~/~:.. '.5: :',."., ;:.-~" ?-~.'~.-r- ..2~v/-'/~ ,:.. :;s~. 5,'~ f ~;~?,." 2~_.l ? · ~r//'~F_~r~' .~?.~?? .,,'-':~: ~'- eib,'.~' -i; ? -:'- . cc. Z~? . _~/~:4/~, Notify' in daY-s-or-when -ready ~ '-I~peEe~d by~._~__~'_~..!~$ Oate~r,,~_/~Z~ Atlar,;~J~cRichfieldCompany North Amer"' ~n Producing Division North Alas )istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March ll, 1977 Mr. Hoyl e Hami 1 ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS NGI 9 (22-2-11-14) Permit No. 76-68 Dear Sir: Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /jw Enclosure STATE OP'~,LASKA OIL AND GAS CONSL~. ATION 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.) 1. Oil r--1 GAS g~] WELLL--J WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At,,r~,¢e 20'N & 940'E of NW cr Sec. l, Tl lN, R14E, UM 13. ELEVATIONS (Show whether DF, PT, GR, etc.) 8' GR Level 14. Check Appropriate Box To Indicate Nature of Notice, Re NUMERICAL CODE .._.0-029-20228 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT, FARM OR LEASE NAME Prudhoe Bay · _ 9. WELL NO. Drill Site NGI 9 (22-2-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadl erochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE} Sec. 2, TllN, R14E, DM 32. PERMIT NO. 76-68 }oft, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF E~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate 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..) ]5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent detalts, 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. Well will be flowed to a flare pit and all hydrocarbons will be flared. 0nly enough gas will be flared to clean the completion fluid out of the tubing. The down hole safety valve will be installed and tested upon conclusion of job. Bottom hole will be measured with pressure bomb run on wire line.~*~ ~.~l~ {i ~_.F~\~i ~- ~ D Estimated Start Date' March 14, 1977 hereby certify that the foregoln9 Is true and correct T,TLEDistrict Drilling E.ngineer (This space for State office use) COt4DI'T IONS OF APPROVAL, IF ANY:/ .. TITLE See InstrUctions On Reverse Side To' CONFIDENTIAL DISTRIItUTED TO; STATE OF AL.ARtC4. DIVISION OF OIL, Ik GA,q ARI~qTIC RICHFIELD North Alaska District En~in~erin~ TRAN SMI TTAL DIVISION OF: OIL AND GAS From: J.A. Rochon/p. Hellstrom Date: Dec. 14, 1976 Well N~,.e: NGI # 9 Transmitted here~ith 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 G~.~na Ray/CCL Laterolog · Location Plat ~[icrolaterolog ~[icrolog ~h~dlog- Interval Sample Log (A.R.Co~,)-Interval) Synerge tic Log %(D-DIL TVD-P,orosity Log · Sepia BL Line ~ ecq., / ea, Receipt Acknowledged For: Date: Please return receipt to: By: Atlantic Richfield Co,,~p~mny North Alaska Engineering Manager P. O. Box 360 Anchorage, Alaska 99510 # 95 Atlant[cRichfieldCompany North Ame~'i~ -'~ Prods]ting Division North A~ask~ ,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 2, 1976 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 RE' NGI #9 (22-2-11-14) Permit No. 76-68 Dear Sir' Enclosed are the Well Completion Reports along with the Well History and Directional Survey for the above mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer CRK/jw Enclosures SUBMIT IN DUI~LiCAIYE* STATE OF ALASKA ',So~,.,ther m- st ructions on OIL AND GAS CONSERVATION COMMITTEE r~,,e,'~ s~; ii ii i i i i i ' i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ..... o,,. ,Q ,,-~:,.,. ,,.~:~.~.UJ ~,~¥ Other Gas Injection b. TYPE OF COMPLETION: x \VEl. I. f)\' ER ~ EX ~ BACK RESVR. ()thor __ 2. NAME OF OPIERATOR Atlantic Richfield Company ,'~. ADDRESR OF OPERATOR . ~P.. O. Box 360. Anchoraoo. Ala.qka qClElrl 4. Loc,,'rmx uv w}:LL [Report tocatio~cldarly and in accordance With amy State requirements)* At surface 20'N i 940'E of SW cc Sec 1, TllN, RI4E, OM At top prod. interval reported below 2205'S i 2197'E of NW cc Sec 2, TllN, RI4E, UM At total depth 1960'S & 1903'E of N~ cr Sec 2, TllN, R14E, UM 1:;. D.&'i'E SPUDDED ~14. DA'£E T.D. RF~CHIgD ~i5. DATE COMP S.USP OR ABA,ND. 8/24/76 I 10/12/76 ] 10/23/76 10980'MD,8615'TV[~lO893'MD, 8549'TVD / a°~ingle 22. PRODUCING !NTEHVAL(S~, OF THIS COMPLETIO.N--TO,P, BOTTOM, N'AME (MD AND TV'D)- Top Sadl erochit 10,406'MD 8188'TVD Bottom Sadlerochit 10,948' ~B 8591 'TVD 5. AP1 N~CAL CODE 50-020-2022~ ... 6. LEASE DESIGNATION A_ND SERIAL NO. ~ ADL 28302 7, IF INDIA_N, ALLOTTEE OR TRIBE; NA1VIE 8. UNIT,FA2X1VI OR LF~ISE NAME Prudhoe Bay 9. '~Vl~iLL NO. 'NGI No. 9 -'(22-2-11-14) -t0.~IEL,D A2qD POOL, OR WILDC&T Prudhoe Bay - Sadlerochit SEC., T., R., M., (BOTTOM HOLE D00 I OBJECTIVE) Sec 2, TllN, R14E, UM 12. PL'I~IIT NO. 76-68 i16. F_M_,EVATIONS (DF, RKB, I~T, GR, ~.1~_~.117. ELEV. CASINGttEAD 18' Gravel Pad ,~.g .,~,.~ ,~,:- , CABL~ TOOLS 23. WAS D~RECTIONAL SU~VEY ~ADE Yes 24. ','YPE EiL,Iq('TiIIC AND (JTIIER LOGS RUN DIL/GR, BHC/GR, CFD/CNL/GR, fiR/VDC/CBL, GR/CNL/CCL & Caliper , i , , ,, ii -- il 25. CASING RECORD (Report all strings set in well) C~SI~q (_; SiZE 20" 13-3/8" 9-5/8" 11, NA 11 I I IIII I I I i)A'fE I;'11~:; i' ['I~t~DLICTION [ ~A ,,, [o[94# - Vetc H-40 [ 72' 32" ! 240 sx Arctic Sot cmt [72# - Vetco[ MN-80[ 2715' 17a" 13~50 ~× PF 11 cmt .. [47# ' Butt I MN-80I 9750' 12~" ! 7.q0 s× C!aqs c, cmt ' [ S00-9t ........... 1 LIN?iX H.ECO~ . [ 27. ~UBING 9431' [. 10.975'1 630 SX C]?s a ........ 7" .q24a' "' j -----9204' OPeN TO PRODUC~ON (intcrval size and number) 29. 'AC~D, Si!OT, ~'ilAT2 URE, C~IENT SQULVZE ~TC. NA i i u i i PRODUCTION PIIODUCT1ON MEI[iOD (FloP;ii, g, ga3 lif~, pamping--size and type of pump) ELL STATUS (Producing or g~!clt-in) ., I}ATE OF TIEST. tt~:URS q ESTF--D ICI1OKE SiZE tPP-OD'N FOR 21. DISPO.qI'rlON OF (;AS ISold, used for ]uel, vented, etc.) OII-~--BL~L. 1 32.lAST OF ATTACHMENT~q PULLED Dr.illina History and M~ltishot :'dL I h°r°b;'-cer tiff'SICNt': , ........ ,hatu~-t h:~_r~ :Tn.~attached haformationTITL.is complete~~~~a,, correct .S determined fro. , , 11 11 II I I I *(See Instructions and Spaces [or Additional Data on Reverse Side) ~/~'i G;kS--RECF. WATER--BBL. i WAT'ER--B BL lOlL GRAVITY,A_PI t TEST WITNESSED BY !~.. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showrfl for depth measure- ments given in ether spaces on this form and in any attachments. Items :20, and :22:: If this well is completed for separate, prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc. Jucir~.g 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. It6m26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing anct 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. SUMMAItY OF F'OIt. MATION TES'I','~ IN('I, IJI)IN(; INTEIIVAL T~STED. ['I~E~URE DATA ~ ~OV~I~ OF 0I~'. GAS. 35. G~GIC MARK~ WAT~ AND MUD NA~ [ i Top Sag RSver 10,291' 8103' lop Shubl~k 1¢,358' 8152' ~ · loP Sadleroch~t 10,406' 8188' Bo~om Sadl eroch~t 10,948' 8591" a~. COnE DATA, Aq~'ACll ~I~ ANO ~'~Cq~t) SHOWS O~ (~lh. GAS OR WAdi. I II II ' Il I' ' II ' I '-' IIlllll ~ .................. i'll .... . .. , . ORILLING HISTORY NGI # 9 (22-2-11-14) API# 50-029-20228, ADL 28302, Permit No. 76-68 Spudded 17½" hole @ 2100 hrs 8-24-76. Drld to 2733'. Ran 13-3/8" 72# MN- 80 butt csg w/shoe @ 2715', FC @ 2641'. Cmtd 13-3/8" csg w/3150 sx PF II cmt. Installed & tstd pk-off 2000 psi OK. RIH w/12¼" bit. Drld FC, cmt & shoe @ 2715' & new form to 2743'. Pess tstd form to 11.5 ppg equiv. Drld to 4881'. Cond hole for tri~p RIH & drld 12¼" hole to 9820' Cond hole for csg. Chgd & press tstd='5/8" rams. Ran 171 jts 9-5/8" ~7# MN-80 butt csg and 65 jts 9-5/8" 47# S00-95 butt csg w/shoe @ 9750', FC @ 9663', lower FO @ 2460', upper FO @ 2334' Cmtd w/750 sx Class "G" cmt w/l% CFR-2 slurry 15.8 ppg. Displ cmt ~/707 bbls mud. ND BOPE. Installed emergency slips & dummy pkoff. Press tstd BOPE & csg pkoff to 5000 psi. PU RTTS tool & shifting tools. Cmtd down thru lower FO w/275 sx of PF "C". Closed FO. Tstd FO w/3000 psi OK. Opened upper FO & rev out. No cmt. Did Arctic Pack job thru upper FO w/O% wtr @ end of job. Closed upper FO & tstd to 3000 psi OK. RIH to top of cmt 9311'. Drld cmt from 9311' - 9663'. Tstd csg to 3000 psi OK. Drld FC & cmt to 9741'. Cond mud. Tstd csg to 3000 psi OK. Drld cmt & shoe plus 5' of open hole. Tstd form to 11.9 ppg equiv OK. POH & PU 8½" BHA. Reamed BHA thru cmt sheaths. Drld from 9825' - 10520'. Pipe started torquing up. Drld w/high torque to 10,552'. Stuck @ 0530 hrs 9-14-76. Work stuck pipe & spotted 50 bbls of 10.9 ppg SFT spotting fluid. Covered BHA w/spotting fluid leaving 45 bbls in DP. Move fluid 2 bbls per hr. Jarred on stuck pipe while moving SFT spotting fluid 2 BPH. Displ spotting fluid & cond hole. Ran freepoint indicator showing pipe free up to 10,415'. Showing pipe 100% free 10,415' & stuck @ 10,435'. Freepoint moved up hole during 3½ hrs while looking for freepoint. Circ & cond hole & ran back off shot. Backed off over crossover sub @ 10,410'. RD wireline, POH. PU fishing string and ran into 9-5/8" shoe. Slipped & cut drlg line. Picked up 69 jts of Grade "G" drill pipe and circ bottoms up above fish. Lapsed time back-off was 13 hrs. Found additional bad spot in drlg line. Pulled back to 9-5/8" shoe & cut off more line. Ran back to fish and screwed in. Circ OK. Jarred on fish and prep 75 bbl of SFT spotting fluid. Fluid in place w/35 bbl around fish. Moving fluid 2 bbl/hr. 12 hrs jarring on fish & moving spotting fluid. Fish plugged off @ 1830 hrs 9-17-76. Jarred on fish. Attempted to unplug fish. Ran freepoint indicator, could not get down. Reran tools to 10,425', freepoint @ 10,415'. Backed off fishing string @ 10,152' while working down lefthand torque. Screwed back in. Made second attempt & dialog tools failed. Reran dialog & string backed off @ 10,242'. Trip in w/screw sub & screwed into top of fishing string. Ran freepoint indicator, worked down to 10,379'. Tools quit, POH leaving 53' dialog fish in collars. Trip in w/wireline fishing tools, could not get down. Top of wireline fish @ 10,326'. Trip in for backoff @ 10302'. String backed off @ 10,241'. while putting lefthand torque into string. Could not screw back in. Circ & cond. Chained out of hole. Left screw in sub in top of fishing string. RIH to shoe of csg. Slip & cut drlg line. Screwed into fish @ 10,241'. Ran dialog tools & worked down to btm of 1st DC. Tools stopped in gelled mud. Backed off collar & circ btms up from 10,272'. Circ & cond hole. POH & rec screw in sub in 30' DC. Made up bit 2 stabilizers, 2 DC'.s &'made cord run to top of fish. Washed & reamed from 9890 - 10,272'. Hole tight and sticky. Hole above bit in good cord Circ & cord hole. RIH. Left drl pipe rubbers in hole. TIH w/WP to catch rubbers. Could not wash over fish @ 10,272'. Circ & cord hole. Trip out. TIH screw-in sub. Screwed into fish @ 10 272'. Pulled goose neck & rotary hose. Ran Dialog & check top of fish @ 1'0,241'. DP single looking up. POH. LD fishing asbly & PU 8½" washover shoe on 1 jt of WP. Worked over top of fish & swallowed single. Landed DP in tbg head. Chgd out rams to 2-3/8". Ran 1-3/4" DC on 2-3/8"butt. Washed from 10,280 - 10,378'. Found Dialog fish. POH & rec 47' of WL fish. Left btm 6' of Dialog tool w/top @ 10,425'. PU mule shoe & reran wash out string to 10,240'. CO, circ inside of fish clean. LD 2- 3/8" tbg. Landed 1 jt of DP. Set safety valve in tbg hgr & chgd rams to 5" RIH_w/2" OD perf gun. Stopp,ed @ 10,392'. Trip out. PU 35' of 1- 11~16" sinker bar'. RIH t~ 10,413 . POH. PU kelly. Screwed into top of tbg hgr. PU & circ. POH. LD WP. PU safety jt. RIH & screwed into top of fish @ 10,242'. TIH w/sinker bar to 10,412'. Trip out. PU live gun. TIH to 10,383'/ 10,393'. Press to 1000 psi. Fired gun. Press to 3500 psi. No penetration _J~r~_.~p~erforate. Made up & ran 2' of Dialog perforating gun. RI~ & shot I__~],.~3.~Q~-_~].~_~Q~L. Checked for penetration w/5000 psi. No circulation. RU & ran freepoint indicating collar free to 10,332'. Attempted backoff w/shot @ 10,332'. Backed off of safety joint. Screwed back in and attempted backoff @ 10,302'. Backed off again @ safety joint. Screwed back in & attempted backoff @ 10,302'. PU 10,000# of string wt indicating backoff of one DC below top of fish. Circ btms up. POH. Rec safety joint & one DC. Top of fish @ 10,302'. RIH w/450' of 3½" DP stinger & 5" DP to 10 302'. Pumped 25 bbls flush ahead of 150 sx Class G cmt mixed w/l% CFR-2 ~ 0.2% HR-7, slurry 16 ppg. Displ cmt plug w/35 bbls wtr @ 171 bbls mud. POH. PU BHA. RIH. LD DP. Tag cmt @ 9973'. Circ & worked DP back into 9-5/8" shoe @ 9750'. Reamed & washed 9750'-9947'. Drld to 9997'. Hole tight on btm. Trip into csg. Chgd over from water base mud to Oil Faze. Reamed & washed from csg shoe @ 9750' - 9995'. Hole sloughing. Cont circ & cord mud. Reamed & washed to 9997'. Drld hard cmt 9997' - 10,017'. Worked tight hole & cord mud. Circ hole clean. POH. Chgd BHA. Ran into 9-5/8" csg shoe @ 9750'. Washed & reamed to btm (10,017'). Circ & cord hole. PU Dyna drill. RIH to 9750' Start shoulder 10,017' - 10,032'. Dyna drill to 10,070'. Reorient & Dy~a-drill to 10,106'. Survey & pulled to 9750'. Chgd BHA. RIH & drld to 10,935'. Losing small amount of mud. Mixed LCM in mud system. Cord mud. Ran DIL log 10,935'/9750'. RIH w/8½" bit & drld to 10,980'. Circ & cord hole. Made wiper trip to 9- 5/8" shoe. Ran DIL/GR, BHC/GR, CFD/CNL/GR & Caliper logs. RIH to 9-5/8" csg shoe. Break circ. RIH to TD. Circ & cord hole. POH to 9-5/8" shoe. CO pits. Mixed & filled pits w/lO.9 ppg wtr base mud. Pumped 400 bbls of water base mud down DP. Vacuum trucks could not keep up while displ. Pulled up to 9-5/8" csg shoe to fill pits. Fin displ Oil Base mud w/water base mud. POH w/open ended DP. RIH w/8½" bit to TD (10,980'). No hole problems. Circ & cord mud. Chgd & press tstd 7" pipe rams. Ran 37 jts of 7" 29# MN-80 butt lnr w/shoe @ 10,975', lnr top @ 9431'. 