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198-126
S ll. PRGAcIiVE DIAgNoSTIc SERVICES, INC. WELL L®IL,7 TRANSMITTAL To: AOGCC Natural Resources Technician 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) LeakPointTM Survey 2) Signed Print Name: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2 —1 900 Benson Blvd. Anchorage, AK 99508 GANCPDC(a USAANC.hou.xwh.BP.com and ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 29 -Mar -19 02-11A CD 1981 i5 30815 RECEIVED MAY 2 1 20M AOGCC 50-029-20273-01 Date : / PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245$952 E-MAIL: PDSANCHORAGE(dMEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM DdAchim MasteffemplateFae ,,Templates,Distribution\TrarumtittelS t bkBP Tm itdocx STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Popl ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Mill CIBP 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ® Exploratory ❑ 5. Permit to Drill Number 198-126 3. Address: P.O. Box 196612 Anchorage, AK99519-6612 I Stratigraphic ❑ Service 1 6, API Number: 60-029-20273-01-00 7. Property Designation (Lease Number): ADL 028308 8 ADL 028311 8. Well Name and Number: PBU 02-11A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL -. q.;c=•- 11. Present Well Condition Summary: Total Depth: measured 13337 feet Plugs measured 12900, 13305 feet CC f1 r1 true vertical 9026 feet Junk measured 12883, 12884 feet ')-EB z 9 2613 Effective Depth: measured 12900 feet Packer measured 10897 feet 1� true vertical 9061 feet Packer true vertical 8278 feet AO G C �d Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 26-106 26-106 1490 470 Surface 2687 13-3/8" 25-2712 25-2703 4930 2670 Intermediate 11453 9-5/8" 23-11476 23-8703 6870 4760 Production Liner 2316 3-1/2" x 3-3/16" x 2-7/8" 11021 - 13337 8369-9026 10160 / 10570 10530/11160 Perforation Depth: Measured depth: 11187 -13300 feet True vertical depth: 8491-9029 feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 21-11476 21 -8703 Packers and SSSV (type, measured and 5-1/2" BOT RHR Packer 10897 8278 true vertical depth) No SSSV Installed 12. Sfimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 880 0 Subsequent to operation: 331 26792 518 0 1671 14. Attachments (re.d per 20 nac M 07025.071, s 25 asst 15. Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil m Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Meixueiro, Paulina Contact Name: Meixueiro, Pauline Authorized Title: Production Engineer- Contact Email: paulina.meixueimAbp.com Authorized Signature: e�..,3' ✓-'" r' Date: 2�Z10� iq Contact Phone: +1 907 564 5971 Form 10.404 Revised 04/2017 'aT7RBDM9gfJEB 2 7 2019 Submit Original Only D. Daily Report of Well Operations PBU 02-11A ACTIVITYDATF RI 1MMARV 'WELL S/I ON ARRIVAL*** (Profile modification). DRIFT TO WFD CIBP 11,589' SLM / 11,575' ELM W/ 2.30" CENT, S-BLR (No sample or issues). 1/17/2019 'WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS' CTU #8 - 1.75" Coil: Job Objective: Mill CIBP MIRU. RIH w/ 2.30" 4 bladed junk mill. 1/29/2019 "*In progress' CTU #8 - 1.75" Coil: Job Objective: Mill CIBP Continue RIH w/ 2.30" 4 bladed junk mill. Dry tag at 11599ft. Mill to 11602ft. POH and MU 2.25" burn shoe with 2.06" venturi. RIH and drytag at 11,604'. Mill on CIBP for 30 minutes and then POOH. Recovered small abount of slip and thread piece. MU 2.35"- 5 bladed junk mill and RIH. Work through lower patch at 8318ft. Dry tag at 11605ft. Attempt to mill, POH after many stalls & attempts to mill. 1/30/2019 '**In progress' CTU #8 - 1.75" Coil: Job Objective: Mill CIBP Continue from 1/30/19 WSR POOH w/ 2.35" 5 bladed junk mill BHA. Trim pipe for coil life. RIH w/ 2.30" burn shoe with 2.06" venturi. RIH and continue milling on CIBP @ 11604' CTMD. CIBP released after 40 min and was pushed to 12466' CTMD into perfs at top of interval. Attempted to continue down hole with several stalls in same area of liner. POOH and conducted pipe management; cut 120', then RIH with four bladed 2.31"junk mill. Push mill to 12598ft. POH for BOP test. 1/31/2019 ...in progress... CTU #8 1.75/.156 WT. Job Scope: Mill CIBP and push as deep as posible, Perform weekly BOPE testing. RIH w/2.31 four bladed junk mill dressed with opti-cut. Tagged CIBP at 12593' continued milling/spinning pushing CIBP to a depth of 12883' CTMD. Program objectives met. POOH & RD. Well secured and DSO notifie . 2/1/2019 ***Continue Job on 2/2/19 WSR*** CTU #8 - 1.75" Coil: Job Objective: Mill CIBP Continue from 2/1/19 WSR. Continue to prep coil for blow down. Blow down reel for welded coil extension. RDMO. 2/2/2019 '**complete... TI;EE=- 5-1/8' FMC IVV3LF6AD= FMC ACTWTOR= AXELSON CKB. 1-=-56 0- Rff B-Bf = 66.0' BF. E -EV = 30.59' KOP= 243T Max Angle = 99' @ 13029' Daken MD= 1167T DakanTVD= 8800'SS 13-3/8' CSG, 72#, N-80, D = 12.347' 1- 277 Minimum ID = 2.375" @ 11569' 3-3/16" X 2-7/8" XO 3-12' BKR DEPLOYMENT SLV, D = 3.00' 1 .0087 bpf, D = 2.992' 11 11380' 02-11 8305' - 8325' 115-12' 7D OR LwR /10SNAP-LATCH PKR D = 2.880• (05/21 ) 10778'5-1/2' OTD XA SLONG SLV, D = 4.562' 10788'-10808' 5-1/2' FES CR DWP SNGLEESET PATCH [)=2.987'(05/13/10) 19-5/8' X 5-12' BOT RHR PKR I 15-12' HES RCP WJI, D = 2.80' 10/14/98 TOP OF BKR SEAL BORE EXTENSDN BTM OF RCP SEAL ASSY. D = 2.803- X DD� 1147 rpf,D=4.892' 11476' MLLOUT WNDOW (02-11A) 11476'-11481' 11668' 3-3/16- X 2-7/8' XO, D = 2.375' FISH: MILLED & PUSHED CDP (2/1/19) 14112883- I 12883' = 2.375' I 13300' I DATE 112wT PERFORATION SUMMARY REF LOG: BHC ON 11/13!/7& MW ON 08/30/98 DATE 021=19 1 ANGLE AT TOP PEFV :43' @ 11187' Note: Refer to Production DB for historical pert data SIZE SPF NT AL Opn(Sgz DATE 2-12' 6 11187 - 11217 O 3/6/2018 2- 6 12035 - 12060 O 0223/11 2' 4 12420 - 12820 O 0926!96 2- 4 13000 - 13300 C 0926/98 FISH: MILLED & PUSHED CDP (2/1/19) 14112883- I 12883' = 2.375' I 13300' I DATE 112wT REV BY I COMMENTS JORMWAL COMPLETION DATE 021=19 1 REV BY DS/JMD I COMMENTS JMILLEDCIBP&SETFISH 0927198 CTD SIDETRACK 0220/19 DD/JMD ADDED OKE, REF, BF & EDBED FISH DEPTH 06/02/10 MV/PJC SET PATCH OV"10 072119 DD/JMD CORRECTED 2-7/8' LNR DEPTH 0227/11 JMF/PJC ADPERFS(0223/11) 03108/18 BTWJMD SETCBP&ADPERFS 03/12/18 BTN/JMD ADDNLNFO ON CBP 12-7Ai' WFRD C13P(05/15/04) 1 ::te„ 1 PRUDHOE BAYUNB WELL' 02-11A PERM] T No:'1981260 API No: 50-029-20273-01 SEC 36, T11 N, R14E, 921' FNL & 916' BP Exploration (Alaska) STATEOF ALASKA • S • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations Iv7 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate IZI Other Stimulate 0 Alter Casing 0 Change Approved Program d Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other:Set CIBP Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 198-126 3. Address: P.O.Box 196612 Anchorage, Development IZI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20273-01-00'. 7. Property Designation(Lease Number): ADL 028308,028311 8. Well Name and Number: PBU 02-11A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13337 feet Plugs measured 11576,12900 feet true vertical 9026 feet Junk measured 12884,13305 feet Effective Depth: measured 11576 feet Packer measured 10897 feet true vertical 8785 feet Packer true vertical 8278 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 26-106 26-106 1490 470 Surface 2687 13-3/8" 25-2712 25-2703 5380 2670 Intermediate 11453 9-5/8" 23-11476 23-8703 6870 4760 Production Liner 2308 3-1/2"x 3-3/16"x 2-7/8" 11026-13334 8373-9026 10160/10570 10530/11160 Perforation Depth: Measured depth: 11187-13300 feet True vertical depth: 8491-9029 feet Tubing(size,grade,measured and true vertical depth) 5-1/2"17#L-80 21-11476 21-8703 Packers and SSSV(type,measured and 5-1/2"BOT RHR Packer 10897 8278 true vertical depth) No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 368 33189 180 0 1289 Subsequent to operation: No Test Available 50 0 14.Attachments:(required per 20 AAc 25.070.25 071,&25.283) 15.Well Class after work: Daily Report of Well Operations WI Exploratory 0 Development 10 Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 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: N/A Authorized Name: Stone,Christopher Contact Name: Stone,Christopher Authorized Title: DS 2&18 PEel ��,, Contact Email: Christopher.Stone@bp.com Authorized Signature: Date: /SIA Contact Phone: +1 907 564 5518 Form 10-404 Revised 04/2017 vre 4!26410 RBDMS't►, APR 1 1 2016 Submit Original Only Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) April 5, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Set CIBP Plug and Perforate for Well PBU 02-11A, PTD #198-126. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • Daily Report of Well Operations PBU 02-11A ACTIVITYDATE SUMMARY ***ELINE PERFOROATING AND PLUG SET*** WELL S/I ON ARRIVAL, INITIAL T/I/O=2400/50/50 DHD SHOT FLUID LEVEL, FLUID AT PERFS, LRS PUMPED 255 BBLS DIESEL TO LOAD WELL RIH W/2.50" HSD 6SPF PJ OMEGA GUN, PERFORATE FROM 11187'-11217'. DEPTH CORRECTED TO SLB MCNL LOG DATED 23-SEPT-98. 3/6/2018 ***LAY DN FOR NIGHT, WELL SECURED, DSO NOTIFIED*** T/I/0=2400/60/60 Assist E-Line Load Tbg w/5 bbls 60/40, 250 bbls diesel. Capped w. 5 bbls 60/40. 3/6/2018 FWHP=400/50/60 Casing valves OTG, E-Line on location upon departure T/I/O =2410/30/50. Temp= SI. Tbg FL(e-line call-in). No AL. Tbg FL @ 12035' (top of pers, —265 bbls). 3/6/2018 SV, WV, SSV= C. MA= 0. IA, OA= OTG. 08:00 ***JOB CONTINUED FROM PREVIOUS DAY*** ELINE PLUG SET INITIAL T/I/O = 300/30/50 RIH W/WEATHERFORD 2.188"CIPB AND SET ME @ 11576'. CCL TO MID-ELEMENT= 9.8', CCL STOP DEPTH = 11566.2'. TOP OF PLUG 11575' RDMO, HAND OVER WELL TO DSO TO POP. FINAL T/I/O=250/30/50. DEPTH CORRECTED TO SLB MCNL LOG DATED 23-SEPT-98. 3/7/2018 ***JOB COMPLETE*** Fluids Summary Bbls Type 252 Diesel 10 60/40 Methanol TREE= 5-1/8"FARC •VVB_LFEAD= FMC • SAFETY NOTES:""" WELL ANGLE>70* 11774' ACTUATOR= AXELSON 02-11 A KB.ELEV= 56' BF.ELEV= CIL.ELEV_ 30 KOP= 2437' I 2076' H5-1/2-OTIS ROM SSSV NS),,D=4.562` Max Angle= 99"@ 13029' Datum MD= 1167T Datum WD= 8800'SS 1W10) I ■ 4326'-4360' 5-1/2"MVP PATCH,D--2.987"(05 13 3/8`CSG,721.hl 80.D=12.347" H 2711' I . - 8305'-8325' -5-1/2'WFD CR LWR SNAP-LATCH PKR Minimum ID =2.375" @ 11569' I • D=2.880'(05/21/10) 3-3/16" X 2-7/8" XO 'Al .... 10778' -I 5-1/2-OTIS XA SLDNG SLV,D=4.562" I EST.TOC(02/25/10) 10700' 141.E I I ve0 10788'-10808' 5-1/2"I-ES CR DWP SINGLE-SET PATCH 1i1t'�i ►�1�/�1 10=2.987"(05/13/10) 11,E 1.1 If 10876' -I 5-1/2"BOT PBR ASSY 1.I #.1 10897' ]-I 9-518'X 5-1/2'BOT RHR PKR i 11 11 111 TUBNG PUNCH(02/14/10) H 10800-10802 ,1�1� 1�11 1111(�� ��IAA 11021' 1-15-1/r FES RCP PKR,D=2.80"10/14/981 11111'1 1'1.01 11111.. 1�11111 3-1/2"BKR DEPLOY Malls SLV,D=3.00" H 11030' /A�1�t� ,?V 1!1!1 11026' -{TOP OF BKR SEAL BORE EXTENSION 1'1'1'1 r I :• 1111111 11111111 11030.6' -IBTM OF RCP SEAL ASSY.D=2.803" 1111111 1.1.1 1�1�1�1 ►v 7"s' 13-1/2"LMR,9.34,L-80,.0087 bpf,D=2.992" I--I 11380' 11380` 3-1/2"X 3-3/16"XO,D=2.800" 011'1. VI i'i'i - -I-� 11111111 411111 11111.11 0.1111 11111.1] .11.111] 11111.11 11141111 11111111 411111 9-5/8"f5[;,471,N-80,D=8.861' --I 11476' 1.11:1. 4.4'.1 MLLOUT VVNCOW (02-11A) 11476'-11481' 5-1/2"TBGPC,174,L-80..0232 bpf,D=4.892' H 11476' 11669' -13-3/16"X 2-7/8"XO,D=2.375" I 11575' H WFD 2.186"EXTRA RANGE CJBP(03/07/18) 3-3/16 LP,6.2a,L-80_0076 bpf,D=2.8 I-I 11669' 4., `I 12884' H NNLLED FASDRL(02/25/10) PERFORATION SUMMARY ` 12900' -I2-7/8"WFRD CLIP(05/15/04) RE=LOG:BHC ON 11/13/77&MND ON 08/30/98 ANGLE AT TOP FERE:436'@ 11187' .4 Note:Refer to Production OB for historical pert data 13305' I-CEP P I-ED SIZE SPF NTBRVAL Opn/Sgz DATE 2-1/2" 6 11187-11217 0 3/6/2018 PBTD H 13300' �.4\ TO BOTTOM 2" 6 12035-12060 C 02/23/11 2" 4 12420-12820 C 09/26/98 12-7/8"LMR,6.51,L-80 FL45,.0056 bpf,D=2.375" H 13334' 2" 4 13000-13300 C 09/26/98 ID--I 13337' DATE REV BY COMM NTS DATE REV BY COMVENTS PRUDI-IOE BAY INT 11/23/77 ORIGINAL COMPLETION 06/02/10' JVJM.) WFDSIZE CORRECTION WELL: 02-11A 09/27/98 CTD SIDETRACK 06/02/10 W/PJC SET PATCH(05/30/10) FERMI-No:r1981260 04/30/10 ?