'Cmtd lnr w/630 sx Class G cmt mixed w/l% CFR-2 and 01-15% HR-7. Preceded slurry w/40 bbls of water. Displ w/228 bbls of mud. Bump plug w/2000 psi. RIH w/8½" bit & 9- 5/8" csg scraper. Drld hard cmt 9220' - 9431'. Trip, RIH w/6" bit & CO to 10,893'. Circ hole clean. Press tstd csg to 3000 psi OK. POH. PU WSO tools. RIH. Set pkr @ 9372'. Opened tools for 3 hr test w/very lite blow 45 mir, dead balance of test. Closed for 1 hr shutin & POH. Charts indi~cated tst OK. Trip in w/6" BHA & cord hole to 10,893'. POH. Ran GR/VDC/.CBL : logs. Cleaned pits & chge over to CaC12 wtr. LD 5" DP Press tstd above FOs to 3000 psi OK. Set BP @ 105'. ND BOP stack. Installed & tstd 9-5/8" modified Gray csg pkoff to 5000 psi OK. Retrieved BP. Ran 9-5/8" gauge ring & junk bskt to top of 7" lnr @ 9431'. Ran 7" tbg w/ shear sub @ 9344' "X" nipple @ 9278', Baker SAB pkr @ 9204', PBR @ 9160', "XN" nipple @ 915~' "XA" sliding sleeve @ 9117' ball valve nipple @ 2201' Landed & tstd tbg pkr to 5000 psi. ND BOPE. NU & tstd xmas tree to 5000 psi. Pulled dummy valve. Set pkr, sheared sleeve @ 2800 psi. Press tstd w/200 psi on tbg & 2000 psi on anul. Then press tstd w/200 psi on anul & 3000 psi on tbg OK. Opened XA sliding sleeve & displ diesel w/338 bbls CaC1 wtr. Closed & press tstd sliding sleeve to 3000 psi. Ran GR/CNL/CCL l§gs & dummy gun which stopped @ top of lnr. Worked foreign object thru lnr top to 10,883'. Reran dummy gun OK. Installed xmas tree & started 48 hr tbg press tst. Released rig @ 0900 hrs 10-23-76. ATLANT ! C NGI-9 PRUDHOE ALASKA ) RICHFIEL~ COMPANY ~AY SPERRy, SUN WELL St, ~YING COMPANY ANCHORAGE~ ALASKA COMPUTATION DATE ........... ~-~;~ .... MUL~I~Q.~.].SURVEY OCTOBER 26, 1976 OOB NU~Em KELLY BUSHING ELEV, : 47,00 FT, . EASTMAN/WHIPSTOCK SURVEY ........................ ~EASURED DEPTH' TRUE SUB-SEA COURSE COURSE DOG-LEG VERTICAL VERTICAL INCLINATION DIRECTION SEVERITy DEPTH ........ DEPTH DEB MIN .... D~GREES DEG/~O0 0 27o0 2790 2885 2976 3O70 3352 3539 ~729 0,00 -qT,O0 0 0 N 88, 0 W 2699.99 2652.99 0 I N 88, 0 W 2789.98 27~2.98 1 15 N 88, 0 W 2882.92 28~5,92 2 ~5 N 69, 0 W '2975,71 ............ 2928.71 % 40 N 67, 0 W 5069.20 5022,20 7 15 N 62, 0 W ~162.50 5115.~0 8 50 N 59, 0 W 5~55,07 ........ 5206,07 ......... 10 .... 0~' N 58, 0 W ~ ~3~7.33 5300.33 12 0 N 56, 0 W 3~37.9~ 3390.9~ 14 0 N 54. 0 W ................................... 5528,60 ............. 3461.60 16 30 N 5~, 0 ~ 5618.95 5571.95 19 30 N 52, 0 W 5707,55 5660,55 22 ~5 N 51, 0 W 5821 1791,66 ............. 57-~,66 ................ 25 ...... 0 : ..... Fi~'"51' O"w ...... 3c1~- 3875.60 362'~.,.60 26 0 N 52, '0 W qlO1 %195 5S35 5128 5 22 2 3959.72 39!2.72 27 0 N 51,50 W ~0~2,21 ....... ~995.21 ..............28 ........ 0 '/ N 50, 0 W 412~.28 4076.28 32 45 N ~9. 0 W 4200.44 . q153,4~ 35 5 N ~9, 0 W q275.19 4228.19 37 55 N 49, 0 W ~$46.78 ~2~9.78 ~9 55 N 52. 0 W ~17,9~ ~$70,95 ~0 15 N 52, 0 W ff557.49 ~510,q-9 ~4 0 ~ 51,50 W q62~,10 q577.~0 ~5 ~5 N 51. 0 W _ ~690,70 q-~>3,70 ~q 0 N 53.50 ~ ~759.2g q7!2o2~ ~1 0 h! 5~. 0 W 4827.87 q. 750,~7 43 55 N 5G,"0 W . ~..89~.09 t~t:-Y,O9 ~ 30 N 56, 0 W Ng$5.q~..... u,~,~:5,39. ., 51 0 N 55. 0 W. 501q-.25 q. 5:5'7.23 51 30 r,j 5~.50 W 0.00 0,00 1,57 1.7% 2.06 2.80 1.59 1.gO 2.16 2,20 2,65 ~.12 2,~ 1.17 1.0~ 1,50 5,08 2,50 3,0~ 2.98 0,35 1,96 2.18 1.89 2.64 3.q5 2,74 4.90 0,67 TOTAL RECTAF.:GULAR COOFDINATES ......... ~.ERTIcAL NORTH/SOUTH EAST/WEST SECTION 9,00 W~ 788 50 <940.00 <..19 ...... ............ · ~'0-~-0'~'"'~': 199.39 W 788,79 9~0,04 9%0.88 9~3.16 967.q~ 953.80 961,70 971.~9 985,51 998,0~ 1015.7~ 1037.06 1060.%9 1085.~1 1111.~8 1158.55 1169.~3 1205,~7 12S9,76 1276.~8 1313,35 1352,25 1391,9q 1~33.~5 1.~7q,05 1511.21 15q7,!8 158q,q8 162g.09 200.~8-W 789.5~ 20S.~8 W 792.S7 209.04"~ ......... ..-?97.99 217.80 ~ 887.~0 228.99 ~ 819.82 2ql.87 W ............ T'-'1'83~®61 256.89 W : 852.26 27~.01W ":"872.97 29~,01'-W ...................... 897.~9 317,42 W 926,68 5q~,20 W 960,79 '575,13"W .......... ~17o~0 ~ 107~,6t w 1122. 506,76 W 1169,91 5 5.91 w a2 .75 .567,66 W X277,05 g~2.26 W 155~.E8 679.q5 W 1~9~.~2 · 728.~5 W 1~56,58 777,79 ~ 1519.60 829.51_W 1585.92 88,1.92 W 1651,92 932.58 W 171q.28 984,01 W 1776.40 10~9.~1 W 1842.2~ 1096.90 W 1911.35 1155.77 W 198~.9J } SPERRY-SUN WELL ANCHORAGE, ALASKA ATLANTIC RICHFIELD COMPANY NGI-9 CO~iPUTATION DATE.._ PRUDHOE BAY OCTOBER 28, 1976 ALASKA )RVEYING CCMpANY ).PAGE 2 ._DATE OF SURVEY OCTOBER 10, 1976 -. "- ' ..... MULTISHOT___.SURVE _.. dOB NUh~BER 16124 KELLY BUSHING ELEV, = ~?,00 FT, EASTMAN/WHIPSTOCK._SuEvE¥_._9820 .... BEASURED DEPTH 5503 5597 5691 5765 5877 5971 6065 6159 6254 65q8 6%~2 6556 6650 6725 6819 6913 7007 7101 71~ 72~5 73~ 7477 757[ 76~5 7757 7~5[ 794~ ~038 5132 '319 TRUE SUB-SEA COURSE COURSE VERTICAL VERTICAL INCLINATION .... DIRECTION DEPTH DEPTH DEG ~IN -DEGREES 5072,~2 5025.~2 52 0 5130.30 .............. 5085.30 .................52 ........... 0 5188.q9 51~1,49 51 5246.~5 5199.85 51 5304,17 5257,17 51 5565.27 5516.27 50 5422.48 5375.~8 51 5~81,53 5%3~.53 51 5541.85 54~4.85 50 5601.95 5554.95 50 5662.06 5615.06 50 5722,59 5675,59 ~9 5783,22 57~6.22 4~ 58~4 ~'5 5797,55 ~9 ~5 5905.13 5858.15 596~.92 5917.92 6023.48 ..... 5976,48 6081.09 6137.22 6190.00 6248,95 6305.4& 6363.12 6221.31 6%79.42 6539.94 E60O,60 6663,5~ 6726,32 6767.~6 ~54&.!0 603,%. 09 6090.22 61~3.00 6201.75 6258,46 6316.12 6574,51 6~32.42 6492.9% 6~ ~I~.5 6~7~.~2 67~C. ~6 ~7~'~ ~ 0 50 0 51 0 51 55 52 30 53 15 5~ 0 5~ ~5 52 20 52 0 51 30 50 10 ~9 40 ~.& 55 %7 0 q9 10 50 0 5i 30 N'55, 0 W ....... 55.5o u ~0 N 55. 0 W q. 5 N 55, 0 W 10 N 55. 0 W 55 N 55. 0 W 0 N 5~.50 W 10 N 54, 0 W 0 N 5~.50 W 30 N 54,50 W 0 N 54, 0 W 50 N 54,50 W 50 N 5~, 0 W N 5~, OW N 54, OW N 54, 0 W N 5~, 0 W N '5%. 0 W N 5%, 0 W · N 5~, OW N W N W N W N W N W N W N W N W N 0 W hi 0 W 54. 0 55,50 5~, 0 5%, 0 53, 0 54, 0 54, 0 5~,.-0 5~.5 54. 5~. DOG-LEG SEVERITY DEG/IO0 TOTAL RECTANGULAR COORDINATE NORTH/SOUTH EASI'/WES 0,67 17'09,01 N 1217.05 0.~! 1751,23 N 1277,91 0,67 1793,30 N 1338,57' 0,26 1835,57 N 1396.93 0.63 1876,85 N lq57,88 0,26 1918,77 N 1517,75 0.42 1960.91 N 1577.57 0,~5 2005,6q N 1656.73 1,29 2046.52 N 1696,29 0.53 2088,~8 N 1755.12 0.67 2130.71 N 1815,78 0,~ 2172,7~ N 1872.15 0,%0 221~..69 N 1930.~4 0.08 2257,5~ N 1989,1~ 0,26 2299,59 N 20~7,29 1,06 23~2,22 N 2105,96 0,97 2385,~3 ~! 2165.44 0,62 2~29.09 N 2225,54 0.80 2~72.&8 N 2285,53 0,84 2514,80 N 2343,50 0,24 2562,27 N 2408,85 1,56 2606,66 P 2q69.42 O,SN 2650,58 ~ 2529,29 0,53 2693.97 N 25~9.0]. 1.67 2756.39 N 2646.34 0,97 2779,17 N 270~,15 0.80 2820.61 ~ 2761,18 2.03 2861.63 N 28!7.65 2,35 2902,~9 N 2274,%1 0.97 2544.30 k 2932.~9 1.61 298g. S$ ~ 29'20,75 VERTICAL SECTIO'"' W 2057.07 W 2130.35 ,W 2203.35 W' 2276.29 W 23%7.51 W 2~19.6E~ W ..........2492.17 2564.67 2637.*~ 2709.0~ 2780.7~. 2852.05 2923,2~' 2995.26 3066.57' $13&.52 5211.q7 5285.1& ~55a.7= ~29.82: 5509.9& ~564,5" 3658.21 ~751'.~= 5802.2,~ ~873,71 ~9~,6T q082.2"~ ~15~.2f ~22" 6= ) SPERRY-SUN WELL )RVEYING COMPANY ANCHORAGE, ALASKA ATLAMTIC RICHFIELD COFiPAN¥ NGI-9 . CO~PUTATION DATE PRUDHOE BAY OCTOBER 28, 19'76 ALASKA ' -DATE OF SURVEY OCTOBER 10, 1'976 -. NULTISHOT'SURV£ dOB NUMBER 1612~ KELLY BUSHING ELEV, = qT',O0 FT. EASTMAN/WHIPSTOCK SURVEY 9820 TRUE SUB-SEA COURSE COURSE DOG-LEG ~EASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY DEPTH- DERTH OERTH DEG MIN -DEGREES OEG/IO0 IOTAL RECTANGULAR CCORCINATES VERTICAL NORTH/SOUT~i EAST/WEST SECTIu~'~ B~13 690q,2ff 6857,2~ 52 5 N ~508 6961.85 691~.85 53 15 N 6602 7017.~ 6970.~5 5~ 15 N 8697 7072.~3 7025,q. 5 55 0 N .... ~ 5~ ~5 ~ 8?gO 7125,9~ 7078.~ 8S~5 7179,78 71~2,78 5~ 30 N 8979 7235.75 71a8.75 5~ 10 N 9073 7293,50 ........ 72q6,50 .... 50 0 .... N 9166 7351,23 730~,23 53 15 N 9261 7~08.57 7361.57 52 30' N ..... 9355 7~66,~ 7~19,q~ 51 30 N 9~50 752&,0! 7~79,01 50 50 N 95~ 7585,90 7538,90 50 0 N 9638 76q6.6~ ......... 7599.6q ...... ~9 9690 9720 9820 9698 9992 10087 lg179 !027~ 1055~ 1 C S ~ S 7680,81 7633,81 4g 7700,70 7653.70 q8 7767,02 ......... 7720,02 ~8 7619.58 7772.58 ~6 788~.6~ 7837e6~ ~5 7952.09 7905.09 ~q 8019.&7 7~72.87 ~1 30 N 2O N 35 N 20 N 55 N 3O N 0 N 5 N 52,50 W . 51.50 W 51, OW 51. 0 W 50, 0 W 50,50 W 50,50 W 50,50 W 50,50 W 50,50 W 50,50 W 50, 0 W 51,50 W 50,50 W 50. 0 W 50, 0 W ~9, O'W q8,50 W ~8,50 W 51, 0 W 53, 0 W 8090,65 8158.99 8227.57 8296.q0 8565.$3 ~.506.32 80q3,65 ~2 $5 N 51, 0 W 8111.99 q2 50 N 51, 0 W 8180.97 42 45 N 51. 0 W 82q9.~0 q2 30 N 51. 0 W 8318,93 ~2 5 N 50. 0 W 8585.8~ ~i. ~0~ ~ 50, 0 ~ 8~59.32 ~1 0 N 50, '0 W 853q.00 ~I 5 ~ ~9.50 W 85S7.g0 ~l 10 N 50. 0 W 1,59 $030,82 N 1,~8 3077,33 N 1,1~ 312',77 N 0,78 3175,52 hi 0,91 3221.90 N 0,51 3270,39 N 0,34 3520,00 q,~5 ~367,16 3,~9 3~13,53 N 0,78 3~61,71' 1,06 ~508,82 0,81 .5556.1~ N 1,51 3601.98 N 0,97 36~7,12 ~.; 2,35 5672.16 0,78 5755,22 1,87 $775,21 1,50 5818.~7 N 2,~3 3861,38 3,~9 3899,69 2,11 595g,71 0.26 3~78,~0 0,08 gOlg,5~ 0.26 ~058,22 0.2~ ~I~&.S5 0,88 ~178,- 0,~5 q22!.~9 0.75 ~2a0,3!. 30~9,95 W ~298.03 ~109.4, ~ ~373.25 3168,56.w 3228.75 W ~526.0E 5287,q5 W 55q5,75 W ~677.6¢ 5q05,95 W ~755.5~ 3~63.1~ W q829,~? ~519.~9 W q902.2 $577,8~ W ~977.82: "363~,99"W 5051.7~'~ 3691,88 W 5125.61 $7q7,97 W 5197.87 3803.73 W ....... 5269.q2 3633,&6 W 5308.5~I' 3851.06 W 5330.9& 3907,98 W 5~05,7J 3951,30 W 5~6~ 3~ ~062.11 W 5531.1~ ...... ~05.5,13 ~ 55~7,9C ~102,12 W 5659.8 q152,03 W 5722.97 · q201,05 W q299.~2 N 5912.3~ q5~$.~2 W 5~75.*: qqq-4,20 W 6100,2~: qa56,67 ~i 6116,67 k~T3.q& W 6165.2! 45:~.07 W 619~.77' AI'LA?ITZC NGI-9 PRUDH©E ALASKA ALASKA } .................................. ~ ......................... SPERRY-SUN_WELL RVEYING ANCHORAGE, ALASKA RICHFIELD COFiPAN¥ COMPUTATION DATE ~AY OCTOBER 28, 1976 COMPANY ........................ ).PAGE .... _DATE OF SURVEy OCTOBER 10, 197G MULTISHOT SURVE dOB NU~'~ER !~ _ KELLY ~USHING ELEV, '= NT~O0_ FT, EASTMAN/WHIPSTOCK SURVEY 9820 ~D KELLY BUSHING ELEV. = ~7,00 FT. INTERPOLATED VALUES FOR EVEN ~000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL' MEASURED VERTICAL ............ VERTICAL RECTANGLILAR COORDINATES MD-TVD 0 0,0'0 ............... 'q7.00 9qO.'O0 N ' 199, 0 0 1000 1000,00 953.00 9q.O,O0 N 199,00 W -0,00 2000 1999.99 1952,99 9~0,00 N 199,18 W 0,00 ~000 2999,62 2952.62 9~.00 N 210,95 W 0.~7 ......... qO00 3952 59 ~905,59 1109,11 N~'" ~3~.56 W~' ~7.~0 5000 ~733 07 ~686 07 1~97 ~5 ~'~. . . ,-- ~,.. 915 81 W 266,92 6000 5581,55 553q,55 1951,68 N'/~.. 1556,19 7000 6019.17 5972,17 25~2,19 N ~ 2160.99 W~' 980,82 ~000 6657,6p 6590.62 28q5,50 N ~ 2795.17 W ~' ~562.57 9000 72q8,18 7201,18 '' ' 55~0,77 N ~' 5,1~,99 W '"' 1751,81 lO000 7890.2~ 76~.~ 382i.~.D.. N ~ 4.QOG.~9 W 2109.75 VERTICAL CORRECTIOF! -0,00 0,0@ 0,37 ~7,03 219,51 351,51 362.38 381,5~ 389.q3 357,~q- 255,33 THE CALCULATION PROCEDURES ARE BASED ON THE USF' OF THREE DIMENSIONAL RADIUS OF CUR~'ATURE ~iETHOD. } SPERRY-SUN WELL )RVEYING .......................................................................... ANCHORAGE, ALASKA ATLANTIC RICHFIELD COFiPA,'JY NGI-'9 COMPUTATION DATE PRUDMOE BAY OCTOBER 28, 19'76 ALASKA COMPANY ............................................................... }.RAGE 5 -DATE'OF SURVEY OCTOBER lO, 1976 MULTISHOT SURVE ~OB--NU,.~_ ....................... ~,u~R 16124 KELLY GUSHING ELEV. EAST~AN/~HIPSTOCK SURVEY 9820 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE ..... SUB-SEA TOTAL MEASURED VERTIC.~L 'VERTICAL RECTANGULAR COORDINATES MD-TVD --DEPTH DEPTH DEPTH NORTH/SOUTH -' EAST/WEST DIFFERENCE VERTICAL CORRECTIOP 0 0,00 q& ~7,00 lq6 147,00 2q6 2q7,00 3q6 $a7.00 qq6 5~6 5~7,00 6~6 6~7.00 7~6 7q7,00 8q6 8~7.00 9~6 9~7,00 10ff6 10~7.00 ...... 1146 1147.00 12~6 12~7.00 1~7 1547 1747 -~7.00 9~0.00 N 199,00 W 0.00 0.00 9~0,00 ~ 199,00 W '0.00 100.00 9~0,00 N 199.00 W -0,00 200,00 9~0,00 N 199,00 W -0.00 ~00.00 9~0,00 N 199.00 W -0.00 ~00.00 9qO,O0 N 199,00 W -0,00 500.00 9qO.00 iq 199.00 W -0.00 600.00 9qO,O0 N 199.00 W -0,00 700.00 9~0,00 N 199,00 W -0.00 ~OO.O0 9~0.00 N 199.00 W -0.00 900.00 9~0,00 N 199.00 W -0,00 .... 1000.00 9~0.00 N 199.00 W -0,00 1100.00 9~0.00 N 199.00 W -0,00 1200.00 9~0,00 ~,I 199.00 W -0,00 940,00 N 199,00 ~ -0,00 9~0,00 id ~99.02 W 0,00' 9~0.00 ~ 199,05 W 0,00 9~0.00 ~j 199,06 W 0,00 940.00 N 199,11 W 0,.00 13~7.00' ' 1500.00 lqqT,00 1~00,00 15~7,00 1300.00 16~7.00 1600.00 17~7.00 1700.00 -0,00 -0.00 -0,00 0,00 - .. -0,00 0,00 0,00 0.00 -0.00 0,00 O,O0 0.00 0,00 0,00 0,00 0,00 0,.00 0.00 COR?AN¥ DATE OF SURVEY OCTOBER I0~ 1976 ~ULTIiHOT IURV~ KELLY 5!.JSHZNG ELEV. = ~7~00 FT~ EASTHA~/w~I?STOCK ~URVEY ~820 INTERPOL~T£D VALI!ES FOR EVEN ~uO FEET OF ,~u,m~S~A DEPTH DEPTH · ~LC SUn~SFA TOTAL VERTICAL VERTICAL R~T~F~ULa~ COORDT~'~'~ .... ~~ ~D~TVD DEPTH ...... DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERT ~ '" ' ,~C~.L COR° 18~+7 19~7 21'4-.7 22%7 25q-7 24a7 25~7 26%7 2847 2~ 7 ~'~7 ~249 345~ c-o~3 1847,00 1800,0~ 940,00 F,J i99,i4 W 0,00 19~7.00 !90n O0 9qO.O0 i.