/PJC RLL PATCHES 02/27/11 .4/1F/PJC ADFERFS(02/23/11) API No: 50-029-20273-01 05/18/10 GJF/SV FISH(05110/10) 03/08/18 BTWJMD SET CBP&ADFERFS SEC 36,T11 N,R14E,921'FM_&916'Frit 05/18/10 JEIISV SET PATCH'FKR(05/13-14/10) 03/12/18 BT IJMD ADM_NFO ON CBP 05/30/10 MBMPJC SET UPPER PATCH(05/27/10) BP exploration(Alaska) - I I • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 i. , F I U /LTD Mr. Tom Maunder ail G �� Alaska Oil and Gas Conservation Commission ,� °� fit. ��riis 333 West 7 Avenue a,, s r Anchorage, Alaska 99501 t 2-6 Subject: Corrosion Inhibitor Treatments of GPB DS -02 ` \\ 1`` Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -086 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed C _ NA Sealed N/A NA NA 0 2 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 lionirwrirvrrwv Uaft U 3ltie3 STATE OF ALASKA iti"r.'Y"` ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1.1E+7 8 g 834 �i�! 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ,` owl 3j Performed: Alter Casing 12 Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time '" - "' n Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 ' Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 / Exploratory ❑ 198 -1260 - 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20273- 01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028311 - PBU 02 -11A- 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13337 - feet Plugs (measured) 12900 feet true vertical 9025.8 - feet Junk (measured) 13295 12884 feet Effective Depth measured 12900 feet Packer (measured) 4326 4350 8305 8325 10788 10808 1089711021 true vertical 9061.5 feet (true vertical) 4002 4017 6485 6498 8198 8213 8278 8369 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 25 - 105 25 - 105 1490 470 Surface 2687' 13- 3/8 "72# L -80 24 - 2711 24 - 2702 4930 2670 Intermediate 11453' 9 -5/8" 47# N -80 23 - 11476 23 - 8703 6870 4760 Production 354' 3 -1/2" 9.3# L -80 11026 - 11380 8372 - 8632 10160 10530 Liner 189' 3- 3/16" 6.2# L -80 11380 - 11569 8632 - 8779 Liner 1765' 2 -7/8" 6.5# L -80 11569 - 13334 8779 - 9026 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 22 - 11476 22 - 8703 Packers and SSSV (type, measured and true vertical depth) 5 -1/2" DWP PATCH PKR 4326 4350 4002 4017 5 -1/2" WFD CR LWR SNAP -LATCH PKR 8305 8325 6485 6498 5 -1/2" HES CR DWP SINGLE -SET PATCI- 10788 10808 8198 8213 9 -5/8" X 5 -1/2" BOT RHR PKR 10897 8278 5 -1/2" HES RCP PKR 11021 8369 12. Stimulation or cement squeeze summary: Intervals treated (measured): MAR Treatment descriptions including volumes used and final pressure: 3 Et.) MAR 1 2 0 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory0 Development el - Service ❑ Daily Report of Well Operations X 16. Well Status after work: Oil IO - Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ SPLUG ❑ 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: NA Contact Joe Lastufka Printed Na e •e L i stu - r Title Data Manager I Signat e i Phone 564 -4091 Date 2/28/2011 I 14 Rcvioc 009 3uhnnt Oi l Only 02-11A " 198 -126 PERF ATTACHMENT - Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02 -11A 9/26/98 PER 12,420. 12,820. 9,049.64 9,060.84 02 -11A 9/26/98 PER 13,000. 13,300. 9,058.82 9,029.09 02 -11A 1/10/02 BPS 11,680. 13,000. 8,858.46 9,058.82 02 -11A 1/21/02 BPP 12,420. 13,295. 9,049.64 9,029.53 02 -11A 5/15/04 BPS 12,900. 13,000. 9,061.48 9,058.82 02 -11A 6/7/09 BPS 11,585. 12,900. 8,791.72 9,061.48 02 -11A 6/13/09 SQZ 10,700. 11,585. 8,134.24 8,791.72 02 -11A 2/23/10 SQZ 10,975. 11,585. 8,335.34 8,791.72 02 -11A 2/25/10 BPP 11,585. 12,900. 8,791.72 9,061.48 02 -11A 2/26/10 BPS 12,900. 20 J 13,000. 9,061.48 9,058.82 02-11A 2/23/11 APF 12,03Q 4' " 12,065 8,984.24 8,989.8 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • i • • 02 -11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 2/21 /20111 CTU #9, 1.75" CT, 0.134" wall; ADD -PERF : Drift coil with ball, BOP Test !Go on weather stand by at 16:00 I ** *Continued on 2/22/11' j � I 2/22/2011 CTU #9 Job Scope = Tie in Log, Add Perf ** *Continued from 2/21/11*** Logged from 12650' - 12050, Flagged Pipe, Logged up to 11500' POOH 99 99 P 99 P ** *Job contiunued on 2/23/11 * ** 3 I 2/23/2011 CTU 9, 1.75" CT, 0.134" wall: ADD -PERF ** *Continued from 2/22/11 * ** Perforated: 1z03�' -2065' w/ 2.0" PJ perf gun, 6spf, 60deg phase. ; ** *Job Complete * ** FLUIDS PUMPED BBLS 71 60/40 McOH 71 TOTAL TREE = 5-1/8" FMC • SAFETY NO. * ** WELL ANGLE > 70° @ 11774' WELLHEAD = FMC 02-1 1 A ACT�ATOR = AXELSON KB. ELEV = 56' - BF. ELEV . GL ELEV = 30' 1 2075' H5 -1/2" OTIS ROM SSSV NIP, ID = 4.562" I KOP = 2437' Max Angle = 99 © 13029' Datum MD = 11677' Datum TVD = . 8800' SS 4326' - 4350' 1-15-1/2" DWP PATCH, ID = 2.987" (05130/10) 1 (13 -3/8" CSG, 72 #, N-80, ID = 12.347" I — ) 2711' ill .I 8305' - 8325' I — 5 -1/2" WFD CR LWR SNAP -LATCH PKR Minimum ID = 2.375" @ 11569' I I ID = 2.880" (05/21/10) 3- 3/16" X 2 -7/8" XO 1�.y4 '.; 10778 H5 -1/2 OTIS XA SLIDING SLV, ID = 4.562" I 'EST. TOC (02/25/10) 1 10700' I ����, 1 0788' - 10808' — 5 -1 /2" HES CR DWP SINGLE-SET PATCH t 4 ID = 2.987" (05/13/10) ) .4 10875' H 5-1/2" BOT PBR ASSY I 10897' 1 X 5 -1/2" BOT RHR PKR 11 'TUBING PUNCH (02 /14/10) 1 10800 - 10802 � 1*1 A; 11021' — 15 -1/2" HES RCP PKR, ID = 2,80" 10/14/98 X 1111 111 13 -1 /2" BKR DEPLOYMENT SLV, ID = 3.00" 11030' ►31 1�1�1 11026' I — { TOP OF BKR SL BORE EXTENSION 11'1 • r� . 111 1 ►l1 11030.5' — OF RCP SEAL ASSY, ID = 2.803" 1 1•1• 1 ►� X •1 1 I 1 1 1.1 14 X 1+11 3 -1/2" LNR, 9.3 #, L -80, .0087 bpf, ID = 2.992" (—I 11380' I a 1 1 1 1. ■ 4 CIO •ti 1' •I'it• 11380' — 13 -1/2" X 3- 3/16" XO, ID = 2.800" I .011 1 1 1 1 1 ► 1 11 1 1 1 1 .0* 04* 1• ►1111 1 X1 4 1 1 1 1 1 1 1 1 1 4 1 ••1 04* 1/ I9 -5/8" CSG, 47 #, N -80, ID = 8.861" H 11476' }-- /1/1111 1∎ X1 MIL LOUT WINDOW (02 -11A) 11476'- 11481' 5 -1/2" TBG- PC,17 #, L -80, .0232 bpf, ID = 4.892" 1-1 11476' 11569' I—I3- 3/16" X 2 -7/8" XO, ID = 2.375" I 1 3-3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.8" I-1 11569' I ` 12884' ( I J MILLED FASDRIL (02 /25/10) 1 PERFORATION SUMMARY \ 12900' — I2 -7/8" WFRD CIBP (05 /15/04) 1 REF LOG: BHC ON 11/13/77& MWD ON 08/30/98 A P ANGLE AT TOP PERF: 76° © 12035' ` Note: Refer to Production DB for historical perf data 13305' 11 CIBP PUSHED SIZE SPF INTERVAL Opn /Sqz DATE i �4\ TO BOTTOM 2" 6 12035 - 12060 0 02/23/11 I PBTD 1-1 13300' r N. 2" 4 12420 - 12820 0 09/26/98 2" 4 13000 - 13300 C 09/26/98 `2-7/8" LNR, 6.5 #, L -80 FL45, .0056 bpf, ID = 2.375" I-I 13334' TD — 1 13337' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/23/77 ORIGINAL COMPLETION 06/02/10 JVJMD WFD SIZE CORRECTION WELL: 02 -11A 09/27/98 CTD SIDETRACK 06/02/10 MV /PJC SET PATCH (05/30/10) PERMIT No: '1981260 04/30/10 ?/ PJC PULL PATCHES 02/27/11 JMF /PJC ADPERFS (02/23/11) API No: 50- 029 - 20273 -01 05/18/10 GJF /SV FISH (05/10/10) SEC 36, T11 N, R14E, 921' FNL & 916' FWL 05/18/10 JED /SV SET PATCH/PKR (05/13- 14/10) 05/30/10 MBM/PJG SET UPPER PATCH (05/27/10) BP Exploration (Alaska) STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Q TUBING PATCH Pertormed: Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver^ Time Extension ^ 4326'-4350' Change Approved Program ^ Operat. Shutdown ^ Pertorate ^ Re-enter Suspended Well ^ 8305'-8325' 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 198-1260 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20273-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number. ADLO-028311 PBU 02-11A 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13337 feet Plugs (measured) 12900' 13305' feet true vertical 9025.8 feet Junk (measured) 12884 feet Effective Depth measured 12900 feet Packer (measured) 4324 4344 8303 true vertical 9061.5 feet (true vertical) 4000 4013 6484 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 25 - 105 25 - 105 1490 470 Surtace 2687 13-3/8" 72# N-80 24 - 2711 24 - 2702 4930 2670 Intermediate 11453 9-5/8" 47# N-80 23 - 11476 23 - 8703 6870 4760 Production 354 3-1/2" 9.3# L-80 11026 - 11380 8273 - 8632 10160 10530 Liner 189 3-3/16" 6.2# 11380 - 11569 8632 - 8779 Liner 1765 2-7/8" 6.5# L-80 11569 - 13334 8779 - 9026 10570 11160 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 21 - 11476 21 - 8703 4-1 /2" 12.6# L-80 4324 - 4349 4029 - 4017 4-1/2" 12.6# L-80 8303 - 8326 6484 - 6500 Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES DWP Patch Packer 4324 4000 4-1/2" HES DWP Patch Packer 4344 4013 t1 j~s w~ ~i ~~ L ~~~ ~k~ti:~S y 4-1/2" HES DWP Patch Packer 8303 6484 . s ~ 4-1/2" HES DWP Patch Packer 8322 6496 5-1/2" HES RCP PKR 11021 8369 5-1/2" BOT RHR PKR 10897 ~~~~„ ~~ 12. Stimulation or cement squeeze summary: f 11 C ~ ~ ~ T U U J Intervals treated (measured): L 1 ee f/f~,,~~ l~ig e0i'11D11SSI l11i~i{R~ ~qq 0t Ga: C Treatment descriptions including volumes used and final pressu re: i . M~iMar~ e 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 1 Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 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: 309-132 Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature t ~ ~ ~ Phone 564-4944 Date 7/15/2010 02-11 A 19126 ~C~C ATT Af'`1.111A CIJT u Sw Name Operation Date Perf Operation Code Meas,Depth Top Meas Depth Base Tvd Depth To Tvd Depth Bas 02-11A 9/26/98 PER 12,420. 12,820. 9,049.64 9,060.84 02-11A 9/26/98 PER 13,000. 13,300. 9,058.82 9,029.09 02-11A 1/10/02 BPS 11,680. 13,000. 8,858.46 9,058.82 02-11A 1/21/02 BPP 12,420. 13,295. 9,049.64 9,029.53 02-11A 5/15/04 BPS 12,900. 13,000. 9,061.48 9,058.82 02-11A 6/7/09 BPS 11,585. 13,000. 8,791.72 9,058.82 02-11A 6/13/09 SQZ 10,700. 11,585. 8,134.24 8,791.72 02-11A 2/23/10 SQZ 10,975. 11,585. 8,335.34 8,791.72 02-11A 2/25/10 BPP 11,585. 12,900. 8,791.72 9,061.48 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVE SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ • 02-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/3/2010 "'"'WELL SHUT IN ON ARRIVAL**"(pre patch) ' CURRENTLY RIGGING UP SWCP 4517 ***CONT WSR ON 5/4/10*"* 5/4/2010 *""CONT WSR FROM 5/3/10"**(pre patch) ~ RAN 3" P-BAILER TO FISH AT 10,976'SLM.(bailer empty) RAN 4.50" BELL GUIDE W/ 3.80" MAGNET TO FISH AT 10,976'SLM. (recovered metal shavings) RAN 3.70 BOX TAP TO FISH @ 10,976' SLM, UNABLE TO RECOVER FISH RAN 4.50" BELL GUIDE, 3.80" MAGNET TO FISH @ 10,976' SLM (recovered metal shavings) ARAN 3.70" WIRE GRAB TO FISH @ 10,976' SLM, UNABLE TO RECOVER FISH RAN 3.80"CENT3.63" 2 PRONG BOX TAP TO FISH AT 10,976'SLM.(unable to recover fish) CURRENTLY RIH W/ 3.45"DECENT,3.60"LIB. ""*CONT WSR ON 5/5/10''"* ~~ ~~.__ 5/5/2010 *''"CONTINUED FROM 5/4/10 WSR***(Pre patch) __.__.___ RAN 3.60" L.LB. ON DECENTRALIZER TO FISH @ 10,976' SLM (No impression). RAN 3.25" P-BAILER W/ 3.50" FINGER BASKET TO 10,976' SLM (--3 cups of sand /metal pcs.) I RAN 3.00" & 3.25" L.I.B. TO FISH @ 10,976' SLM (Impression offish laying ~ sideways in tbg). j RAN 3.63" 2 -PRONG BOX TAP TO 10,976' SLM (No recovery, small amount of unset cement in box tap). CURRENTLY RIH W/ 4.50" BELL GUIDE, 2.50" MAGNET (Magnet sticking out '. bell guide 9-3/8"). *"*JOB IN PROGRESS, CONTINUED ON 5/6/10 WSR""" 10 '***CONTINUED FROM 5/5/10 WSR***(Pre patch) 'RAN 2.50" MAGNET TO FISH @ 10,976' SLM (Nothing recovered). RAN 2.50" L.I.B. ON DECENTRALIZER TO FISH @ 10,976' SLM. (impression of flute @ 9 o'clock) MADE MULTIPLE RUNS WITH 1-7/8" ALLIGATOR GRAB WITHOUT !SUCCESS. CURRENTLY IN HOLE W/ 2.625" 1 -PRONG WIRE GRAB @ 10,976' SLM. (*'`*JOB IN PROGRESS, CONTINUED ON 5/7/10 WSR*** • • 5/7/2010 ***CONTINUED FROM 5/6/10 WSR***(Pre patch) RAN 3.50" MAGNET TO FISH AT 10,976' SLM (No recovery). RAN 4.50 LIB TO FISH AT 10,976' SLM (inconclusive). RAN 2.50 LIB TO FISH AT 10,976' SLM (bullnose still appears to be @ 9 o'clock). *"* WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS.**" "**""*" TAG HANGING ON WING FOR FISH LEFT IN HOLE.""""""* 5/10/2010 ~ "*"W ELL S/I ON ARRIVAL***(pre patch) RAN 4.50" G-RING TO 10,976' SLM, ABLE TO WORK TOOLS TO 10,978' jSLM. RAN 2.50" HYDROSTATIC BLR, 3.50" FLAT BOTTOM TO 10,980' SLM. RECOVERED -4 CUPS OF CEMENT & BULL NOSE FROM JUNK BASKET WEDGED IN BLR BOTTOM. CURRENTLY RIH W/ 3.60" L.I.B. TO TAG 5-1/2" HES RCP PKR @ 11,021' MD. ***JOB IN PROGRESS, CONTINUED ON 5/11/10 WSR*** 5/11/2010. ""*CONTINUED FROM 5/10/10 WSR***(pre patch) RAN 3.60" L.I.B. TO 10,979' SLM, UNABLE TO GET IMPRESSION OF 5-1/2" =HES RCP PKR. RAN 3.71" G-RING TO 10,980' SLM, UNABLE TO MAKE ANY HOLE. RAN 3.50" PUMP BAILER TO 10,980' SLM (recovered --2 cups coarse dirt). gBROKE THRU BRIDGE @ 11,010' SLM, DRIFT TO 11,300' SLM W/ 2.25" x 5' DRIVE DOWN BAILER. RAN 2.25" CENT, S-BLR TO 11,675' SLM, STOPPED DUE TO DEVIATION ~ (No issues). ..DRIFT TO 10,975' SLM W/ 5-1/2" x 27' HES DWP DUMMY PATCH (No issues). ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 5/13/2010.***WELL SHUT-IN UPON ARRIVAL***(ELINE: PATCHES) 'INITIAL T/I/0= 320/ 0/150 . SSV/SWABNVING-C, MASTER-O, IA/OA-OTG, RIH WITH 1ST HES 5.5" DWP PATCH. SET DOWN AT 7480' @ 100FPM. PASSED @ 150FPM. 'SET 1ST HES 5.5" DWP PATCH AT 10788-10808'. SAT DOWN WITH 2ND HES 5.5" DWP PATCH AT 7485' @ 100FPM. ATTEMPT TWICE MORE @ 150 FPM AND SET DOWN SAME PLACE BOTH TIMES. POOH TO CHECK PATCH AND SETTING TOOLS. *"*JOB CONTINUED ON 14-MAY-2010*"* ® 5/14/2010 T/I/0=300/0/100. (Displace tbg w/ crude & 776 mixture for E-line). Speat into tbg w/ 5 bbls neat meth followed by 96 bbls crude & 776 mixture. Pump additional 101 bbls crude to spot mixture at desired depth for E- Line to set patch. Pump crude down tbg as directed to assist E-line. FWHP=200/0/200. E-Line still on well upon LRS departure. • 5/14/2010 '""`JOB CONTINUED FROM 13-MAY-2010***(ELINE: PATCHES) RAN JUNK BASKET WITH 3.5" GAUGE RING. PERFORMED MAN DOWN DRILL. DECISION MADE TO RUN WEATHERFORD 2-PART PATCH. I SET WEATHERFORD 4.50" CROME LOWER PACKER OF 20' PATCH. SET DEPTH: 8325'. CCL TO MID-ELEMENT: 15.5'. CCL STOP DEPTH: 8309.5' ""*JOB CONTINUED ON 15-MAY-2010*'"'" 5/15/2010 5/26/201( **"JOB CONTINUED FROM 14-MAY-2010"**(ELINE: PATCHES) RIG DOWN AND MOVE OUT. SSV/SWAB/WING-C, MASTER-O, IA/OA-OTG, FINAL T/i/O 80/15/200 ***JOB ON HOLD FOR SL TO INSTALL UPPER PATCH. WELL LEFT SI.*** ___. __.~ ***WELL S/I ON ARRIVAL*** (tbg patch) DRIFT TO LOWER PATCH ANCHOR @ 8312' SLM W/ 4.535" WRP DRIFT ""'CONTINUED ON 5/27/10 WSR""" 5/27/2010!***CONTINUED FROM 5/26/10*** (tbg patch) (SET 5-1/2" WEATHERFORD PATCH @ 8305' - 8325' ***WELL S/I ON DEPARTURE"*'" 5/28/2010°"'"'"WELL SHUT IN ON ARRIVAL.*** (ELINE SET PATCH) BEGIN SPOTTING IN EQUIPMENT. *""JOB CONTINUED ON 29-MAY-2010.*"" a • 5/29/2010'. T/I/0=0/0/160 temp=s/i MIT IA PASSED to 3000 psi (set tbg patch) Pump 8 bbls crude down IA to reach test pressure. IAP lost 120 psi 1st 15 min, IAP lost 80 psi 2nd 15 min. FAIL. pump .4 bbls to repressure. IAP lost 60 psi 1st 15 min, IAP lost 20 psi 2nd 15 min PASS FWHP's=0/0/160 SV, WV=S/I SSV, MV=O IA, OA=OTG Tag Hung, DSO notified at departure. 5/29/2010 ***JOB CONTINUED FROM 28-MAY-2010."** INITIAL T/I/O: 30/0/150 PSI. RIH WITH 5.5" HES DWP 20' PATCH. OD = 4.53" ID = 2.987'. OAL OF TOOLSTRING = 42' WEIGHT = 800 LB. TIED INTO TUBING PUNCH AT 4338'. SET PATCH AT 4330-4350'. LRS MIT-IA TO 3000 PSI PASSED. "**JOB COMPLETE*** FLUIDS PUMPED BBLS 12 METH 2 DIESEL 24 Total TREE= 5-1/8" FMC WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 56' BF. ELEV = GL. ELEV = 30' KOP = 2437' Max Angle = 99 @ 13029' Datum MD = 11677' Datum TV D = 8800' SS ~ 02-11 13-3/8" CSG, 72#, N-80, ID = 12.347" I~ 2711' Minimum ID = 2.375" @ 11569' 3-3/16" X 2-7/8" XO EST. TOC (02/25/10) 10700' TUBING PUNCH {02/14/10) I-I 10$00-10802 3-1/2" BKR DEPLOYMENT SLV, ID = 3.00" I-1 11030' 3-112" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" I~ 11380' 9-5/8" CSG, 47#, N-80, ID = 8.861" I-j 11476' f- 5-1/2" TBG-PC,17#, L-80, .0232 bpf, ID = 4.892" 11476' 2075' -{5-1/2" OTIS ROM SSSV NIP, ID = 4.562" 4326' -4350' S-1/2" DWP PATCH, ID = 2.987" {05/3011 8305' - 8325' 5-1/2" WFD CR LWR SNAP-LATCH PKR ID = 2.880" (05!21/10) 1077$' 5-1/2" OTIS XA SLIDING SLV, ID = 4.562" 10788'-10808' 5-1/2" HES CR DWP SINGLE-SET PATCH ID - 2.987" {05/13/10) 10875' 5-1/2" BOT PBR ASSY 10897' 9-5/8" X 5-112" BOT RHR PKR 11021' -j 5-1/2" HES RCP PKR, ID = 2.80" 10/14!98 11026' TOP OF BKR SEAL BORE EXTENSION 103 BTM OF RCP SEAL ASSY, ID = 2.803" 380' I-13-112" X 3-3/16" XO, ID = 2.800" MILLOUT WINDOW (02-11A) 11476'-11481' 11569' I-~ 3-3116" X 2-7/8" XO, ID = 2.375" 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.8" ( PERFORATION SUMMARY REF LOG: BHC ON 11/13/77 ANGLE AT TOP PERF: $9 @ 12420' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12420 - 12820 O 09/26/98 2" 4 13000 - 13300 C 09(26(98 12884' -{MILLED FASDRIL (02/25/1 12~-I 2-7/8" WFRD CIBP (0 3305, I~ CIBP PUSHED I TO BOTTOM PBTD 13300' 2-7/8" LNR, 6.5#, L-80 FL45, .0056 bpf, ID = 2.375" -r I 13337' I DATE REV BY COMMENTS DATE REV BY COMMENTS 11/23/77 ORIGINAL COMPLETION 06/02/10 JUJMD WFD SIZE CORRECTION 09!27/98 CTD SIDETRACK 06/02/10 MV/PJC SET PATCH (05/30/10) 04/30/10 ?/ PJC PULL PATCHES 05/18/10 GJF/SV FISH (05110/10) 05/18/10 JED/SV SE? PATCWPKR (05/13-14/10) 05/30/10 MBMIPJC SET UPPER PATCH (05/27/10) PRUDHOE BAY UNIT WELL: 02-11A PERMfT No: 1981260 API No: 50-029-20273-01 SEC 36, T11 N, R14E, 921' FNL & 916' FWL BP 6cploration (Alaska) STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate^ Other Q Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ PKR Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-ent Suspended Well ^ S UEEZE 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^~ Exploratory ^ 198-1260 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20273-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Numbe ADLO-028311 PBU 02-11A 10. Field/Pool(s): \ PRUDH OE BAY FIELD 7 PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13337 feet Plugs (measured) 12900' 11184' feet true vertical 9025.8 feet Junk (measured) 13305 feet Effective Depth measured 12900 feet Packer (measured) 4324 4344 8303 true vertical 9061.5 feet (true vertical) 4000 4013 6484 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 25 - 105 25 - 105 1490 470 Surface 2687 13-3/8"72# N-80 24 - 2711 24 - 2702 4930 2670 Intermediate 11453 9-5/8" 47# N-80 23 - 11476 23 - 8703 6870 4760 Production 354 3-1/2" 9.3# L-80 11026 - 11380 8273 - 8632 10160 10530 Liner 189 3-3/16" 6.2# 11380 - 11569 8632 - 8779 Liner 1765 2-7/8" 6.5# L-80 11569 - 13334 8779 - 9026 10570 11160 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 21 - 11476 21 - 8703 4-1 /2" 12.6# L-80 4324 - 4349 4029 - 4017 4-1/2" 12.6# L-80 8303 - 8326 6484 - 6500 Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES DWP Patch Packer 4324 4000 4-1/2" HES DWP Patch Packer 4344 4013 q~; ~ ~ 4-1/2" HES DWP Patch Packer 8303 6484 ~ ct ~~ ilY ~..~~ N °e °~~+j4,.~.~ Li ~ w -- 4-1/2" HES DWP Patch Packer 8322 6496 5-1/2" HES RCP PKR 11021 8369 5-1/2" BOT RHR PKR 1089 ~~~ Y 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~c ~~ ~ d e~U~ ~ Treatment descriptions including volumes used and final pressu t ~ .,,,~ ~ re: A ~ ~ 6~ yw~a. ~ptYN1'IISSt0l1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 't~. Well Class after work: Copies of Logs and Surveys Run \ Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 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: 309-132 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 7/14/2010 02-11 A PFRF oTTAC~..NENT • Sw Name Operation Date. Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth To Tvd Depth Bas 02-11A 9/26/98 PER 12,420. 12,820. 9,049.64 9,060.84 02-11A 9/26/98 PER 13,000. 13,300. 9,058.82 9,029.09 02-11A 1/10/02 BPS 11,680. 13,000. 8,858.46 9,058.82 02-11A 1/21/02 BPP 12,420. 13,295. 9,049.64 9,029.53 02-11A 5/15/04 BPS 12,900. 13,000. 9,061.48 9,058.82 02-11A 6/7/09 BPS 11,585. 13,000. 8,791.72 9,058.82 02-11A 6/13/09 SQZ 10,700. 11,585. 8,134.24 8,791.72 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVE SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE L_ J • i 02-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/16/2009 ***''WELL S/I ON ARRIVAL****(pre pkr sqz) .RECOVERED FISH FROM PREVIOUS JOB ' ATTEMPT TO EQUALIZE WRP @ 11,184' MD PULL WFD WRP PULLING TOOL FROM 11,166' SLM TROUBLESHOOT LEAKING SWAB **"CONTINUED ON WSR 05/17/09"** I ` 5/17/2009 "*"CONTINUED FROM WSR 05/16/09*"" (pre pkr sqz) RAN 10' x 2.50" PUMP BAILER TO 11,166' SLM (RECOVERED -1 1/2 GAL z PARRAFIN) SWAB WILL NOT HOLD, JOB DELAYED WILL RETURN WHEN SWAB REPLACED I i i "**WELL LEFT S/I, DSO NOTIFIED OF STATUS*** 5/21~ T/I/O = 0/620/350 Set BPV pulled swab valve put on B-cond. swab valve. Put grease fittings in master and SSV. Pulled BPV set TWC . P/T to 5,000# PASS. Pulled TWC. _ _ 5/22/2009 _ _ **''WELL S/I ON ARRIVAL"** (pre pkr sqz) BAILED APPROX. 1-1/2-- GALLONS OF ASPHALTINES FROM 11,144' SLM TO 11,155' SLM j CURRENTLY ATTEMPTING TO WORK BAILER PAST PATCHES & I CONTINUE BAILING ASPHALTINES ""'* ***CONTINUE WSR ON 5/23/09 • • 5/23/2009 *"*CONTINUE WSR FROM 5/22/09"** (pre pkr sqz) BAILED APPROX. -5 CUPS ASPHALTINES FROM 11197' SLM TO 11199' SLM CURRENTLY ATTEMPTING TO PULL WRP @ 11050' SLM **"CONTINUE WSR ON 5/24/09**" 5/24/2009 "*"CONTINUE WSR FROM 5/23/09*** (pre pkr sqz) RAN ASSORT OF BAILERS TO CLEAR FILL OFF OF WRP @ 11048' SLM (APPROX. -2 CUPS OF ASPHALTINES) ABLE TO LATCH WRP W/ 3 1/2" GR BUT HAD TO BEAT DOWN, GR NOT SHEARED CURRENTLY RUNNING IN W/ 2.25" PUMP BAILER W/SNORKEL BOTTOM "**CONTINUE WSR ON 5/25/09*** 5/25/2009 ***CONTINUE WSR FROM 5/24/09**" (pre pkr sqz) MADE MULTIPLE ATTE_MP_T_S TO PULL 3 1/2 WRP FROM 11048' SLM (UNABLE TO LATCH DUE TO ASPHALTINES) RAN ASSORT OF BAILERS TO CLEAR FILL FROM WRP @ 11048' SLM CURRENTLY ATTEMPTING TO 5' x 1.75" DRIVE DOWN BAILER PAST UPPER PATCH @ 4346' SLM **"CONTINUE WSR ON 5/26/09*"* 5/26/2009"**CONTINUE WSR FROM 5/25/09*** (pre pkr sqz) BAILED APPROX. -2 CUPS ASPHALTINE FROM 11048' SLM MADE SEVERAL ATTEMPTS TO PULL 3-1/2"WRP @ 11048' SLM ""*CONTINUE WSR ON 5/27/09*** 5/27/2009'***CONTINUE WSR FROM 5/26/09*** ;ATTEMPT TO PULL 3 1/2" WRP ""'"*JOB NOT COMPLETE'"*** ***LEFT WELL SHUT IN, PLUG IN HOLE, NOTIFIED PAD OP ON DEPARTURE** i • • 6/4/2009 **"W ELL S/I ON ARRIVAL""" JARRED -5HRS ON 3-1/2"WRP AT 11,032'SLM. WRP MOVING UP/DOWN -11'. ***JOB CONTINUED ON 6/5/09*** 6/5/2009.'"*"JOB CONTINUED FROM 6/4/09"*" JARRED UP ON 3-1/2"WRP -5 HRS. WRP APPEARS TO BE MOVING UP/DOWN -2'. ATTEMPTED TO FREE UP WRP BY PUMPING HOT DIESEL/CRUDE WHILE JARRING. ***JOB CONTINUED ON 6/6/09""' 6/5/2009 (continued from 6/04/09) T/I/0=2450/1080/240 Assist wireline by pumping down tbg.Pumped 3 bbls neat, 50 bbls of 180*F diesel and 277 bbls of 180*F 'crude down the tubing while slickline attempted to pull a WRP. Final WHP= X900/1200/300. slickline on well at departure 6/6/2009 T/I/0=1380/1250/280 Temp=S/I Assist slickline w/ Load & Kill Pumped 280 bbls of 120'` crude down TBG Continues Bleeding IA psi @ 200 bbls away Final Whp's=680/1660/200 ',Wing shut swab open ssv open casing valves open to gauge's 6/6/2009~"""JOB CONTINUED FROM 6/5/09*** PULLED 3-1/2"WRP @ 11 083' BLM (MISSING ONE ELEMENT~_ DRIFT TO PATCH @ 4359' SLM W/5-1/2" BRUSH, 3.70" 3-PRONG GRAB (NO RECOVERY). DRIFT TO DEV @ 11,764' SLM W/2-7/8" BRUSH & 2.20" 3-PRONG GRAB (NO RECOVERY). i TAG 2-7/8" XO 11,596'SLM FOR DEPTH TIE IN W/ 2.70" CENT, 2.50" LIB (PIC OF XO). RIH TO SET 2-7/8" HES FASDRIL VIA HES ETD, UNABLE TO PASS PATCH AT 4351'SLM. i *""CONT ON 06-07-09 WSR*** • 6/7/2009***JOB CONTINUED FROM 6/6/09""* (pre pkr sqz) UNABLE TO PASS UPPER PATCH @ 4351' SLM W/HES ETD & 2-7/8" FASDRILL SET HES 2-7/8" FASDRIL (2.18" ODl W/ BULLNOSE VIA HES ETD t~ TURNED OVER TO DSO*"* 6/11/2009 CTU #6, Cmt. Sqz.; MIRU CTU #6. Perform chain inspection. Cement in .test. Cont' on WSR 06/12/09 .... 6/12/2009 CTU #6, Cmt Sqz; Cont' from WSR 6-11-09 ... Waiting on cement test results. Results good. MU and RIH with 2.0" BDN. Fluid pack well with 425 ~ ~ bbls of 1 % KCL. Bull head 200 bbls of diesel down coil back side. Mix barite pill, pump 4.5 bbl, 16 ppg barite pill above composite plug up to 11045' ctm. '.Park coil. batch up cement. Cont' on WSR 6/13/09 ... i NOTE: Gel/Barite Pill consisted of 1.5 ppb of Geovis (ECF612) blended in the pumpers tub with 3.33 bbls of fresh water. Barite was then mixed in until a weight of 16 ppg was reached (50 - 50# sacks) yielding a 5 bbl pill. 6/13/2009.; CTU #6, Cmt Sqz; Cont' from WSR 6-12-09 ... Batch mixed cement on location. Pump 31 bbls squeezeCrete cement, 8 bbls LARC cement total of 39 bbls pumped. (+ 200 psig pressure bump). PUH to safety @ 9200' ctm. Wait 1 hr. switched to Biozan. RIH washed down to 11100' ctm. POOH washing tubing @ 80 % running speed . Wash across jewelry on way OOH. FP well with 50/50 to 2000'. At surface with coil, closed swab valve trapping 500 psi WHP. RD. "'"' Job Complete "*" 6/23/2009 T/I/0=600/1360/280 temp=S1 [IOR] Attempt MIT Tubing 3000 psi. Rigged up to companion valve, pumped 15 bbls 80" crude down TBG. IA tracking w/TBG. Bled IA to eliminate gas. Pumped additional 68 bbls crude down tubing to pressure up Tx IA. Unable to MIT Tubing due to communication between Tx IA. **Continued on 6-24-09*` • 6/24/2009*"Continued from 6-23-09*" CMIT TxIA 3000 psi PASSED. Pumped 5.3 bbls (88.3 total) 60° crude down Tubing to pressure up Tx IA to 3000 psi. T/IA lost X50/40 psi in 15 min's, 20/40 psi in 2nd 15 min's, 0/0 psi in 3rd 15 min's for a total loss of 20/40 psi in last 30 min's. Bled back approx. 