~ i99,17 W 0.00 2097.00 2000.00 9~0~00 N 199,20 W 0,00 2!g7,00 2100,00 9qO,O0 N · q 25 W 0,00 22~7,00 2200,00 940,00 ~.~ 199,26 W 0,00 2547,00 2500,00 9~+0,01 ~- 199,28 W O.O0 2447.00 2400.00 9q.O,O! N 199,~1 W 0~00 25¥7.00 2500.00 9~O.Oi F: 199.5~'W 0.00 2&~7,00 2600 O0 940,01 ;, 199.57 W o0on 28~7.00 2~un.o0 940~2& ".~ 201 87 W ..... ,, . , , 0,05 2947,n0 290u,00 ' ~,,o 2q. f" 206~8~ W 0,!8 51k7,00 3100,00 =~ 9~,62 ~.: 227,u= W 1,52 5247,00 3200,00 ~60,95 F" 240,66 W 2,79 33~7,n0 5500 O0 971.~5 r'; 256 83 W 4,65 ~ ~': ~ · ~ 5~00.00 984~8~ ,,~ 275~ . 36~7,n0 360C,0o 10"2 0~ ' 3£5.~7 W !~,85 0,00 0.00 0.00 O.OO 0.00 0~00 O,OO 0~05 15 O~ ) uH~ , ALA° A!LA~TIC RICHFi£LO COMPANY NGI-m. CO~iPUTATIO~ DATE PRUOHO£ 3AY OCTOBER 28~ 197~ ALASKA INTERPOLATED VALU[$ FOR EVEN ~00 FEET OF COM'":A,,.,Y. ~- SUD~SEA ',!PAGE ? DATE OF SURVEY OCTOBER NULTZSHOT SURVE _ JOB NUF~¢E~ ~' KELLY ~USHZ~ [LEV. = ~?~00 FT~ EASTMA~/WHiPSTOCK SURVEY 9~20 FiD DEPTH TRUE SU..~,-SEA TOTAL MEASURE~ VERTICAL VERTZCAL R ~,.... AN~ULA~ 600RDZNAT DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WE ES MD-TVD ST DIFFERENCE VERTICAL CORRECTiCE 3771 37q7.00 3700.0~ 10q7,55 3882 38~7,00 5800.00 1076.82 ~106 ~0q7,30 qO00.O0 11q0.25 N ff72o6N ~225 ~1~7,00 ~100,00 1179,q~ N 518~27 ..... ~3~5 q2~7.00 q200,O0 1225,&% N 57!,~2 q60~ ~9~7,00 ~qO0.O0 1528,5~ N 698.87 4880 ~647.00 ~600.00 !~q6.25 N 847.77 5018 q7~7,00 *700.00 150~,87 ~; 923,87 5154 48~7,00 qbuO,O0 t557,65 N 999~50 5501 4947.00 4900.00 1618.2¥ [~ 1088,51 ..... ~n. O0 1690, 582~ 5197,00 5100,00 ' ' 1765,3k...~'i 129=¢.53 5785 52~7,00 5200°00 1855,~8 ~..I 1399,09 59q5 53~?,0~ 5300,00 190.7,2~ U 1501~3~ 6103 5qqT.o0 5~00,00 1978,50 f,J 1602,02 6262. ~5~,~- .~,u,.~ ~50-.-O,~O~ 2050,0c.~ W 2~,82 7.96 W 35.17 10.55 W ~g,7! 11.5~ 'W 59.44 i2~72 W 76,19 16,7~ W 98,53 22,33 W 126~29 27.78 W 157,11 W 192,q0 35,29 W 233.81 ~1.40 W 27!.~7 57.86 ~ 507~75 58~05 W 35~,7& q7,02 W ~77,I2 W 538.2q 61.11 W 656,95 58,77 W 715.00 ANCH©RAGE~ ALASKA ATLA,,..~., ~'CRICHF'?~ A~,iY . ~ ~LD CO~P f'~G Z ~'~ CO;]PUTATION DATE ALASKA INTERPOLATED "~V~L.~b"-~ FOR EVEN t00 FE~T OF SUB-SEA DEPTH' i u~. SUB-SEA TOTT, L MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MB--TVD DEPTH DEPTH ...... DEPTH NORTH/SOUTH EAST/WEST DZFFF_R~-''''''~,~ VERTICAL CORRECTIO~: 6-~i8 56~7.00 5600,0~ 2120,15 B~ !799,25 W 771,56 657;5 57~7,00 5700..,00 2!-59.~52 ,.N !8~5,~9 W 826,85 6728 58~+7, O0 ~.~uO. O0 2~:e ~ ' - . ~u..u~ N 199!,~8 W 881.78 6884 59~7.00 5~00.00 2329.21 r~; 2088.06 W 937.52 70~5 60~7,00 ~O00,OO 2~03,08 7210 61q7,00 6!O0.Ou 2 '¢ ~- " ~o0~ N 2296,12 W 1063,3~ 7~79 6247,~n~ ~ 6200.00 75~ 63~7,00. 6500.00 2'~'oo8,~5 fj 2512,59 W 1197,80 7706 6~7,00 6qO0.O0 2712,92 ;d 2815,02 W 1259.17 78&i &547,00 6500.00 ~784,05 N 2710,87 w 131~,89 8013 66~7,00 6600,00 2851,21 N 2803,30 W 136&,7~ EI~3~ 67~7.0n`, 6700~n0= 2~S6~38 ~o~0 68~7.n0 6800~00 2907,29 x.; 2991.~ W !~73,~3 8~8~ 6°~v, O0 6~00,00 ~064,°'~ ~',,~ x093~ 87 W !5TM _~ 7 -. .~ ~00,59 W 1605 72 8326 7147.00 7100.00 32~!.0~ ¢.~ 3610,27 W 1679.~7 ~7 W2~7,0o 7200.00 9325 7a~7,00 7q-.¢' ' 76 . ,~0, O0 5~' ~:~ N ~616, 56,55 55.27 56,73 60,61 65,!1 61~36 55,72 5!,8~ q9.~7 62,73 69.55 7~,5! 60~95 ATLA?-~7 ZC ALASKA DATE OF ""." KELLY 8USr{z:'4G DLEV. - O0 FY EASTMAN/WHIPSTOCK SURVEY 9820 :U¢-S:A DEPTH ,,.,TERPOL.ATEO VALUES FOR EVEN lOO FEET OF "' " . TRUE SUB=SEA TOTAL ~EASUnEO VERTICAL VERTICAL RECTANGULA~ COORnlNA~._S MD~TVD ' ~ SOUTH DEPTH DEPTH DEPTH NORT,,/ EAST/~EST DIFFERENCE VERT~CA CnRR~TY L ON 9~S5 75q7,00 7500.0Q 5572~69 N 3711,62 W ~- ' '' ~ 580~ 05 W t991,55 $ 96:8 76~7.00 7000,00 3o~7.~9 ~- 97,-~9_. 77~7.00 7700.00 5720.46 N 3890,99 w,~ 20q2.88- 99~8. 78~'7.00 7600.00 ~.~.=~oo 63 N ~.x973,25 W 2091.12 10079 79~7.0~ 7900 O0 ~' N - 38~8.28 ~0~9.30 W 2132.91 102~ 80~7,0~u 8000,00 3913,92 N ~12l,O0 W 2167,98 !~-' ~ 8100.00 3971,~! r ~192,~I ~ 2203~ ~ 10~6~. 82~7.00 8200~ .00 ~0~9.~6_. ,.,"' ~26%,5~. W 223~..¥1 ,..~-~._.-0622 8~7.00 8300.00 4007.~6 !'~ 4355.33 W 2275.~8 ........ ~0756 8~7.00 8%00.00 ~1q5~28 ;4 4%0~.22 W 2309.98 10589 85~7.00 8500.00 6201,91 N ~70.98 W 23~2.8~ 10980 ~' °0 59 55 5~ 36 :55 32 22 THE CAL_CULATIui,; : ~u,.,,EDURES USc A THE F.;£AREST ~0 FOOT ~", '-'r; .-.~., iF R~r'IUS OF rURVATURE) POINTS .... ;_ ....... ~__ .~- ........................................ :'- , t i~ ' ' ' !;:*--'"'"~?'* ................ ' . . ...... !_. _'~. ~ ........ · L i Atlantic~ichfic4d~ ........ T~ ...... October 12, 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 No. 9 (22-2-11-14) Permit No. 76-68 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Sincerely, District Drilling Engineer CRK/jw Enclosures n),-,-,., ~o. P-4 STATE OF ALASKA I'US'V. OIL AND GAS CONSERVATION COMMII-rEE MONTHLY REPO'RT OF DRILLING AND WORKOVER OPERATIONS o,L []] oA, []] oT., Gas Injection WKLL WELL 2. NAME OF OP]~ATOR Atlantic Richfield Company 3. ADDRESS OF' OPERATOR P. 0. Box 360, Anchorage, Alaska 4. LOCA/'ION O.F 995]0 20'N & 940'E of SW cr Sec l, TllN, R14E, UM SUBMIT IN DUPLIC~T~ !s. A~'~ NU~EmC~L CODE 50-029-20228 6 LEASE DESIGNATION A.%-D SERIAL NO. ADL 28302 7. IF INDIA]~, ALOTTEE OR TRIBE NAi~IE 8. L,~IT,F.~{A~ OR LEASE N.kME Prudhoe Bay 9. WELL NO. NGI No. 9 (22-2-11-14) 10. FIELD A_NTD POOL, OR WILDCAT . Prudhoe Bay - Sad]erochit Pool 11. S~--C., T., R., M., (BO~I'O~'~ HOLE OBJEc~rv~ Sec 2, TllN, R14E, UM 19-. PER3VIIT NO. 76-68 13. REPORT TOTAL DF~TH AT END OF MON~JH, CHA~NGF~S IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLLTMES USED, PERFORATIONS, /'ESTS A.ND I:LESULTS. FISHING JOBS. JLrlNTK LN HOLE A_ND SIDE-TRACKED HOLE AND ANY OTITER SIGNIFICANT CH3%NGF~ IN HOL~ CONT)ITIONS. See Attached. .. /-/' (1 ~ . Y (_l oil .,d J,I 1-'$nlervutio, committee by the 15th of the lu~ceedinj month, unle~ o~herwiJe directed. MONTHLY REPORT OF DRILLING OPERATIONS NGI No. 9 Cont drilling 12¼" hole to 9820'. Cond hole for csg. Chgd & press tstd 9- 5/8" rams. Ran 171 jts 9-5/8" 47# MN-80 butt csg and 65 its 9-5/8" 47# S00-95 butt csg w/shoe @ 9750', FC @ 9663', lower FO @ 2460', upper FO @ 2334'. Cmtd w/750 sx Class "G" cmt w/l% CFR-2 slurry 15.8 ppg. Displ cmt w/707 bbls mud. ND BOPE. Installed emergency slips & dummy pkoff. Press tstd BOPE & csg pkoff to 5000 psi. PU RTTS tool & shifting tools. Cmtd down thru lower FO w/275 sx of PF "C". Closed FO. Tstd FO w/3000 psi OK. Opened upper FO & rev out. No cmt. Did Arctic Pack job thru upper FO w/O% wtr @ end of job. Closed upper FO & tstd to 3000 psi OK. RIH to top of cmt 9311'. Drld cmt from 9311 '-9663'. Tstd csg to 3000 OK. Drld FC & cmt to 9741'. Cond mud. Tstd csg to 3000 psi OK. Drld cmt & shoe