10 bbls. Rigged up to IA and pumped 9 bbls crude to reach test pressure. T/IA lost 40/60 in 15 min's, 20/20 in 2nd 15 min's for a total loss of 60/80 in 30 min's. Bled back approx 11 bbls. '"*Swab, Wing, SSV valves closed- Master, IA, OA valves open on departure** FWHP's= 200/600/280 FLUIDS PUMPED BBLS 4.5 BARITE 3 NEAT 80 BIOZAN 121 50/50 METH 639 1 % KCL 257 DIESEL 1104.5 Total TREE= 5-1/8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 56' BF. ELEV = GL. ELEV = 30' KOP = 2437' Max Angle = 99 @ 13029' Datum MD = 11677' Datum TV D = 8800' SS ~ 02-11 2075' I--I 5-1(2" OTIS ROM SSSV NIP, ID = 4.562" 13-318" CSG, 72#, N-80, ID = 12.347" ( 2711' Minimum ID = 2.375" @ 11569' 3-3116" X 2-718" XO EST. TOC (02(25110) 10700 (TUBING PUNCH {02/14110) ( 3-1/2" BKR DEPLOYMENT SLV, ID = 3.00" I-{ 11030' ~ 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" I ~9-518" CSG, 47#, N-80, ID = 8.861" ~--~ 11476' f-- 5-1/2" TBG-PC,17#, L-80, .0232 bpf, ID=4.892" 11476' 3-1/2" X 3-3/16" XO, ID = 2.800" MILLOUT WINDOW (02-11A) 11476'-11481' 11569' I~ 3-3/16" X 2-718" XO, ID = 2.375" 3-3116" LNR, 6.2#, L-80, .0076 bpf, ID = 2.8" ~ 11569' PERFORATION SUMMARY REF LOG: BHC ON 11/13177 ANGLE AT TOP PERF: 89 @ 12420' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12420 - 12820 O 09/26/98 2" 4 13000 - 13300 C 09/26/98 12$84' -i MILLED FASDRIL (02/25/10) 12900" 2-718" WFRD CIBP (05/15104) CIBP PUSHED I TO BOTTOM PBTD 13300' 2-7/8" LNR, 6.5#, L-80 FL45, .0056 bpf, ID = 2.375" 13334' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/23/77 ORIGINAL COMPLETION 06/02!10 JUJMD WFD SQE CORRECTION 09/27/98 CTD SIDETRACK 06/02/10 MV/PJC SET PATCH (05/30110) 04/30/10 ?/ PJC PULL PATCHES 05/18!10 GJF/SV FISH (05/10/10} 05/18!10 JEDlSV SET' PATCH/PKR (0511 3-1 4/1 0) 05/30/10 MBMfPJC SET UPPER PATCH (05/27/10) PRUDHOE BAY UNIT WELL: 02-11A PERMfT No: 1981260 API No: 50-029-20273-01 SEC 36, T11 N, R14E, 921' FNL & 916' FWL BP Exploration (Alaska} 4326` -4350` ~-j 5-1 /2" DWP PATCH, ID = 2.987" (05/30/10) 8305' - 8325' 5-112" WFD CR LWR SNAP-LATCH PKR ID = 2.880" {05/21/10) 10778' 5-1/2" OTIS XA SLIDING SLV, ID = 4.562" 1078$'-10808' S-1/2"HESCR DWP SINGLE-SET PATCH ID - 2.987" (05113110) 10875' 5-112" BOT PBR ASSY 10897' 9-5/8" X 5-1/2" BOT RHR PKR 11021' --15-1/2" HES RCP PKR, ID = 2.80" 10/14/98 11026' TOP OF BKR SEAL BORE EXTENSION 11030.5' BTM OF RCP SEAL ASSY, ID = 2.803" ` ~~ ia. PrtoAC~ive DiaylvosTic SeRVieES, INC. • If"V~~L ~~r~.7 ~~~a~~~L To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907j 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Ina Attn: Robert A. Richey 130 West International Airport Road ~ Q ~ ~ ~ Suite C _f Anchorage, AK 99518 ~ ~ L~ Fax: (907) 245-8952 1) Leak Detection - WLD 17-Mar~10 02-11A 1 BL/ EDE 2) Signed Print Name: F 50-029-20273-01 ""- ~ "~ ,..._ ~- .ter,-,a ~~ .~: a~f~ :~ ~~ Date e ~`:4 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchorage(c~memorVlog.COm WEBSITE : wvuw.memory4og.COm C:~Documenfs and Settings~Diane Williams~DesktopYCransmit_BP.docx S~~~ber~+~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date osi2~ios NO. 5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 14-12 AYTU-00048 USIT L~ 07/26/09 1 1 L2-06 ANHY-00101 PRODUCTION PROFILE ~~ 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK C' 07/16/09 1 1 M-O6A AZCM-00034 PRODUCTION LOG '' - 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE (p L ^ 07/21/09 1 1 02-11A AYS4-00084 LDL - J 07/20/09 1 1 W-212 63SQ-00011 INJ PROFILE W/WFL ' - 07/20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL p` - 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL -6C L 07/24/09 1 1 H-29A AYQQ-00027 RST 'a 05/19/09 1 03-28 B14B-00067 RST I- Z-! 07/17/09 1 1 B-27A AXBD-00029 MCNL 06/12/09 1 1 C-15A AWJI-00038 MCNL - 06/25/09 1 1 Q-04A B1JJ-00023 MCNL ' 05/28/09 1 1 V-05 08AKA0024 OH MWD/LWD T 10/13/08 1 1 07-066 AWJI-00042 MCNL 07/21/09 1 1 02-33B 09AKA0149 OH MWD/LWD EDIT O6/03/09 1 1 14-23A 09AKA0035 OH MWD/LWD EDIT 05/12/09 1 1 H-196 B2WY-00004 MCNL (REPLACEMEN~ L ' 05/07/09 1 PLEASE ACKNaWLEDGE RECEIPT BY 51GNING AND RETURNING ONE COPY EACFi T0: BP Exploration (Alaska) Inc. Petrotechnica! Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ~ ~~ u -~ _.~ ~ ALASSA OIL A1QD GA.S COI~SERQATI011T COMI~IISSIOI~T Matt Brown Well Intervention Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX {907) 276-7542 `~~%/ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-11A Sundry Number: 309-132 ~'~~~~~~~? APR : ~~' ~~?C Dear Mr. Brown: 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. Sincerely, 7"~"~ Cathy P. Foerster Commissioner DATED this / % day of April, 2009 Encl. ii~ /C _ _ _ ~i d/ G® STATE OF ALASKA -/ ~ r A~ . ;~ ~ ~~~OIL AND GAS CONSERVATION COMMI~ON O{ _ , ~P pTION FOR SUNDRY APPROVAL. 11~ ~~~s~~ ~, , ~~~ ~OfIS', t,011~~~ili~` ~ ~~ ~~ 20 AAC 2s.2so ~~ 1. Type of Request: Suspend Operational shutdown Pertorate Waiver Othe Alter casing ^ Repair well. ^~ - Plug Pertorations^ Stimulate ^ Time Extension ^ PACKER REPAIR Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development- Exploratory ^ 198-1260 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-20273-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 02-11A Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028311 - 56 KB - PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13337 _ 9025.8 - 12900 9061.5 12900 11184 13305 Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 25 105 25 105 1490 470 Liner 354 3-1/2" 9.3# L-80 11026 11380 8372.8 8632 10160 10530 Liner 189 3-3/16" 6.2# L-80 11380 11569 8631.6 8779 Liner 1765 2-7/8" 6.5# L-80 11569 13334 8778.8 9026 10570 11160 Production 11453 9-5/8" 47# N-80 23 11476 23 8703 6870 4760 Surface 2687 13-3/8" 72# N-80 24 2711 24 2702 4930 2670 Perforation Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# L-80 21 - 11476 - - 4-1/2" 12.6# PATCH L-80 4324 - 4349 - - 4-1/2" 12.6# PATCH L-80 8303 - 8326 Packers and SSSV Type: 4-1/2" HES DWP Patch Packer Packers and SSSV MD (ft); 4324 4-1/2" HES DWP Patch Packer 4344 4-1/2" HES DWP Patch Packer 8303 4-1/2" HES DWP Patch Packer 8322 5-1/2" HES RCP PACKER 11021 5-1/2" BOT RHR PACKER 10897 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/27/2009 OIL Q - GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby ce ify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Printed Nam tt Brown Title Well Intervention Engineer Signature Phone 564-5874 Date 4/13/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - /~ C r ~ ~`~ a~ ~~ ~~` ~ ~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ` ~ 1 /~ ' 1 Other: `~ ®c~-~,~ ~U \ S~ ~' ~~ l~cC~~SC~I~ `-~h~ ~ ~ ~ ~~ ~~ ~ Vl~~ ~ . `~ ` '~~"' ~~ ~ ~ ~ ~~~~ " ~ Subsequent Form Required: u-V ~ ~ ,/ APPROVED BY I Approve ~'~COMMISSIONER THE COMMISSION Date: 1 ~K~6,i`ii..11 02-11 A 198-126 PERF OTTOrHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02-11A 9/26/98 PER 12,420. 12,820. 9,049.64 9,060.84 02-11A 9/26/98 PER 13,000. 13,300. 9,058.82 9,029.09 02-11A 1/10/02 BPS 11,680. 13,000. 8,858.46 9,058.82 02-11A 1/21/02 BPP 12,420. 13,295. 9,049.64 9,029.53 02-11A 5/15/04 BPS 12,900. 13,000. 9,061.48 9,058.82 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • . 02-11 A Packer Repair by To: Jerry Bixby /Clark Olsen, Well Operation Supervisors From: Claudia Rico Hernandez -Pad Engineer Matt Brown -Wells Engineer Subject: 02-11 A Packer Repair PBD02WL11-N Please perform the attached packer repair procedure: March 30, 2009 Est. Cost• $250M IOR: 500 BOPD S 1. Pull W RP S 2. Run composite in 2-7/8" at 11600' C 3. Lay in viscous pill to 11045' C 4. Cement Squeeze P 5. MIT-T, MIT-IA CP 6. FCO viscous pill/ mill composite Current Status S.I. (RHR and Liner Top packer leak) Last Test: 1007 BOPD 3.14 %WC 76735 GOR 77266 MCFD 1474.4 FTP 0 MMCFD AL Max Deviation 99.1 ° at 13029.3 ft Min ID 2.375" 11569' Last Tag: 19-Oct-08 tag WRP ~ 11184, 16-Feb-08 drifted to deviation at 12,106' 03-Oct-06 tagged CIBP w/CT at 12,874' Last Downhole Op: LDL 11/30/08 Latest H2S value: no data for 02-11 A; less than 5 ppm expected from offset wells SBHP/T: no data for 02-11A but about 3300 psi, 189° at 8800 SS (11677' MD) from nearest recent offset data Note: Sundry approval from the State is required prior to performing this work. Background 02-11 A was sidetracked with CT in 1998. During the initial completion, the PT of the liner showed some leaking at 1950 psi. In 1/99, the tubing was punched and POGLMs were installed for AL. A caliper run in 7/00 indicated some deep penetration points just 1 . 02-11 A Packer Repair • below the RHR packer. The POGLMs were pulled in 8/00 due to leaks and patches were set at 4324' and 8308'. The GOR continued to rise and a PPROF run in 4/91 indicated 95% of the flow came from the RCP liner top packer with only 5% from the perfs. A plug was set in the liner and a liner top squeeze was performed with coil in 1/02 with +/-1 bbp of cement. Following the squeeze, the cement was milled and the plug pushed to 13,305' MD. A caliper of the tubing in 2/08 showed little damage. In 3/08, the well failed an MIT-T but passed an MIT-IA to 3000 psi. A LDL run on 10/20/08 while pumping crude down the tubing indicated leaks at the RHR packer at 10897' (5-1/2" x 9-5/8") as well as the liner top packer at 11021' MD. Pumping was swapped to the IA and a LLR of 2.75 bpm at about 2600 psi was recorded. A second LDL was run on 11/30/08 down the IA. The LDL showed fluid log was 2 bpm at 2450 psi. was run down to the RHR packer while pumping moving past the packer in the IA. LLR during the From the leak detect logs, the RHR packer is leaking in the IA. The tubing is leaking just below the RHR packer as well as at the liner top. It is believed that the original liner cement job did not get cement all the way to the mill out window and fluids pumped are leaking out of the window, either via the leaking tubing/liner top or around the RHR packer. Objective The objective for this job is to remediate the leaks in the tubing & the IA by pumping cement. Job Summary First, the WRP will be pulled and a composite plug will be set in the 2-7/8" liner. A viscous pill of 4 ppb geovis will be placed such that top will be just below the RCP liner top packer. A CTU squeeze will follow, pumping enough cement to fill the annular volume from the RHR packer at 10897' to the millout window at 11476' as well as the annulus between the 3-1/2" liner and 5-1/2" tubing. Cement will be cleaned out down to the viscous pill but the pill will be left in place. After WOC, an MIT-T and MIT-IA will be performed to determine if the squeeze was successful. If both the MIT-T and MIT-IA pass, the viscous pill will be cleaned out and the composite plug milled up. If the MIT-T passes but the MIT-IA fails, a separate procedure to punch/cement the RHR packer will be sent to the Slope. AnnComm History > 06/22/98: MITOA Passed to 2000 psi > 01/10/99: POGLMs (2) set in tubing > 02/04/99: MITIA failed, LLR 4.9 gpm C«~ 1200# > 05/23/99: TIFL Passed post GLV set 2 02-11 A Packer Repair > 01/10/02: Set FAS Drill Bridge Plug -MIT-IA Passed to 2500 psi > 06/26/00: TIFL Failed, flow up IA > 06/27/00: SL ran DGLV's > 06/28/00: TIFL Failed post DGLV's > 07/07/00: LDL leak bottom POGLM > 07/08/00: SL CO bottom DGLV > 07/12/00: TIFL failed post DGLV c/o. > 07/20/00: SL pulled top POGLM > 07/27/00: Pulled POGLM; rubber and slips left in hole (fishing) > 07/28/00: PDS Caliper tubing; set PX plug Q sliding sleeve. > 07/30/00: PPPOT-T Passed @ 4000 psi; IC checks need changeout > 08/03/00: DHD c/o bad checks w 1/2" ball valve prep for seal-tite > 08/12/00: CMIT-TxIA Passed to 3000 psi > 08/25/00: WL set two 2.5" Tbg patches C~ 4328'-4348' and 8307'-8322' > 08/29/00: MITIA Passed to 3000 psi > 09/10/01: Issued temporary IAxOA waiver > 09/15/01: MIT OA Passed, PPPOT - IC Passed, TIFL Inconclusive > 09/23/02: MITOA Passed to 3000 psi > 10/02/02: MITIA Passed to 3000 psi > 11/13/02: PPPOT-T and PPPOT-IC Passed > 06/16/03: MITOA Passed to 3000 psi > 05/15/04: CT set CIBP C 12900' ctmd. > 06/21/04: MITOA Passed to 3000 psi > 06/24/05: MITOA Passed to 3000 psi > 09/24/05: TIFL Passed > 12/10/05: Waiver revised > 06/09/06: MITOA Passed to 3000 psi > 04/03/07: MITIA Passed to 3000 psi > 05/07/07: IAxOA waiver cancelled due to passing MITIA > 02/16/08: Set WRP G 11184'. Caliper LNR: Liner packer damage identified. 3.5": All jts <20%. 3.188" :All jts <6%. 2.875": 15 jts <20%; 10 jts 20-36%. > 03/03/08: MIT-T Failed, LLR ~ 4 bpm indicating a liner lap leak C~3 1000 psi, MIT-IA Passed to 3000 psi > 10/20/08: LDL indicates packer leak C«~ 10897' MD > 11/06/08: IA FL sample taken to lab, results were methanol Contacts: Matt Brown Claudia Rico Hernandez 564-5874 w 564-5626 w 223-7073 c 344-1130 h CC: Well File 3 .. • 02-11 A Packer Repair Slickline 1. RIH & pull WRP at 11,184' 2. Drift as deep as possible w/SL to at least 11,650' (50 deg inclination at 11,650'). 3. Make up Baker Quick-drill composite plug (OD = 2.400") & running tool. 4. RIH w/composite plug and running tools. 5. Set Baker Quick-drill plug top at 11600'MD. • The goal is to set the composite plug near. the top of the 2-7/8" liner; the exact depth is not critical as long as it is set in the liner 6. POOH. RD SL. CTU Lay in Viscous Pill/Cement Squeeze Note: target Viscous pill top is 11,045' MD 1. Load well with 400 bbls seawater followed by 200 bbls diesel. 2. RU CT and RIH with with slick cementing balldrop nozzle (minimum well bore ID 2.375" at 11569') 3. Lightly tag composite plug at 11,600. PUH 10' & flag pipe. 4. Lay in 4.5 bbls 4 ppb geovis pill from 11,600' to 11,045' Volumes: - 2-7/8" liner: 11569' to 11600' (top composite): 0.2 bbls - 3-3/16" liner: 11380' to 11569': 1.4 bbls - 3-1/2" liner: 11045' to 11380: 2.9 bbls 4.5 bbls 5. Circulate 50 bbls seawater while parked at 11,045' to dress off top of viscous geovis pill. POOH to +/- 10750'. Cement Squeeze Cement calculations: Goal is to fill annular spaces below RHR packer (10897') with cement down to the millout window (11476' top window) • 5-1/2" x 9-5/8" volume below RHR packer: 25 bbls 4 02-11 A Packer Repair • • 3-1 /2" x 5-1 /2" volume below RCP packer: 4 bbls • 3-3/16" x 5-1/2" volume to millout window: 1 bbl • Vol in tubing above geovis pill to RHR packer: 1 bbl Total vol to fill annular spaces + tubing from geovis pill to RHR packer: 31 bbls 25% Excess cement: Total pumpable cement: 8 bbls 39 bbls 1. Pump crude or methanol down the backside as necessary to lighten the hydrostatic pressure to maintain a positive WHP. 2. Line up a triplex pump to the 9-5/8" and pressure up to 1,000 psi. Maintain +/- 1,000 psi on 9-5/8" during squeeze operations. 3. RU cementers and batch mix 39 pumpable bbls LARC cement. BHT at packer depth of 10897' DD is 185°F. • Catch a sample of the cement for QC testing. (Lab must be notified prior to the job 659-2423.) Once the blend is approved, conduct Job Scope meeting to ensure that participants know the upcoming job sequence. 4. Line out cementers to the CT. Pump the following down the coil while taking returns up the annulus: a. 10 bbls of 2% KCI b. 39 bbls cement e. One coil volume of 2% KCI f. McOH for FP coil 5. RIH with coil to 10' above geovis pill at 11045' as the cement reaches the nozzle. 6. With IA and backside shut in, pump in 2 bbls cement out nozzle then begin POOH to 10797' (100' above RHR packer). • Reciprocate around 10797' MD while squeezing cement away. • Once a 1000 psi pressure bump is observed, open the backside and pull the coil uphole at max speed to safety depth. Note: 39 bbls of slurry would extend up into the 5-1/2" tubing to 9352' MD if no cement is squeezed behind pipe. • Maintain stable WHP for 30 minutes. 7. POOH to safety at 9252'. With coil at safety, close the backside, and walk squeeze pressure up to a target of 3,500 psi dP at the RCP in 500 psi 5 02-11A Packer Repair. • increments. Hold each increment for 15 minutes. Maintain 3,500 psi DP for 60 minutes. Note: Account for 2% KCI and cement densities when calculating DP at RCP (SBHP = 3300 psi at 8,800' SS / 11,677' MD / 8,856' TVD). • After 60 min at 3,500 psi, bleed off WHP over a 10 minute period. Note: 31 barrels of cement can be squeezed into the RCP/tubing leaks before the cement top will fall to within 20' of the leak below the RHR packer. 8. Clean out well bore. • RIH jetting biozan down at 1:1 to 11,100' (~80' into liner) • Make 3 down passes and 2 up-passes (C~3 80% running speed) and 4000 psi injection pressure. Take a barrel count to ensure 1:1 returns. • On the third and final up pass, spot 10 bbls 10% TEA solution from the 11,100' at 11,680' CTM up across the squeezed RCP leaks. • POH jetting all tubing jewelry. Post-Leak Repair 1. After 3 days WOC, MIT-T to 3000 psi, MIT-IA to 3000 psi, establish leak rate if fails. 2. RU SL. Drift tubing & tag PBTD. 3. If MIT's pass, perform CTU FCO of viscous geovis pill & mill composite as follows: a. RU CTU. b. MU MHA + 2.3" mill. RIH & circulate out geovis pill down to composite at 11,600. c. Once geovis pill is bottoms up, mill composite plug at 11600'. Push mill to TD at 12900'. d. POOH at 80% to surface monitoring returns e. RDMO. s 02-11 A Packer Repair Note: 02-11 A will need aState-witnessed MIT. 02-11 A Packer Repair • 02-11 A Current Schematic raE£. sts•FUr. WE11IfAC1• ACTUATOR^ K8. ELEV ^ FMC AXELSON ~fi BF. HFV • C,L ELEV ^ __ 3b KOP= _ 213T Maoc Angb ~ 99 ~ 13029' ~~~- Datun MD = DatunND a~ . t td 7T . 9800', 02 -11 A sAl~rvNO,~s: °• w~. occ~s 70•~ „774' HOR¢. ®12482'. SOfRK WMDW NNLL®TFRU 9~ 5/8't~3AND 5-1f2'TBG~ 11476' •^ D ~ 2.99r 0825A0 PAiCM, Minimum ID = 2.375" Q 11569' 3-3116" X 2-T/S" XO Leak in IA :u~ounLi packer Leaking liner top packer 31 ft' LNR P@3FOftATDN st~-ar REF LOC;; BHC ON 1 ti 13171 A NCL,E AT TOP PBtF: 89 ~ t 2424 Nafe: Refer t0 ftodict1a108 tar h star W I peA deA~ S¢E SPF NTH~IVAI OpYSq[ QATE r 4 1242D - 1282 C 08Y2&'98 r 4 13000 - 13300 C 09PZQd98 „~ ~ ~ ~. ~, • .ear ,uruwye ~ >POF BIQt SEAL aoRE ExTENSION 'MOF RCP SEALASSV, D • 2803" ter wRP ~ovtd.t7e~ 'ECML CLEARANCE, O1h269' ur x 3.3rtc xo, ~ ~ z eoo• Leak in tub at bottom of RHR II MuatrWMbC1M ,,.M'_11.A.• ----- ~ PRLOFgE BAY UNIT WELL: OQ-11A PERARf Nx'1981260 API No: 54028~202T3U t BP E¢ploratlon (Aasks- 8 • 02-11 A Packer Repair • 02-11 A Post-Sqz Schematic TRff • i 1dt' FMc WELLHEAD ^ F!AC ACTLIATOR• AXEL:x'?N KB. El W ~ _ ~a 8F. EiEV ~ KOF~ 243T hlan Mgb_• 99 ~ 13029 DatunMD~ 776TT Datun TV D ~ _ .___ _ 880tr SS 0 2 -11 A SAFETY NOTES_ .. ~ WBL EXCEEDS 7n• ~ „774' HORQ ~ 12482'. SOTRK WNOW ML1.~TiEtU 9- 5/8' CSGAND 5-11Z" Tf3G~ 11478' D •2.962' 08/2SA0 b •2992" 0885.t~0 Minimum ID = 2.375" @ 11569' 3/16" X 2-718" XO Fi119-5/8" x 5-1/2" annulus with cement below RHR packer Fi115-1/2" x 3-1/2" annulus with cement below RCP JU t~~aurwtNmw tu7~r-11~A1• PERFORATpN SUM6NRY REF LO(t BHCON 11/13!77 A NGLE AT TOPFf1iF: 88 Q 12120' Notae ReflK to Ftoduction DB for hatorMal pelf dada S¢E SPF MRHiVAL OpYS~ DALE 2' T 4 4 12420 - 12820 13000- 13300 C C 09f26/98 09f26198 FL45, DA-E REV BY GJMMENTS DATE REV BY COMMB~OfS PF2tAFtDEBAY UNR t183J77 ORIGINALCOMPLETION 08/17/03 CMCkTLP OATUMMDCORRECfIDN W9.L:02-11A 0987196 C f D S10E7 RAC K 06/15JOM KCF.~t(A K SET WF RD CM3P FfRAR Pbc X1981280 05,30VOt Clith CORP.bCT10NS 12!21105 WMPAG WAN ER SAFETY NOTE APINoc SO.02~20273-01 Ot,03J0~2 outera2 DAClKA TNrtr, POGLMS PULLED BPSE7aMINIDUPCV~TE4 OS/t0V07 06na0e RDVwPAG 1CM~su riANFR SFTY NOTE DELETED sETWRP oz,aa SE036. T11N, R14E, 921' FNL a916' FWL . ~ e~ 0182!02 KSBACK CIBPPl1SNED TO BOTTOM 8P 6cploratloa (ANska) 9 02-11 A Packer Repair • 02-11A LDL 11-30-08 Pump Down IA 2 3000 5 I i . 2500 ' 2 , ~ ~~ ~' 2000 ! a - _ _ _ ~ t- TBG 1.5 o to ; I IA ~ m 1500 , - - - ----- - ----- __ - --- _ a m ~ ! ~- OA m E ' III- BBLs 1 V 1000 - _ -_ _ -___ --- -_ __ _ i -+- BPM -- ------ -- - _ - __ 0.5 500 ~ ~ - ~3K -CIE - ~~~~~*. . w l N~ ~~~ 0 ~gk ~li il 0 12:00 13:12 14:24 15:36 16:48 18:00 19:12 10000 1000 0 a m 100 10 1 /98 ~~ 100 80 3 60 40 20 0 1 /00 1 /02 1104 02-11 A +OIL ROW RATE -+- WATER ROW RATE rro 100000 10000 0 1000 100 1 /06 1 /08 1/10 I -~- WATEACUi PCT -GAS LIFE RATE 2soo 200o f D is00 U r n 1000 ~ o C7 s00 t 0 1/98 1/00 1/02 1/04 1/O6 1/08 1/10 ~ - --J 10 02-11A Well Tests • 02-11 A Packer Repair 11 • • ~ 02-11 A Packer Repair • ~_•...~ ~, PDS Caliper 28-Jul-00 Deep penetrations below RHR packer 12 • • • • ~ 02-11 A Packer Repair • 10/20/08 LDL Pumping down tubin -PKR- i ~ .•'~ Fluid exiting -~- ,--- ~ 1as6o ! ~-- ~ - tubing at or just ;~ I t ~ ~~~~~~` ~~~ ' ~ below RHR _ - Line Speed - a6 Up ~~~ t~ pac er i p ~ '' i Temperature - 80 fpm Up ~'. ; } , ~ 1 ~ Ii • ? Temperature - 80 fpm Down -~! ~'. ' ~ i ~ __ ~i ' ~ Une S ~ 80 Down _ _ ~ ~ i ,. i - _ r emperature - 80 tpm Up ~ l f i .. --- :._._-~-_ _.___-- -. _ E- _ i .._____.__.-- _ i ~ ! .% r i KatUfe - 80 m DOWTI --I ~ \l, c- ~i ! ! i --- I--~ --- -- 1 ~ 1 \t ,, . , I i f L---- - I 11600 P PKR- ~ ~~ ~~ Fluid exiting ,• `:, tubing at RCP _ . `-~~ packer .` _ _._ .... ~i. ._ _L_ .. - 1 i I i ~ j a ~ 1 .t I i I I_. ` ,. .. _.. .. i •y 13 • • ~ 02-11 A Packer Repair ~-~v-va i.li>_. rum ping a ow n lti - ---- - i .w_.. _ . , - - - -- i I ; . - ~ ~ . :~ ' i ~ t. -- ~' ~ 1es~:, ______ __ _ _ I -- - - - --1- -- - ;~ _ .---- i - 1040 ~ ; -- ~ - , , - , Fluid i _ ~ ' I ~ moving _ ' ast RHR ~ ~ • I p _ _ ~_. 1esa1 ' ~ ; packer _ ~ i -- r~arr ma Ray ------ Te n'tpe rature (1 hr Warrnba ck i 1 --- _.. _ ..__._ ~._ - emperature (3 hr'~;Jar mback; ~ 1090G I ~ ~ I _ ~ . - - -- Tempe ratur e (a l hr VYarmba ck - - -- - i - Temperature (Iry ectlr r3, I i i - -- - ---_ emperature t Stati c) ~ 11000 1 ~ ~ - ~ _ I j 0 Gamma Ray 100 ~'~ CCL -600 0 Terperatue i 1 hr Ntarrnback) 104' 0 Temperature t 3 M VYarrnbecki 104 0 Temperature i 5 hr 1lSrarmbackti 100 ---------------------------------------------------------------- 0 Tert~perature t Irtjectir~t; 109 0 Temperature t Static) 100 14 dV~~~ ~O~ _., __ Ti~A/I~~f~/~T;4L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~ , t jj~~rrn `~ ti~~~>m~~~d~w"L~ ~ ~, i ~`, f lav RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and e~~s- ray /~dsa 'i's~--CtiS3- / ~O~ ~roActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 2458952 1] - STP 20-0ct-08 02-11 A 1 Color Log /EDE 50-022920273-01 2) Leak Detection - STP 17-0ct-08 L5-21 i Signed : Print Name: ~ s o 1 Color-Log /EDE 50-029-21:732-00 Date : - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (90T)245~8952 E-MAIL : 33f~S~~a~li{39'~C3° f(7.~i'1vn',~i't~ICSq.Ci3i3E WEBSITE : Wr,~NV,ti'9~'S3~t?4"tJ~i3¢~.Ca333 C:\Doc~ents and Setringsl0wner\Desktop\Transmit_BP.doc 09/24/07 lyl Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~J7,., B1t~ti.' N~V ~ 2~~T Well Jnh 7! Lna Dec~rintinn N0.4414 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Date RI_ Cnlnr CD 09-25 11695072 LDL v .,~, ~ _p 08/17/07 1 L-04 11661166 SCMT 08/25/07 1 15-26B 11661165 MEM PROD PROFILE 08/23/07 1 02-12B 11628789 MEM PROD PROFILE p 08/20/07 1 02-11A 11428266 MCNL ~ .. / G 10/03/06 1 1 18-24AL2 11209591 MCNL ~ ~ ~ (p 03/23/06 1 1 14-07 11637334 RST 1 - / L 05/08/07 1 1 B-14 11637349 RST '~'~- / ~/ 07/04/07 1 1 Z-08A 11630483 RST - C 06/21/07 1 1 Z-46 40012671 OH EDIT MWD/LWD ~ - ~ / 4 < 12/12/05 2 1 Z-46A 40012671 OH EDIT MWD/LWD ~ / - 01/03/06 2 1 E-37A 10928640 MCNL a p~ -Ofd ' l 06/14/05 1 1 B-34 11594510 RST q - ~ '- < ^~.. 06/14/07 1 1 MPH-17 11813063 CBL/USIT (PDC) CH EDIT ~O~ -(~ ) 5' S "~ 07/21/07 1 YLtASt AGKNUWLtUGE KtGt1Y 1 t3T SIGNING ANU lit 1 UIiNING ONE DOPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ,j "` ~y r F~ ~i.~ ~ ~! 900 E. Benson Bivd. ~ "~ `. _ " ~~-- Anchorage, Alaska 99508 Date Delivered: ~-~~--~' r Cr ~t ~~ ..., °:~~ ~-.,ttrlb9i,~~6tJii . ~~~i: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth Received by: ~ - • • 02-11A (PTD #1981260) Internal Waiver Cancellation - Normal Well . . All, An internal waiver was issued for IAxOA communication on well 02-11A (PTD #1981260) on 12/10/05. The well passed an MITIA on 04/03/07 proving two comepentent barriers. Under the new WI System Policy set to take effect on June 1, 2007, 02-15 will be Operable. The well is reclassified as a Normal well. Please remove all waivered well signs and the lamintaed copy of the waiver from the wellhouse. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~NED MA'< 1 6 2007 1 of 1 5/8/20074:49 PM ( STATE OF ALASKA (' ~H~"" t=~ ALASKA Oil AND GAS CONSERVATION COMMISSlffi,;,:, ,¡.~~: REPORT OF SUNDRY WELL OPERATIONS 2004 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Repair Well 0 PluQ Perforations ŒJ Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 4. Current Well Class: Stimu~t§,::s Oil '::'~ôtHe~DCn~'~: ,", wa~~:;D Time ÈXtè~~¡~~t] Re-enter Suspended Well 0 5. Permit to Drill Number: 198-1260 Name: BP Exploration (Alaska), Inc. 56.00 8. Property Designation: ADL-0028311 11. Present Well Condition Summary: Total Depth measured 13337 feet true vertical 9025.8 feet measured 12900 feet true vertical 9061.5 feet Casing Conductor Liner Liner Liner Production Surface Perforation deDth: Measured depth: 12420 -12820 True vertical depth: 9049.64 - 9060.84 Tubing ( size, grade, and measured depth): 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Effective Depth Length 80 354 189 1765 11453 2687 Development Œ1 Stratigraphic D 9. Well Name and Number: 02-11A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Exploratory 0 Service D 6. API Number 50-029-20273-01-00 Size 20" 91.5# H-40 3-1/2" 9.3# L-80 3-3/16" 6.2# L-80 2-7/8" 6.5# L-80 9-5/8" 47# N-80 13-3/8" 72# N-80 Plugs (measured) 12900 Junk (measured) 13295 MD TVD Burst Collapse 25 - 105 25.0 - 105.0 1490 470 11026 - 11380 8372.8 - 8631.6 10160 10530 11380 - 11569 8631.6 - 8778.8 11569 - 13334 8778.8 - 9026.1 10570 11160 23 - 11476 23.0 - 8703.0 6870 4760 24 - 2711 24.0 - 2702.1 4930 2670 5-1/2" 17# L-80 4-112" 12.6# L-80 4-1/2" 12.6# L-80 3-1/2" HES RCP Packer 4-1/2" HES DWP Patch Packer 4-1/2" HES DWP Patch Packer 4-1/2" HES DWP Patch Packer 4-1/2" HES DWP Patch Packer 5-112" BOT RHR Packer @ 21 @ 4324 @ 8303 @ 11021 @ 4324 @ 4344 @ 8303 @ 8322 @ 10897 11476 4349 8326 Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Daily Report of Well Operations. ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature 1j /Ã:.A .' L,-~ Form 10-404 Revis:;t004 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - 'I;J'I.' (1)\ t~. < A:. l(~" \.' I,D Oil-Bbl 832 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 35.7 531 780 Tubing Pressure 353 318 843 35.4 700 426 15. Well Class after proposed work: ExploratoryD Development ŒJ Service D 16. Well Status after proposed work: OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant OR\C\Nl\re 6/25/04 564-4657 Date .í' \ ( 02-11 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/15/04 CTU#9: DRIFT & SET CIBP. WELL FLOWING UPON ARRIVAL. SHUT-IN WELL. RIH WI 2.25" JSN FOR DRIFT RUN. DRIFT WELL TO 13,000' CTMD AND POOH. MU 2.235" 00 WFRD CIBP (FOR 2-7/8" LINER), KNOCK WHP DOWN AND RIH TO 12,950 AND PUH TO SETTING DEPTH OF 12,900' CTM. DROP BALL AND SET CIBP AT 12,900' CTMD. PU AND RBIH AND TAG PLUG, OK. POOH. LAY DOWN WFRD SETTING TOOLS AND RD CTU. CONTACT DSO, WILL POP WELL IN AM AS THIS IS A WAIVERED WELL. WELL NOT FREEZE PROTECTED. FLOWLINE NOT FREEZE PROTECTED. CONTACTED EOC WITH WELL STATUS. WELL LEFT SHUT-IN. «< JOB COMPLETE »> FLUIDS PUMPED BBLS 50 215 265 45/55 Methanal 1 % KCL TOTAL Page 1 TREE = W8..LHEAO = A Cfl.LA. TOR = KB. ELEV = BF. ELEV = GL. ELEV = KoP~- -- Max Ange = Datum MO = OatumTVO = 5-118" FMC FMC AXELSON 56' 02-11 A 30' 2437' 99@ 1302g' 11677' 8800' SS 8 ~ ~ ~ ~ I I 113-3/8" CSG. 72#, N-80, 10 = 12.347" H 2711' ~ Minimum ID =2.375" @ 11569' 3-3/16" X 2-718" XO J k V 13-1/2" BKR DEPLOYMß\lTSLV, 10= 3.00" H 11030' 1 TOPOF 3-1/2" LNR H 11033' 1 13-1/2" LNR, 9.3#, L-80, .0087 bpf, 10 =2.992" I~ 11380' 1 TOPOF3-1/6"LNR H 11380' 1 19-518" CSG, 47#, N-80, 10 = 8.861" H 11476' 1 15-1/2" TBG-PC,17#, L-80, .0232 bpf, 10 =4.892" l-t 11476' ~ 1 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.8" H 11569' ~ / 1 TOP OF 2-7/8" LNR 1-1 11570' ÆRFORA TON SUMMARY Ra: LOG: BHC ON 11/13/77 ANGLE AT TOP PERF: 89 @ 12420' Note: Refer to Production DB for historical perf data SIZE SPF INTER V AL Opn/Sqz DA TE 2" 4 12420 - 12820 0 09/26/98 2" 4 13000 - 13300 C 09/26/98 f SAFETY NOTES: **IAX OACOMM. OPERAllNG PREsSUREOF13-318" ANNULUS MUST NOT EXCEED 2000 PSI (11/02/02 WAIVER). WELL EXCEEDS 70° @ 11774' ; HORIZ @ 12482'.SDTRKWINDW MLUÐ THRU9-5/8" CSGAND 5-1f2"TBG@ 11476'. 2075' HS-1/2" OTIS ROMSSSV NP. 10 =4,562" 1 I 4324' H5-1/2" HES OWPTBG PATCH, I ~ 110 = 2.992" 08125/00 8303' H5-1/2" HES DWPTBG PATCH, I 1'0 = 2.992" 08125/00 H5-1/2" OTISXA SLlOINGSLV, 10=4.562" I H5-1/2" BOT PBR ASSY 1 H9-5/8" X 5-1/2:' BOT RHR PKR 1 HS-1/2" I-ES RCP A<R. 10 = 2.80" 10/14/98 I 1 I ~ 10778' 1 10875' 1 10897 1 11021' 1 11026' HTOPOFBKR SEAL BORE EXTENSION t 11030.5'I-1BTMOFRCPSEALASSY,10=2.803" 1 11380' H3-1/2" X 3-3/16" XO, 10 = 2.800" I MILLOUTWINOOW 11476'-11481' I. 11569' 1-13-3I16"X 2-718" XO, 10 =2.375" 1 1 12900' 1-12-718" WFRDClBP(05/15/04) 13305' I-!CIBP RJSHEO I ITO BOTTOM 1 ffi TO l-t 1lli-1 13337' 12-7/8" LNR, 6.5#. L-80 FL45, .0056 bpf, 10 = 2.375" H 13334' I DATE REV BY COMMENTS 11/23/77 ORIGINAL COMPLETION 09/27/98 CTDSIŒTRACK 05/30/01 CI-Vtlh CORRECTIONS 01/03/02 DACiKAK FQGLMS PLLL8:> 01/18/02 TN'tlh BP SET & MN 10 UFDATES 01/22/02 KSB/KK aBP PUSH8:> TO BOTTOM DA TE REV BY COMM8'JTS 11/08/02 KB/TLH WAIVER SAFEfY NOTE 08/17/03 CMO/TLP OA ruM MO CORRECllON 05/15/04 KCF/KAK SETWFROCIBP ffiUDHOE BA Y UNIT WI3...L: 02-11A ÆRMIT No: 1981260 API No: 50-029-20273-01 SEC 36, T11N, R14E, 921' FNL& 916' FWL BP Exploration (Alaska) ·n..."" , 1. 1JU v~-1. 1..<1., 1. -1.~, uuu. .L1.-.L.l \'_da~~ JJJ. VV""'U~J l~LUllHJU LV piUUU... e . Subject: Re: PBQ;~î~â!iF~12,and H~21 (Class B3 wells) returned to production From: T?mMaUllder~toni_maunder@admin.state.ak.us>\c.("'.-.__ \ '.(p Date: Fn, 22 NoV200217:07:33 -0900 . . "~ \"ð.~ . <:.... Joe, John, et al: In the last paragraph of my earlier message, you were required to notify the North Slope Inspectors in advance of the re-testing on H-2l and F-12. In earlier conversations between the Problem Wells staff and, in particular, Inspector Jeff Jones you were requested to notify the Inspectors when diagnostics were scheduled on AlB3 type wells. On the 4 wells mentioned in the earlier email, we can find no record that the Inspectors were contacted in advance. I would like to take this opportunity to reiterate that request. When diagnostics are planned on AlB3 wells, the North Slope Inspectors should be contacted so they may witness the diagnostics if they are able. Your usual cooperation with a request such as this will be appreciated. Tom Maunder, PE AOGCC Tom Maunder wrote: Joe, John, et al: We have received two messages from Problem Wells regarding the startup of 4 B3 type wells. The specific wells are DS 02-llA, H-21, F-12 and DS 02-l8A We call your attention to the Commission's letter of October 29, 2002 to Mr. Randy Frazier (copy attached), where the necessary integrity requirements for returning the "AlB3" wells to operation were listed. In Item 3, it is noted that, ..."the report must include pre-test pressures in all casing annuli and the shut in tubing pressure." Initial pressures are noted on MITs and TIFLs, however initial pressures are not noted on packoff tests. This information should be included on future reports. Item 8 requires that "Any well exhibiting communication across more than 2 barriers must be secured." We have examined the information submitted and in 2 cases DO NOT AGREE that the conditions necessary to satisfy the 2 barrier requirement have been met. The specific wells that we feel have not met the requirements of the October 29 letter and BP's own internal criteria as explained to us are H-21 and F-12. With regard to H-21, the MIT OA and TIFL appear to satisfactorily demonstrate that the OA has pressure integrity and that there was no measured fluid rise in the IA. The tubing hanger packoff test FAILED and it is specifically noted that the tubing hanger neck seals were leaking when the test was performed April 19, 2002. Please explain how the requirements of the Commission's letter , '?- .~" \"\ n" ,,\(si;) ~ _.' \ \' \Q..Cu' v 1 of2 3/9/2006 12:49 PM 1"". í UU VL-l U,", r-1L, dllU n-Ll ~\....Id:>:> DJ WCII:» ICtUlllCU tV ¡JIUUU... e e and BP's own internal policy for competent tubing (including tubing packer and packoffs) has been satisfied? We also find it interesting that a more recent packofftest has not been conducted as opposed to one 6 months in the past. The information supplied for the other wells were much closer in time. With regard to F-12, both the tubing hanger and production casing packoffs are listed as FAILING. The TIFL has contradictory information recorded on it and it appears incomplete. Although some information is recorded for the 6:45 observation, the fluid level at that time is not recorded. One is left to infer that the fluid level did not change from the previous observation, however that may not be valid. Again, please explain how the requirements of the Commission's letter BP's own internal policy for competent tubing (including tubing packer and packoffs) has been satisfied? You are requested to re-test and confirm the packoff (tubing hanger and production casing) competency on wells H-2l and F-12 and the TIFL on F-12 and submit the information to the Commission. Successfully passing these tests in conjunction with the earlier testing will confirm the tubing as a barrier on the subject wells. If the tests are not successful, the wells must be secured until the competency of the tubing can be demonstrated. Please contact Jim Regg at 793-1236 or myself at 793-1250 with any questions. The requested test results should be available for the Commission's inspection (email response is acceptable) on Tuesday November 26. Please also include a current wellbore drawing for the subject wells and plan to include a well drawing with subsequent test information submissions. Your field personnel should also contact the North Slope Inspector at 659-2714 or page them at 659-3607 approximately 24 hours in advance of the work so that the Inspector may witness the testing as they are able. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Gentlemen,The following "83" category wells have been returned to production: F-12 (on line 11/08/02 @ 20:00), 02-11A (on line 11/09/02 @ 11:00), and H-21 (on line 11/10/02 @ 18:00). Attached please find the test records that demonstrate the two competent barriers required to produce these wells.Dave Reemfor Joe Anders 659-5102 Mobil: 943-1154 Pager: 659-5100, x1154 20f2 3/9/2006 12:49 PM e e WELLHEAD PACK OFF TESTING FORM WELL: DATE: TESTED BY: DS:02-11 11/13/2002 FMC TEST FOR: FSO 32613 TYPE & GEN .FMC I INITIAL PRESSURE DATA Well Status: TBG: 480 CONTROL: Not hooked up TYPE: IA: 500 OA: BALANCE: Not hooked u~ 1720 Tubing Hanger Test PASS FAIL Pressured To: 5000 Press. @ 15 min: 4920 Press. @ 30 min: 4900 Test Port Press. @: 0 Bled to 0 Psi YES / NO Were Lockdown Screws Tightened? YES / NO Torqued to fUlbs Comments: Good test on tubing hanger void. Inner Casing Hanger Test PASS FAIL PLASTIC PACK Pressured To: 3000 Press. @ 15 min: 2880 Press. @ 30 min: 2880 Test Port Press. @: 15 Bled to 0 Psi YES / NO Were Lockdown Screws Tightened? YES / NO Torqued to fUlbs Comments: There was a set of Hokey valves on both test ports, Check to see what kind of plastic was in void. Got gas from both sides. Pumped in oil and got good returns, could not see any type of plastic in returns. Tested void. Good test. e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@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 / 02 10/02/2002; 9/23/2002 Tony Peter; Skip Hendricks Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. We1l102-11A I Type Inj. I N/A MD/TVDI 10,8971 8,278' Tubing 950 970 970 970 Interval! I P.T.D.11981260 I Type test I M Test psil 20701 I. Casing 225 3000 2910 2880 P/FI P Notes: MIT-IA [10/02/02] O. Casing 225 450 440 440 We1l102-11A I Type Inj. I N/A 1 MD/TVDI 10,897'1 8,278'1 Tubing 900 900 900 900 Interval I I p.T.D.11981260 I Type test I M Test psi 20701 Casing 300 300 300 300 P/FI P Notes: MIT-OA [9/23/02] O. Casing 300 3000 2950 2940 Weill I Type Inj. 1 MD/TVDI 1 1 Tubing I ntervall P.T.D.I I Type test I Test psi! I I Casing P/FI Notes: Weill I Type Inj.1 I MD/TVDI I I Tubing I I I Interval I P.T.D.I I Type test I Test psi! I I Casing I I I I P/FI Notes: Weill I Type Inj. MD/TVDI 1 I Tubing I I I Interval! P.T.D.I I Type test I Test psi I I Casing I I I P/FI Notes: 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 INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form Revised: 06/19/02 02-11 A MIT 10-02-02.xls . . . , MICROFilMED 7/30/02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Saved as M:/weepie/microfilm_marker.doc File on Left side of folder 198-126-0 PRUDHOE BAY UNIT Roll #1: Start: Stop Roll #2: MD 1.3337_ TVD 09026 Completion Date: 02-1 lA 50- 029-20273-01 Start Stop 9/27/98 Completed Status: 1-OIL BP EXPLORATION (ALASKA) INC Current: Name D 8826 D 8895 L GR-MD L GR-TVD L LEAK-SPIN/TEM/ L MCNL R CALIPER SRVY R SRVY LSTNG R SRVY LSTNG Daily Well Ops _ --- _ .... Was the well cored? yes no Comments: Interval 1 SCHLUM MCNL BH GR-MUD FINAL 11329-13307 FINAL 8631-9006 FINAL PRES 100-11001 FINAL 10763-12997 PDS 0-10995. BHI 11300.