plus 5' of open hole. Ts td form to 11.9 ppg equiv OK. POH & PU 8½" BHA. Reamed BHA thru cmt sheaths. Drld from 9825'-10520'. Pipe started torquing up. Drld w/high torque to 10,552'. Stuck @ 0530 hrs 9-14-76. Work stuck pipe & spotted 50 bbls of 10.9 ppg SFT spotting fluid. Covered BHA w/spotting fluid leaving 45 bbls in DP. Move fluid 2 bbls per hr. Jarred on stuck pipe while moving SFT spotting fluid 2 BPH. Displ spotting fluid & cond hole. Ran freepoint indicator showing pipe free up to 10,415' Showing pipe 100% free 10,415' & stuck @ 10,435'. Freepoint moved up ~ole during 3½ hrs while looking for freepoint. Circ & cond hole & ran back off shot. Backed off over crossover sub @ 10,410'. RD wireline, POH. PU fishing string and ran into 9-5/8" shoe. Slipped & cut drlg line. Picked up 69 jts of grade "G" drill pipe and circ bottoms up above fish. Lapsed time back-off was 13 hrs. Found additional bad spot in drlg line. Pulled back to 9-5/8" shoe & cut off more line. Ran back to fish and screwed in. Circ OK. Jarred on fish and prep 75 bbl of SFT spotting fluid. Fluid in place w/35 bbl around fish. Moving fluid 2 bbl/hr. 12 hrs~jarring on fish & moving spotting fluid. Fish plugged off @ 1830 hrs 9-17-76. Jarred on fish. Attempted to unplug fish. Ran freepoint indicator, could not get down. Reran tools to 10,425', freepoint @ 10,415'. Backed off fishing string @ 10,152' while working down lefthand torque. Screwed back in. Made second attempt & dialog tools failed. Reran dialog & string backed off @ 10,242'. Trip in w/screwinsub & screwed into top of fishing string. Ran freepoint indicator, worked down to 10,379'. Tools quit, POH leaving 53' dialog fish in collars. Trip in w/wireline fishing tools, could not get down Top of wireline fish @ 10,326'. Trip in for backoff @ 10,302'. String b~cked off @ 10,241' while putting lefthand torque into string. Could not screw back in. Circ & cond. Chained out of hole. Left screw in sub in top of fishing string. Penetration rate log shows top of Sag River @ 10,285', top of Shublik @ 10,360', top of Sadlerochit @ 10,395'. RIH to shoe of csg. Slip & cut drlg line. Screwed into fish @ 10,241' Ran dialog tools & worked down to btm of 1st DC. Tools stopped in ~e!led mud. Backed off collar & circ btms up from 10,272'. Circ & cond hole. POH & rec screw in sub in 30' DC. Made up bit 2 stabilizers, 2 DCs & made cond run to top of fish. Washed & reamed from 9890 - 10,272'. Hole tight & sticky. Hole above bit in good cond. Circ & cond hole. RIH. Left drl pipe rubbers in hole. TIH w/WP to catch rubbers. Could not wash over fish @ 10,272'. Circ & cond hole. Trip out. TIH w/screw-in sub. Screwed into fish @ 10,272' Pulled goose neck & rotary hose. Ran Dialog & check top of fish @ 10,2~1'. DP single looking up. POH. LD fishing asbly &~PU~.8½" washover shoe on 1 jt of WP. Worked over top of fish & swallowed sfngle. Landed DP in tbg head. Chgd out rams to 2-3/8". Ran 1-3/4" DC on 2-3/8"- butt. Washed from 10,280'- 10,378'. Found Dialog fish. POH & rec 47' of WL fish. Left btm 6' of Dialog tool w/top @ 10,425'. PU mule shoe & reran wash out string to 10,240'. CO, circ inside of fish clean. LD 2-3/8" tbg. Landed 1 jt of DP Set safety valve in tbg hgr & chgd rams to 5". RIH w/ 2" OD perf gun. ~topped @ 10,392' Trip out. PU 35' of 1-11/16" sinker bar. RIH to 10,413'. POH. PU keily. Screwed into top of tbg hgr. PU & circ. POH. LD WP. PU safety jt. RIH & screwed into top of fish @ 10,242'. TIH w/sinker bar to 10,412'. Trip out. PU live gun. TIH to 10,383'/10,393'. Press to 1000 psi. Fired gun, Press to 3500 psi. No penetration. Prep to_reperforate. Made up & ran 2' of Dialog perforating gun. RIH & shot 10,380' - 10,383'. Checked for penetration w/5000 psi. No circulation. ~q3~~'~L~p~6i~'~' indicating collar free to 10,332'. Attempted backoff w/shot @ 10,332' Backed off of safety joint. Screwed back in and attempted backoff @ 10,302~. Backed off again @ safety joint. Screwed back in & attempted backoff @ 10,302'. PU 10,000# of string wt indicating backoff of one DC below top of fish. Circ btms up. As of September 30, POH. Rec safety joint & one DC. Top of fish @ 10,302'. RIH w/450' of 2~" DP stinger & 5" DP to 10,302'. Pumped 25 bbls flush ahead of 150 sx Class G cmt mixed w/l% CFR-2 & 0.2" HR-7, slurry 16 ppg. Displ cmt plug w/35 bbls wtr @ 171 bbls mud. POH. PU BHA. RIH. AtlanticRichfieldCom~a;~y North Ah~$! 'isl,ric~ Post OfficF ~;-< 300 Ye~ephen{- 907 277 ~637 October l, 1976 Mr. O. K. G ilbreth State of Alaska - Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: This letter is to reaffirm the substance of our telephone conversation of September 28, 1976 concerning Atlantic Richfield's course of action on the North Gas Injection Well #9. Our situation was as follows: We had stuck drill collars in the wellbore on September 14th. Since that date, attempts to back off and jar the fish resulted in leaving more drill collars in the hole. Further fishing operations could only aggravate the problem as the angle of the hole is 53~. We proposed to come out of the hole and plug back above the fish with an open hole plug. Our purpose in notifying the State was to make you aware that we would leave an uncemented fish in the hole between the Sadlerochit and the Sag River Sands. We feel that these formations are already in direct communication due to a system of faults at this vicinity of the structure. The original NGI #9 wellbore would therefore not initiate communi- cation between these zones. Listening to all the information given, you concurred with us that our proposed action was an acceptable solution to our problem. Please let me know if you have any comments to add to this recollection so that this letter may reflect an accurate picture of our interchange. Very truly yours, C. R. Knowles ~c~'~ District Drilling Engineer CRK/jw September 8, 1976 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 1-4 (23-5-10-15) DS 3-6 (Il-14-10-15) Dear Si r' Enclosed please find the Mo~,thly for the above mentioned wells. Si ncerel y, pC. R..Knowles District Dril'ling Engineer CRK/jw Report of Drilling Ix.. fi'"", Operations Enclosures F~rm No. P--4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, WI:LL ~.LL fi~ T n'i~r't'~ nn 2. NAME OF OP]gl:G%TOR Atlantic Richfield Company P. O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL 20'N & 940'E of SW cr Sec l, TllN, R14E, UM 50-029-20228 6 LEJkSE DESIGNA~'~ION A.~'D SERIAL NO. ADL 28302 ? IF INDIA]~. AL/OTTEE OR TRIBE NAME 8. L.~IT F.~I~,{ OR LEASE NAME Prudhoe Ba}, g WELL NO NGI No. 9 (22-2-11-14) 10. FLFJ~E) A-~TD POOL. OR %VILDCAT Prudhoe Bay - SadlerochSt Pool ii SEC , T., R., M.. (BOT'TOM HOLE o~rv~ Sec 2, TllN, R14E, UM 12. PE~JVIIT N'O. 76-68 ]3, REPORT TOTAL DI~iPTH AT END OF MON'rH, CHA. NGES IN HOLE SIZE, CASING AN/) CEMF_~NTING JOBS INCLUDING DEPTH SET AN~D VOLLrMZES USED. PERFORATIONS. TF_,STS A_N-D F,.ESULTS FISHING JOB~ JL~K LN HOLE A/WD SIDE-T]q, ACKED HOLE A. ND ANY OTHER SIGNIFICANT CH. ANGES IN HOLI~ CONDITIONS. Spudded 17½" hole @ 2100 hrs 8-24-76. Drld to 2733' Ran 13-3/8" 72# MN-80 butt csg w/shoe @ 2715', FC @ 2641'. Cmtd 13-3/8" csg w/~150 sx PF ti cmt. Installed & tstd pk-off 2000 psi OK. RIH w/12¼" bit. Drld FC, cmt, & shoe @ 2715' + new form to 2743'. Press tstd form to 11.5 ppg equiv. Drld to 4881'. Cond hole for trip. On August 31, RIH & drld 12¼" hole to 5100'. oil and ~as coniervotion commiflee by the 15~ of the su~cNding month, uflleM Otherwise directed. O2~1B STATE of ALASKA DEPARMENT OF NATURAL RESOURCES Divlsion of Oil and Gas To: [-- Hoyle H. Hamilton~ Acting Director FROM: Harold R. Hawk i ns Petroleum Inspector DATE , September 7, 1976 SUBJECT: TO witness BOP test for ARCO and inspect abandonments for Mobil. Each separate reports. This report NG! No. 9, Sec. 2, TIIN, RIhE, UoM. Permit No. 76-68 for ARCO August 27, 1976 - I left my house at 6:00 AM for Wien flight to Prudhoe Bay to witness BOP testing of NGI No. 9 and inspect several abandonments for Mobil Oil. Wien flight No. 9 was cancelled and BP gave me the ok to take BP's chartered flight to Prudhoe at 10:OO AM. The. BOP tests were ~supposed to be Saturday afternoon, but Oonnie Fields, pusher for ARCO, said BOP tests would start sometime today. I arrived at. Deadhorse at 1t:30 AM and arrived at NGI No. 9 drill site for ARCO with Donnie Fields at 12:.30 PM. ! called Bud Abram, operator for Mobi. 1, and told him where ! was. He told me he would pick me up by chopper as soon as he could .get one and accompanying him would be Ken Sullivan, another operator for Mobil. Donnie Fields and I decided this would be a good time to test the manifold of NGi No. 9. There were 46 flanges and 16 low torque wing valves, one Swaco superchokewhich I witnessed the testing to 5000 psi and all were O-K. One positive choke was actuated. This was all we could test at this time. They are now nippling up on the BOP. Time is 3:00 PM. At 3:20 PM, Bud Abrams, operator for Mobil, and Ken Sullivan picked me up by chopper at drill site No. 9 and we proceeded to check .out their proposed abandonments which wi 11 be on separate reports, t inspected several aban- donments from 3:20 PM to 7:30 PM for Mobil and they brought me back to the NGI No. 9 drill site. At S:OO PM I started BOP tests on NGi No. 9 as they just finished nippling up as 1 got there. They tested the hydrii first to 3000 psi using a ~ll- head type test plug. Next the top pipe rams and insidevalve on the kill llne and inside valve on the choke line and two cameron type valves on the spool were tested to 5000 psi. Then the outside kill valve and outside choke valve was tested to 5000 psi. Next the test st.emwas pu!led and blind rams and HCR valve and check valve was tested to 5000 psi. ~ugust..2~, 1976 - The test stem was put back in and the lower pipe rams were tested to 5000 psi plus two other cameron type F valves to 5000 psi. The test plug was pulled again and the upper and lower kel-l.y were tested to 5000 psi. Ball valve and dart valve on the floor were O-K. I looked the location over and it Is in very good shape. They have a steel fuel tank not bermed. The well sign is in place with all data OK. .The pit area is well harmed. The master gauge on the accumulator showed 3000 psi. The N2 backup bottles had 1650, 1450, 1500, 1700, 17OO, 17OO psi. The control panel on the floor is working in good shape. Ho H. Hamilton -2- Sept~er 7, In summary: I witnessed a BOP test on NGJ No. 9 and found all components in good working condition and all tests complete. ! also Inspected several proposed abandonments for Hobil 0II which will be on separate reports. 1 also talked to Chris Gulnn, Alaska Division of Lands In Falrba-nks, before I left Anchorage. He told me he would accept my d~lslons on inspections of Hobll abandonments. A copy of my reports and pictures are to be sent to him - Chris Gulnn, Division of Lands, qqZO Airport ~Road, Fairbanks, Alaska ~9701. Attachment -v . al.~r~.o.,..,. Jll and Gas Conservation ,Dr~:Perm~,t No. 7~~.~:',', ~': ' . ' ' Operator ~ ~r~ Represented by~~t~l~2~me & Number ~-g ~.~ ... ~::.~- - · .. Sari Sfactory Yes. No Item (~ () () () () ( ) ('~'~) 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 .e Inspecti on Location ,General 1. Well Sign 2. General Housekeeping 2. Reserve Pit-(~t)open( )filled 4. Rig ( ) Safety Valve Tests Sal~i'sfactory -.Type I-nspection Yes No Item '0~) BOPE Tests () (~)() () () () () 15. L:~,~Casing set 16. ~fluid-( )Wtr.-~--[ )mud (~'oil .1.7.~... Master Hyd. Control Sys.~m psig 1-8. N2 btls.~~.l~s'i~ 19. Remote Co~ro~s-- · /~ 20. I)rilling spgol.~__"outlets- ' 21. Kill Li.ne-(~) Check valve ~J () (~) () () (~ () 22. Choke Flowline (X~ HCR valve 23. Choke Manifold No. vatv~ fl~s~ 24 '.Chokes'~R. emote( )Pos.~_Adj] '~-~-- 25 Test Plu~;~)Well. hd( )csg( )none 26 Annular' ~reventer~s~.~ 27. Blind Rams~ps~q ( ) ( ) 11. P&A Marker (~) ( ) 28. Pipe Rams~_~_~!~psiq ( ) ( ) 12. Water well-( )capped( )plugged (~) ( ) 29 Kelly & K611y-cock_~"~m~psig ( ): ( ) 13. Clean-up (~. ( ) 30. Lower Kelly valve~_~si? ( )' ( ) 14. Pad leveled (~) ( ) 31 Safety Floor valves-~i~)BV ~')Dart Total inspection observation time_~ hrs/days Total number leaks and/or .eQuip. failures_~ Remarks. cc' ~,~/~' ~,~ Notify in --,-~days or when ready,,----Inspected Division of Oil and Gas 3001 Porcupine Drive, Anchorage, Alaska 99501 August 4, 1976 Re: Prudhoe Bay NGI No. 9 (22-2-11-14) Atlantic Richfield Company State Permit No. 76-68 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 2, Township llN, Range t4E, U.M. Well samples, core chips and a mud log are not required. A directional survey is required. )tany 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 comnencing operations you may be contacted by the Habitat Coordinator's office, Depart- ment of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations prolmulgated 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· llke 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 -2- August 4, 1976 In the event of suspension or abandonment please give this office adequate advance notification so that we may have a witness present. Very truly yours, Hoyl e H. Hami 1 ton Member Alaska Oil and Gas Conservation Committee Enclosure CC: Department of Fish and Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Department of Labor, Supervisor, Labor Law Compliance Division w/ encl. AtlanticBichfieldCompany North Americ'"'~ Producing Division North A~aska ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 2, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: North Gas Injection Well No. 9 (22-2-11-14) Sec 2, TllN, R14E, UM Dear Sir: Enclosed is our Application for Permit tc Dr~ll the above-mentioned well, together with the $100.00 application fee and required survey plat. Since this is the ninth well drilled from this dr~ll site, we request the waiver cf the double diverter line requirement of CO 137, Rule 4. This well will be directionally drilled. The surface and bottom hole 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, ?