-131500.10 BHI 11300.-13150.10 CH 11/4/98 11/6/98 OH 3/19/99 3/22/99 OH 3/19/99 3/22/99 D OH 3/19/99 3/22/99 CH 5 7/26/00 8/4/00 CH 2 11/4/98 11/6/98 D CH 8/9/00 8/10/00 OH 10/19/98 10/20/98 OH 10/20/98 10/20/98 Sent Received T/C/D Are Dry Ditch Samples Required? yes ~ And Received? yes no Analysis Description Received? yes no Sample Set # Wednesday, November 08, 2000 Page 1 of 1 STATE OF ALASKA ALA9¥'(A OIL AND GAS CONSERVATION COMMIS!::;TCN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X (set tbg patch) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 56 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Servia__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 918' FNL, 4364' FEL, Sec. 36, T11 N, R14E, UM (asp's 687666, 5950281) 02-1 lA At top of productive interval 9. Permit number / approval number 1808' FNL, 1976' FEL, Sec. 1, T1 ON, R14E, UM (asp's 690210, 5944177) ~' 198-126 At effective depth 10. APl number 50-029-20273~01 At total depth 11. Field / Pool 1545' FNL, 2851' FEL, Sec. 1, T1 ON, R14E, UM (asp's 689327, 5944415) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 13337 feet Plugs (measured) Tagged PBTD (9/26/1998) @ 13300' MD. true vertical 9026 feet Effective depth: measured 13300 feet Junk (measured) true vertical 9029 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 262 Sx AS 110' 110' Surface 2655' 13-3/8" 2706 cubic ft CS III & 460 cubic ft 271 1' 2702' Class G Production 11420' 9-5/8" 2218 cubic ft Class G 11476' 8703' Liner 347' 3-1/2" 17.5 bbls 15.8 ppg Neat Class G 1 1380' 9026' ORIGINAL Perforation depth: measured 12420' - 12820'; 13000' - 13300'. true vertical 9050' - 9061" 9059' - 9029'. '~*:~ iv'ED Tubing(size, grade, and measured depth) 5-1/2", 17#, L-80 POT @ 11476' MD; 4-1/2", 12.6#, N-80 POT @ 11814' MD.SEP 2:2 2000 Packers &SSSV (type& measured depth) 95/8"X51/2"BOTRHRPACKERe10897'MD; 51/2"HESRCP @ 11021'MD. ¢~J~.$i~-~ L'~i & ¢:,~r:~ ¢~..* ~ ~. 5-1/2" OTIS RQM SSSV @ 2076' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut in (annular communication) Subsequent to operation 1856 41983 638 1659 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well/~p~rations ._X ~ Oil __X Gas __ Suspended __ Service 17. I hereby certify,~t"tb~o~oing is t~nd Cect to the best of my knowledge. Signed Title: Alaska Drilling & Wells Technical Assistant Date ul Rauf Prepared by Paul Rauf 564-5799 SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 · 02-11A · DESCRIPTION OF WORK COMPLETED SET TUBING PATCH Date Event Summary 7/20/2000 - 7/27/2000: 8/25~2000: 8/29/2000: RIH & retrieved POGLM's f/4323' & 8260' SLM. (Required several days to fish out of hole). RIH & set a tubing patch f/8307' to 8322.5' & f/4328' - 4348.5'. MITIA to 3000 psi - passed. Placed well BOL & obtained production data. Page 1 TRANSMITTAL II, ProActive Diagnostic Services, Inc. To: Phillips Alaska, Inc. AOGCC Lori Taylor RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 LoG CD-ROM MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR FLOPPY FILM BLUELINE Open Hole I I 1 Res. Eval. CH I I 1 Mech. CH 1 02-11A 7-28-00 Caliper Survey ~or ~r,--r~rr~ I BL/1F Signed · Print Name: RECEi'"'" VClJ Date' ,~JJG 0 9 2000 Alaska Oil & Gas Cons. Commission Anchorage ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-maih pdsprudhoe~NA800.net Website: ~v.memorvlog.com C:WIy DocumentsXDistribution_FormsXPhillips_pb_form.doc Memory Multi-Finger Caliper Log Results Summary Company: BP Exploration (Alaska) Inc. Well: Log Date: July 28, 2000 Field: Log No.: 4136 State: Run No.: 1 APl No.: Pipe Desc.: 5.5" 17 lb. L-80 IPC Top Log intvl: Pipe Use: Tubing Bot. Log Intvi: 02-11A Prudhoe Bay Alaska 50-029-20273-01 Surface 10,995 Ft. (MD) Inspection Type' Corrosive & Mechanical Damage Inspection COMMENTS · This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the tubing is mostly in good to fair condition with respect to corrosive damage. Penetrations ranging from 10% to 40% wall penetration are recorded throughout the interval logged, appearing mostly in the form of a narrow line of corrosion, on the Iow side of the pipe. Multiple Holes are recorded in Joint's 113 (4,372') and 219 (8,328'), at the location of Packoff Gas Lift Valve installations. Packoff Gas Lift Mandrels were pulled pdor to running this log. An area of corrosion in Pup Jt. No. 287.4, just below the packer, indicates a maximum of 26% cross- sectional metal loss. This is the most significant area of cross-sectional metal loss indicated in the log. No significant tubing restrictions are recorded throughout the logged interval. The distribution of the wall penetration damage recorded throughout the logged interval is illustrated in the Body Damage Profile page of this report. Elongated collars were recorded @ Joints 118, 141,202, 214 and 223 when tool paused momentarily in joint make up. MAXIMUM RECORDED WALL PENETRATIONS · Multiple Holes (100%) Jt. 113 @ 4,372' MD Multiple Holes (100%) Jt. 219 @ 8,328' MD Line Corrosion (64%) Jt. 287.4 @ 10,905' MD Corrosion (37%) Jt. 213 @ 8,100' MD Line Corrosion (34%) Jt. 233 @ 4,529' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · Corrosion (26%) Jt. 287.4 @ 10,905' MD Corrosion RECEIVED Line Corrosion (14%) Jt. 71 @ 2,767' MD AUG 0 MAXIMUM RECORDED ID RESTRICTIONS · . u~J & ga.s Cons. Commisslor[ · f ~,ch0ra.qe No areas of signifi~nt ID restriction (in exc~ of 0.20 in.) were r~orded throughout the ime~a~iogge6. [Field Engineer' R.A. Richey Analyst: R.A.. Richey Witness: Doug Varble I ProActive Diagnostic Services, Inc, / P,O. Box !369, Stafford, ~-3,( 77497 Phone: (2oi) or (888) .,6a-9085 Fax: (28!) 565-1369 E-mail , DS~ m~mol,iog,com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 6:¢~-z~4 Well: 02-11A Fie[d: Pmdhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA PDS Caliper Overview Body Region Analysis Survey Date: July 28, 2000 Tool Type: MFC40 No~ 00432 Tool Size: 2 3/4" No, of Fingers: 40 Analysed: R.A. Riche¥ Tubing: Size Weight Grade & Thread Nora. OD NomJD Nom. Upset 5.5 ins 17 ppf 1..-80 8TRS IPC 5.5 ins 4.892 ins 5.5 ins Penetration and Metal Loss (% wall) penetration body ~ metal loss body 0to 1to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Numberof[ointsanalysed(total= 296) Pene 0 46 170 77 1 2 Loss 2 289 4 1 0 0 Damage Configuration ( body ) 150 ~ Number of ioinB damaged (total = 251) _ 90 10 149 0 2 Damage Profile (% wall) penetration body ~ metal loss body 0 50 1 51 98 148 198 248 Bottom of Survey = 289.1 100 Analysis Overview page Anchom~e PDS CA R JOINT TABULATION SHI Pipe: 5.5 ins 17 ppf L-80 8TRS iPC Well: 02-11A Wall tt~ickness. Body: 0.304ins Upset = 0~304ins Field: Prudhoe Bay Nominal iD: 4.892 ins Company: BP Exploration (Alaska), Inc. Country: USA Date: July 28, 2000 penetration body metal loss body Joint Penetratio~ Metal Projection Minimum Damage profile No. Upset Bod' Loss Upset Body iD Comments [ (% wall) inches inches % % inches inches inches 50 10 1 .06 ~09 29 7 .03 .04 4.89 Line corrosion. ~ 2 0 .05 17 3 0 .02 4.91 Line shallow corrosion. 3 0 .07 24 4 0 .04 4,85 Line corrosion. 4 0 .07 24 $ 0 .04 4.88 Line corrosion. 5 0 .06 18 3 0 .04 4.92 Line shallow corrosion. 6 0 .05 17 2 0 .03 4.90 Line shallow corrosion. 7 0 .02 7 2 0 .03 4.89 8 0 .05 17 2 0 .04 4.90 Line shallow corrosion. 9 0 .02 7 2 0 .04 4.91 10 0 .06 20 2 0 .04 4.91 Line shallow corrosion. 11 0 .02 7 2 0 .04 4.91 12 0 .02 7 2 0 0 4.90 13 0 .02 7 2 0 0 4.89 14 0 .02 7 3 0 .04 4.93 15 0 .06 20 3 0 .04 4.90 Line shallow corrosion. 16 0 .02 7 2 0 .04 4.90 17 0 ~01 5 3 0 0 4.89 18 0 .03 9 3 0 .03 4.90 19 0 ,07 22 3 0 .05 4.89 Line corrosion. 20 0 .04 13 2 0 0 4,90 Line shallow corrosion. 21 0 .05 16 2 0 .04 4.90 Line shallow corrosion. 22 0 .07 22 3 0 .04 4.91 Line corrosion. 23 0 .04 14 2 0 .06 4.90 Line shallow corrosion. 24 0 .05 18 3 0 .04 4.90 Line shallow corrosion. 25 0 .02 7 I 0 0 4.91 26 0 ,02 5 2 0 0 4.92 27 0 .04 12 3 0 .04 4.88 Shallow pining. 28 0 .06 18 4 0 .1C 4.82 Line shallow corrosion. Lt. Deposits. 29 0 .02 7 2 0 0 4.91 30 0 .04 13 4 0 .03 4.87 Line shallow corrosion. 31 0 .03 9 2 0 .0( 4.87 32 0 .06 20 3 0 .04.04 4.88 Line corrosion. 33 0 .05 16 3 0 .04 4.89 Line shallow corrosion. 34 0 .07 22 2 0 4.90 Line corrosion. 35 0 .03 9 3 0 .04[ 4.90 36 0 .02 8 3 0 .06[ 4.90 37 0 .03 10 4 0 .04[ 4.88 38 0 .07 23 3 0 .03 4.88 Line corrosion. 39 0 .02 7 2 0 ,03] 4.88 40 0 .06 19 2 0 .02 4.92 Line shallow corrosion. 41 0 .02 6 2 0 0 4.90 42 0 .06 20 2 0 0 4.90 Line shallow corrosion. 43 0 .02 7 2 0 .03 4.90 44 0 .02 7 3 0 0 4.90 45 0 .02 7 3 0 0 4.89 46 0 .06 18 2 0 0 4.90 Line shallow corrosion. 47 0 .02 8 2 0 0 4.91 48 0 .07 22 3 0 .04 4.91 Line corrosion. 49 0 .03 8 3 0 0 4.88 50 0 .02 8 4 0 .04 4.87 P,pe abu,at,onspa e I RECEIVED AU6 0 9 2000 Ar;chorage PDS JOINT TABULATION SHI Pipe: 5.5 ins 17 ppf L-80 BTRS IPC Well: 02-11A Wall thickness. Body: 0.304ins Upset = 0,304ins Field: Prudhoe Bay Nominal ID: 4.892 ins Company: BP Exploration (Alaska), Inc. Country: USA Date: July 28, 2000 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (%wall) inches inches % % inches inches inches50 10 51 0 .03 9 2 0 0 4.88 52 0 .02 8 3 0 .03 4.89 52.1 0 .03 8 2 0 .04 4.87 PUP 52.2 0 0 0 0 0 0 4.92 SSSV 52.3 0 ,02 8 13 0 0 4.92 PUP 53 0 ~04 12 3 0 .04 4,88 Shallow pitting. 54 0 .05 17 I 0 .04 4.88 Line shallow corrosion. 55 0 .07 22 4 0 .05 4.87 Line corrosion. 56 0 .08 28 6 0 .06 4.88 Line corrosion. 57 0 .05 18 3 0 .05 4.87 Line shallow corrosion. 58 0 .05 15 3 0 .05 4.89 Line shallow corrosion. 59 0 .03 11 4 0 .05 4.88 Shallow pitting. 60 0 .05 16 3 0 .0,I 4.88 Line shallow corrosion. 61 0 .05 15 2 0 .1C 4~85 Line shallow corrosion. Lt. Deposits. 62 0 .04 12 4 0 .05 4.86 Shallow pitting. 63 0 .09 29 8 0 .0~ 4.86 Line corrosion. Lt. Deposits. 64 0 .04 14 3 0 .071 4.84 Line shallow corrosion. Lt. Deposits. 65 0 .08 27 7 0 .09J 4.88 Line corrosion. Lt. Deposits. 66 0 .04 12 3 0 .05j 4,86 SI]aJJow pitting. 67 0 .03 11 4 0 .06J 4.84 Shallow pitting. 68 0 .03 10 2 0 .08i 4.84 Lt. Deposits. 69 0 ~09 29 12 0 .07[ 4.85 Line corrosion, Lt. Deposits. 70 0 .03 11 3 0 .08 4.84 Shallow pitting. Lt, Deposits. 71 0 .08 27 14 0 07 4.89 Line corrosion. Lt. Deposits. 72 0 .06 20 3 .08 .08 4.86 Line shallow corrosion. Lt. Deposits. 73 0 .07 22 4 .06 .08 4.84 Line corrosion. Lt. Deposits. 74 0 .03 10 2 .05 .06 4.85 Lt. Deposits. 75 0 .04 12 3 0 .09 4.81 Shallow pitting. Lt. Deposits. 76 0 .09 3(} 4 0 .07 4.88 Line corrosion. Lt. Deposits. 77 0 .04 12 4 0 .10 4.82 Shallow pitting. Lt. Deposits. 78 0 .06 2(} 3 0 .06 4.85 Line shallow corrosion. Lt. Deposits. 79 0 .07 24 6 0 .12 4.81 Line corrosion. Lt. Deposits. 80 0 .04 12 4 0 .11 4.85 Shallow pitting. Lt_ Deposits. 81 .02 .04 14 2 .10 .07 4.84 Line shallow corrosion. Lt. Deposits, 82 0 .03 9 2 0 .06 4.84 83 0 .04 14 3 0 .06 4.83 Shallow pitting. 84 0 .04 14 3 0 .10 4.82 Shallow pitting. Lt. Deposits. 85 0 .03 I 3 0 .06 4.84 Shallow pitting. 86 0 .04 14 4 0 .07 4.82 Line shallow corrosion. 87 0 .06 19 3 0 .03 4.89 Line shallow corrosion. 88 0 .03 S 3 0 .05 4.88 89 0 .04 13 3 0 .05 4.87 Shallow pitting. 