/7 C. R. Knowles District Drilling Engineer CRK/MAM/cs Enclosure Form 10-401 ' SUBMIT IN TRIPLICATE (Other instructions on REV. 1-1-71 reverse side) la. TYPE OF WORK b. TYPE OF WELL OIL WELl. [~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL [] DEEPEN [-'] GAS SINGLE MULTIPLE WELL[] OTHER~aS Injection ZONE [] ZONE · 2. NAME OV OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360~ Anchorage~ AK 99510 4.LOCATIONAtsurfaceOF20,~/WELt_ , & 9/40'E offer of Sec 1, TllN, R1/4E, UM At proposed prod. zone -8300'SS, 2180'E & 2180'S of NW er Sec 2, TllN, R14E, UM 13. DISTANCE IN MILES AND DIREI2TION FROM NEAREST TOWN OR POST OFFICE* · ~ : · Approx 8 miles north west ef Deadhorse AP I # 50-029-20228 6. LEASE DESIGNATION AND SERIAL NO. ADI, 28202 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI No. 9 (22-2-11-14) 10. FIELD AND POOL~ OR V, qLDCAT Prudb. oe Bay -Sadlerochit Pool 11.SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. Sec 2, TllN, R14E, UM 14. BOND INFORMATION: TvPEStatewide Suretyand/orNo. Federal Insurance Cc,. #80113840 ~mount $100,000.00 15. DISTANCE FROM PROPOSED * [ 16. No. OF ACRES IN LEASE 17. NO.ACRES ASSIGNED LOCATION TO NEAREST I TO THIS WELL PROPERTY OR LEASE LINE, FT. 2180' [ 2560 :' _,~20 (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION I 19. PROPOSED DEPTH 20. ROTARY OR CABLE TOOLS TO NEARF. ST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 3370~ I 8657'T~ (10,970'MD) Rotary · 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 18' Gravel Pad 22. APPROX. DATE WORK WILL START October 15, 1976 **See below** 23. PROPOSED CASING AND CEMENTING PROGRAM . . SIZE OF ItOLE SIZE OF CASING WEIGIIT PER FOOT GRADE SETTING DEPTH Quantity of cement -. '~2'"' " 20" 94# 'Hd4'0 100'MD' ' Circ tc surf +500 sx Permafrost , 17-]_/2" 13-3/8" 72# N-80 2700'MD Circ to Surf +4000 sx permafrost ii'-.1/4', 9-5/8" 47# MN-80 9646'MD +1500' cmt clm ].st stg_+750 sx .... & $00-95 +300' cAt clm 2nd stg +275 sx 8-1/2" 7"' lnr 29#, MN-.80 TD _+--t800' cAt c].m. +300_ sx-- Atlantic Richfield Company propcses to directior, ally drill this well to 8657'TVD, 10970'MD for future use as a gas injection well into tee Sadlercchit 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 opera- tiona].ly checked on each trip. A non-freezing fluid will be left in all uncemented annuli in the permafrost interval. Seven inch 29# ML~-80 tubing with a Baker "SAB" packer assembly & a 7" safety valve landing nipple will be rut. as completion assembly. This well wi].l be shut in pending perforation. **Note: This work could start approx. Auzust 15, 1976. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present produclive zone and proposed new productive zone. If proposal is to drill or deepen dixectionally, give pertinent data on subdurface locations and measured and true vertical depths. Give blowout preventer-program. ~ 24. I hereby certify that the, Foregoihg is True and'Correct SIGNED. ~J--~([ TITLE Dist. Drlg Engineer (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED I MUD LOG [] Y~S ~ NO I [] YES g] No DIRE~IONAL SURVEY REQUIRED YES [] No CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-029-20228 PERmT NO. 76- 68 APPROVAL DATE APPOVED BY .... " . TITLE Member *See Instruction On Reverse Side Auqust 4, 1976 DArU. August 4, 1976 5P_C t tON 915' 940_' section ._ line 965' 989 1014 10.~9 ~ 1. 1064' . .... A '~:~ -- A? BUILT W£~L NO ~ LAT. 70°t9'36. t29'' LONG. 148°28'50016" WELL NO. 2 .L A T. 70° 19' 57.284" LONG. 148° 28'.50.762" WELL NO. 3 LAT. 70° 19'38.441" LONG. 148°28'51.495'' WELL NO. 4 LAT, 70° 19'$9.596" LONG. 148°28'52.223'' WELL NO. 5 LAT 70° 19' 40.749" LONG. 148°28'52.947'' WELL NO. 6 LAT 70°19'41.908'' LONG. 148°28'53.68Z' WELL N O. 7 LA-[ 70c 19'45.052", LONG. I48°28'54.412' WE'LL NO. 8 LAT. 70° 19' 44.210" LONG. I48°28'55.!26'' WELL NO. 9 LAT. 70° 19' 45.370" LONG. 148°28'55.850'' WELL NO. i0 LAT. 70° 19'46.5i9" LONG. 148028'56.589" Y 5 971 400.07 X 687 350.54 Y.,.~ 971 51690 X 687 522 06 Y 5 971 65.376 X 687 294.09 Y 5 971 750,62 X 687. 266.18 Y 5 97i 867:ft X 687 ,,. ~ 8.47 Y 5 97I 984 28 X 687' 210.34 Y 5 972 099.94 X 687 182.47 Y...,c 972 2 I7.07 X .687 !55.06 Y 5 972 334 `31 X 687 12731 Y 5 972 950.53 X 687 099.t4 EXISTING WELL O~ CONDUCTOR PIPE SECTION CERTIFICATE OF SURVE'YOR 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 SURVEYOR 12 WELL NO. I TOP PAD ELEV. = ~8.4 FT. MLLW ARCO~ AFE 292265 HVL #. ' '. ATLANTIC RICHFIELD CO. AS -BUILT WELL I THUR IO NORTH INJECTION SITE LOCATED IN PROTRACTED PREPARED BY NEWITT V. LOUNSBURY ~ ASSOC. 72.3 W. 6TH. AVE., ANCHORAGE, ALASKA DATE OCT 9, 1975 SCALE I = 300 LOOSE CHKD. BY G. D. FIELD BK. LEAF CHECK LIST FOR NEW WELL PERMITS Company .. Yes No Remarks 1.Is the-permit fee attached ...................... 2. Is well to be located in a defined pool . . . 3. Is a registered survey plat attached .......... ~ 4. Is well located proper distance from property line ....... 5. Is well located proper distance from other wells . 6. Is sufficient undedicated acreage' available in this pool ...... ~L~j~ 7. Is well to be deviated ....... 8. Is operator the only affected party ...... , .... ~ 9. Can permit be approved before ten-day wait .......... K~/~3~ 10. Does operator have a bond in force ll. Is a conservation order needed . . 12. Is administrative approval needed ................. 13. Is conductor string provided ............. ...~. .... 14. Is enough cement used to circulate on conductor and surface ..... 15. Nill cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons ........... 17. Will surface casing protect fresh water zones ............ 18 Will all cas'~nq give adequate safety in collapse tension & bur~t 19. Does BOPE have sufficient pressure ratinqT~. . . ~/~l~. . ~.p...4'oo~'~. . .-. Additional Requirements: Approval Recommended: Geology Engineering' UAL LCS JCM . Revised