90 0 .06 21 3 0 .07 4.83 Line corrosion. Lt. Deposits. 91 0 .05 1~ 3 i 0 [ .05 4.85 Lineshallowcorrosion. 92 0 .05 16 3I [0 .09 4.84 Line shallow corrosion. LL Deposits. 93 0 .07 24 5 0 .07 4.86 Line corrosion. Lt. Deposits. 94 0 .05 17 7 0 .05 4.88 Line shallow corrosion. 95 0 ,06 2C 3 0 .05 4.83 Line shallow corrosion. 96 0 .07 [ 23 5 0 .06 4.87 Line corrosion. Lt. Deposits. 97 0 .02I 2 0 .06 4.89 PDS CA R JOINT TABULATION SH[ Pipe: 5.5 ins 17 ppf L-80 BTRS IPC Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: 02-11A Field: Prudhoe Bay Company: BP Exploration (Alaska}, Inc. ~ penetration body Country: USA ~ metal loss body Date: July 28, 2000 Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset 3ody ID Comments (% wall} inches inches % % inches inches inches 50 1ts 98 0 .03 112 3 0 .04 4.83 99 0 .06 2C 3 0 .06 4.89 Line shallow corrosion, ts 100 0 .07 24 4 0 .05 4.86 Line corrosion, ts 101 0 .03 3 0 .06 4.82 Lt. Deposits. 102 0 .06 lC. 2 0 .05 4.86 Line shallow corrosion. 103 0 .03 lC 3 0 .07 4.85 LL Deposits, 104 0 ,04 12 3 0 .08 4.84 Shallow pitting. Lt. Deposits. 105 0 .03 3 0 .06 4.85 106 0 .02 2 0 ,05 4.86 107 0 .03 11 2 0 .04 4.86 Shallow pitting, 108 0 .06 21 3 0 .05 4.85 Line corrosion.L~ 109 0 .02 3 0 .04 4.87 ~ 110 0 .04 1: 3 0 .04 4.85 Shallow pitting. 111 0 .06 1~ 3 0 .05 4.88 Lille shallow corrosion. ~ 112 0 .04 12 2 0 .04 4.88 Line shallow corrosion. 113 0 .32 10C 4 0 .05 4.87 Multiple HOLES ! ~ ~ ts ts ts 114 0 .05 l; 3 0 .07 4.83 Shallow pitting. Lt. Deposits. 115 0 .03 4 0 .06 4.85 Lt Deposits. 116 0 .06 [ lC~ 5 0 .05 4.84 Ltse shallow corrosion. 117 0 .08 ] 25 9 0 .06 4.85 Line corrosion, t.t. Deposits. ~ 118 0 .03[ 1£ 3 0 .07 4.84 Shallow pitting. LLDeposits. 119 0 .05 j 1~i 3 0 .07 4.85 Shallow pitting. Lt. Deposits. 120 0 .03 11! 3 0 .05 4.88 Sha ow pttng 121 0 .06 1c_ 4 .08 .11 4.81 Line shallow corrosion, Lt. Deposits. 122 0 .04 12 3 0 .08 4.84 [ Shallow pitting. Lt. Deposits, 123 0 .04 13 4 0 .05 4.84 Shallow pitting. t24 0 .05 17 3 0 .06 4.84 J Line shallow corrosion. 125 0 .06 18 10 0 .07 4.81 Shallow corrosion. Lt. Deposits, 126 0 .07 22 3 0 ,06 4.83 Line corrosion. 127 0 .03 !1 2 0 .05 4.86 Shallow pitting. 128 0 .03 10 3 0 .05 4.86 129 0 .03 11 3 0 .04 4.86 Shallow pitting. 130 0 .07 24 3 0 .11 4.82 Corrosion. Lt. Deposits. 131 j 0 .04 14 3 0 .07 4.78 Line shallow corrosion. Lt. Deposits. 132 [ 0 .08 26 9 .05 .09 4.87 Line corrosion. Lt. Deposits. ~ 133I 0 .03 11 3 0 .08 4.81 Shallow pitting. Lt. Deposits. 134 [ 0 i .06 20 3 .06 .07 4.86 isolated pitting. LL Deposits. 135 0I .07 22 3 0 .10 4.82 Line corrosion. Lt. Deposits. 136 0 ,04 13 3 0 .06 4.84 Shallow pitting. Lt. Deposits. 137 0 .07 24 4 0 .08 4.85 Line corrosion. Lt. Deposits. 138 0 .04 13 3 0 .07 4.82 Shallow pitting. Lt. Deposits. 139 ] 0 I .05 18 6 0 .06 4.81 Shallow pittints Lt. Deposits. 140 0 .05 16 5 0 .10 4.81 Shallow pittints Lt. Deposits. 141 0 .05 17 3 0 .07 4.82 Line corrosion. 142 0 .07 22 3 0 .09 4.83 Line corrosion. LL Deposits. 143 0 ~04 12 3 0 .06 4.83 Shallow pitting. Lt, Deposits. 144 0 .06 21 3 .05 .11 4.83 Line corrosion. Lt. Deposits. 145 0 .06 19 4 0 .08 4.83 Line shallow corrosion. Lt. Deposits. 146 0 .05 17 2 0 .1(3 4.81 Line silallow corrosion. Lt. Deposits. 147 0 .04 12 3 0 .08 4.83 Shallow pittints Lt. Deposits. ~ Pipe Tabulations page 3 RECE[VED Artshts'age PDS CAI3 OINT TABULATION SH1 Pipe: 5.5 ins 17 ppf b80 BTRS IPC Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: Field: Company: Country: Date: 02dlA Prudhoe Bay BP Exploration (Alaska}, Inc. USA July 28, 2000 penetration body metal loss body Penetration Minimum ID Co~nments inches 4.83 4.80 4.82 4.79 4.83 4.80 4.82 4.80 4.82 4.80 4.83 4.83 4.80 4.85 4.83 4.84 4.82 4.81 4.87 4.78 4.84 4.81 4.80 4.83 4.81 4.81 4.83 4.84 4.80 4,86 4.80 4.79 4.87 4.84 4.82 4.80 4.80 4.84 4.85 4.83 4.84 4.82 4.83 4.82 4.85 4.82 4.82 4.83 4.85 4.84 Damage profile (% wall) 50 100 Pipe Tabulations page 4 RECEIVED AU6 0 9 PDS CA R JOINT TABULATION SHI Pipe: 5.8 ins 17 ppf L-80 BTRS IPC Wall thickness~ Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: 02-1 lA FieJd: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Date: July 28, 2000 Minimum [D inches 4.86 4.85 4.84 4,83 4.89 4.88 4.81 4.86 4.87 4.85 4.85 4.85 4.83 ,071 4.87 4.87 4.83 4.85 4.85 4.83 4.81 4.86 4.86 4.86 4.82 4~84 4.82 4,82 4.84 4.81 4.85 4.88 4.85 4.85 4.89 4.86 4.90 4.85 4.84 4.87 4.84 4.83 4.84 4.87 4.87 4.83 4.86 4.86 4.87 4.87 4.77 Shallow pitting. Lt. Deposits. Line corrosion. Lt, Deposits. Line shallow corrosion. Deposits. Pipe Tabu[a~ons page 5 ~penetr~ion body ~metalloss body Damage profile (% wall) 50 100 PDS JOINT TABULATION SHI Pipe: 5.5 ins 17 ppf L-80 BTRS IPC Well: 02-11A Wall thickness. Body: 0.304ins Upset = 0.304ins Field: Pmdhoe Bay Nominal ID: 4.892 ins Company: BP Explorafion (Alaska), inc. Country: USA Date: July 28, 2000 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inches tsches 3 50 10 248 0 ~06 20 3 0 ~05 4.87 Line corrosion. ~ 249 0 .06 18 3 0 .04 4.88 Line shallow corrosion. 250 0 .08 28 7 .05 .08 4.83 Line corrosion. I.t. Deposits. 251 0 .04 12 3 0 .06 4.84 Shallow pitting. LL Deposits. 252 0 .04 14 7 0 .03 4.90 Line shallow corrosion. ~ 253 0 .04 12 5 0 .07 4.85 Shallow pitting. Lt. Deposits. 254 0 .05 15 3 0 .06 4.87 Shallow pitting. Lt. Deposits. ~ 255 0 .08 25 3 0 .06 4.87 Line corrosion. ~ 256 0 .03 11 3 0 .05 4.85 Shallow pitfing. 2.57 0 .04 12 3 0 .04 4.87 Line shallow corrosion. 258 0 .05 16 3 0 .08 4.82 Shallow pitting. Lt. Deposits. ~ 259 0 .05 17 3 0 .11 4.82 Shallow pitting. Lt. Deposits. ti 260 0 .05 17 3 0 .04 4.86 Line shallow corrosion, ti 261 0 .06 19 3 0 .04 4.85 Line shallow corrosion. ~ 262 0 .08 26 7 0 .0~ 4,90 Line corrosion. Lt. Deposits. ~ 263 .09 .07 22 3 0 .05 4.87 Line corrosion. ~ 264 .03 .06 19 4 .10 .06 4,83 Line shallow corrosion. ~ 265 0 .03 10 5 0 0 4.89 266 .05 ,06 21 4 0 .07 4.87 Line corrosion. LL Deposits. ts 267 0 ,04 13 2 0 .05 4.84 Shallow piing. 268 0 .06 ~8 4 0 ,05 4.86 Line shallow corrosion. ~ 269 0 .05 16 3 0 .05 4.86 Line shallow corrosion, ti 270 0 ,07 24 3 0 .05 4.87 Line corrosion, ts I 271 .10 .10 34 5 0 .05 4.86 Corrosion, ts 272 0 ,06 21 5 0 .04 4.84 Line corrosion, ts 273 0 .06 19 3 0 .041 4.88 Shallow pitting, ts 274 0 .03 11 3 0 .03 4.86 Shallow pitting. 275 .07 .09 30 5 0 .031 4.89 Line corrosion, ts 276 0 ,08 28 4 0 .03 4.88 Line corrosion, ts 277 0 .05 17 3 0 .03 4.86 Shallow pitting. ~ 278 0 .07 24 3 0 .04i 4.87 Isolated pitting, ts 279 0 .07 22 3 0 0 4.88 IsoJated pitting, ts 280 0 .06 20 5 0 .04 4.88 Isolated pitting. ~ 281 0 .06 21 4 0 ,03 4.87 Line corrosion, ts 282 0 .06 21 3 0 .04 4.87 Line corrosion, ts 283 0 .07 23 4 0 .04 4.86 Line corrosion, ts 284 0 .07 22 3 0 .06 4.86 Line corrosion. Lt. Deposits. ts 285 0 .08 27 5 0 .04 4.87 Line corrosion, ts 285.1 0 .07 23 3 0 .04 4.86 PUP Line corrosion, ts 285.2 0 0 ~ 0 0 0 4.87 Sliding Sleeve 285.3 0 .09 31 5 0 .04 4.87 PUP Isolated pitting, ts 286 .06 .05 15 3 0 .07 4.85 Shallow pitting. Lt. Deposits. 287 0 .08 25 6 0 .07 4.86 Line corrosion. Lt. Deposits. ts 287.1 0 0 0 0 0 0 4.86 PBR 287.2 0 .05 17 3 0 .04 4.86 PUP Line shallow corrosion. ~ 287.3 0 0 (3 0 0 0 4.98 Packer 287.4 .12 .19 64 26 0 0 4,98 PUP Corrosion. ~ tsts 288 0 .10 32 4 0 .05 4.86 Line corrosion. 289 .07 .10 32 7 0 .20 4.73 Line corrosion. Deposits. ts 289.1 0 .05 18 7 0 .05 4.87 PUP Shallow pitting. ~ Damage Classifications Penetration/projection class, in order of damage severity Pipe Tabu[afions page6 Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of circumference, but depth range does not exceed 1 * pipe iD Line- damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference General - damage depth range exceeds 1 * pipe ID and/or extends more than 20% of circumference /\]askti ~'i[ & ~:ts~ Co~, C~titsissits~ Attshts'~ti Isolated - damage depth range does r (ceed 5 * pipe ID or extend more than 20% o~: ~umference Damage reporting threshold = 30 thou i, .... es deviation in body, 50 thou in upset. Modal L.?.~.ength = 0.500 feet~ RECEIVED AUG 0 9 .~'~ Alaska. u,:~ & ~q~.s Cons. ,~,..~:-~,:,,~, Anchomge PDS Caliper Sections Well: 024 1A Field: Prudhoe Bay Company: BP Exploration (Alaska), inc. Country: USA Tubing: 5.5 ins 17 ppf U80 J3TRS IPC Survey Date: July 28, 2000 Too[ Type: MFC40 No. 00432 Too[ Size: 2 3/4" No. of Fingers: 40 Analysed: R.A. Richey Cross section for Joint 113 Tool speed = 69 Nominal ID = 4.892 Nominal OD = 5.500 Remaining wall area = 96 % Tool deviation = 51 ° at depth 4351.38 ft Finger 31 Penetration: 0.322 ins Hole HIGH SIDE = UP Cross-Sections page 1 PDS Caliper Sections Well: 02-1 lA Field: Prudhoe Bay Company: BP Exploration (Alaska), inc. Country: USA Tubin 5.5 ins L-80 BTRS IPC Survey Date: July 28, 2000 Tool Type: MFC40 No. 00432 Tool Size: 2 3/4" No. of Fingers: 40 Analysed: R.A. Richey Cross section for Joint 219 Tool speed ~ 70 Nominal ID ~ 4.892 Nominal OD = 5.500 Remaining wall area -- 97 % Tool deviation ~ 60 ° at depth 83O7.22 ft Finger 33 Radius: 2.718 ins Hole HIGH SIDE = UP Cross-Sections page 2 Well: 02-11A Field: ?rudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Tubin 5.5 ins 17 ppf L~80 BTRS IPC PDS Caliper Sections Survey Date: July 28, 2000 Tool Type: MFC40 No. 00432 Tool Size: 2 3/4" No. of Fingers: 40 Analysed: R.A. Richey Cross section for Joint 287.4 Tool speed = 67 Nominal iD = 4,892 Nominal OD = 5.500 Remaining wall area = 75 % Tool deviation = 48 ° at depth 10905.49 ft Finger 11 Radius = 2,672 ins Corrosion 0.19 in = 64% Wall Pen. HIGH SIDE = UP RECEIVED A!J6 0 9 Cross-Sections page 3 Well: 02-11A Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA 5.5ins 17ppf L-80 BTRS IPC PDS Caliper Sections Survey Date: July 28, 2000 Tool Type: MFC40 No. 00432 Tool Size: 2 3/4" No. of Fingers: 40 Analysed: R.A. Richey Cross section for Joint 289 Tool speed -- 61 Nominal ID = 4.892 Nominal OD = 5.500 Remaining wall area = 94 % Tool deviation = 43 ° at depth 10964.51 ft Finger 36 Projection =-0.198 ins Deposits Min. ID = 4.73 in. HIGH SIDE = UP AUg 0 9 Artchm-ags Cross-Sections page 4 PDS . LIPER JOINT TALLY SHEET Pipe: 5.5 ins 17 ppf L-80 BTRS IPC Wall thickness. Body: 0.304ins Upset-- 0.304ins Nominal ID: 4.892 ins Well: 02-11A Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Date: July 28, 2000 Joint Depth Length Measured Type No. ID feet feet inches 1 -.20 37.04 4.952 2 36.84 39.65 4.962 3 76.49 38.88 4.946 4 115.37 37.82 4.946 5 153.19 39.55 4.960 6 192.74 39.48 4.964 7 232.22 39.70 4.946 8 271.92 39.58 4.958 9 311.50 39.59 4.963 10 351.09 39.47 4.963 11 390.56 39.78 4.964 12 430.34 39.46 4.964 13 469.80 39.45 4.945 14 509.25 39.55 4.963 15 548.80 39.04 4.959 16 587.84 39.36 4.951 17 627.20 38.89 4.943 18 666.09 39.02 4.947 19 705.11 39.70 4.966 20 744.81 39.32 4.966 21 784.13 39.68 4.961 22 823.81 39.54 4.958 23 863.35 39.61 4.959 ,24 902.96 39.68 4.955 25 942.64 39.57 4.952 26 982.21 39.33 4.960 27 1021.54 39.32 4.957 28 1060.86 39.44 4.949 29 1100.30 39.59 4.965 30 1139.89 39.74 4.960 31 1179.63 39.57 4.954 32 1219.20 39.60 4.961 33 1258.80 39.40 4.946 34 1298.20 39.43 4.965 35 1337.63 39.34 4.947 36 1376.97 39.68 4.955 37 1416.65 39.60 4.948 38 1456.25 38.92 4.949 39 1495.17 43.43 4.936 40 1538.60 39.64 4.964 41 1578.24 39.59 4.951 42 1617.83 39.42 4.952 43 1657.25 39.58 4.966 44 1696.83 39.49 4.961 45 1736.32 39.55 4.938 46 1775.87 39.75 4.955 47 1815.62 39.27 4.948 48 1854.89 38.48 4.963 49 1893.37 39.43 4.948 50 1932.80 39.23 4.949 Joint Depth Length Measured Type No. ID feet feet inches 51 1972.03 41.62 4.951 52 2013.65 39.18 4.945 52.1 2052.83 14.69 4.941 Pup 52.2 2067.52 17.65 nominal SSSV 52.3 2085.17 8.48 4.925 Pup 53 2093.65 39.37 4.951 54 2133.02 39.42 4.944 55 2172.44 38.61 4.958 56 2211.05 37.01 4.947 57 2248.06 38.35 4.952 58 2286.41 35.73 4.959 59 2322.14 38.19 4.961 60 2360.33 38.89 4.944 61 2399.22 38.03 4.945 62 2437.25 34.67 4.956 63 2471.92 35.45 4.941 64 2507.37 38.40 4.945 65 2545.77 37.08 4.952 66 2582.85 38.25 4.950 67 2621.10 38.14 4.935 68 2659.24 34.95 4.952 69 2694.19 35.75 4.921 70 2729.94 36.32 4.939 71 2766.26 36.48 4.930 72 2802.74 32.98 4.945 73 2835.72 43.39 4.938 74 2879.11 31.69 4.946 75 2910.80 38.89 4.952 76 2949.69 38.24 4.958 77 2987.93 37.60 4.933 78 3025.53 38.30 4.945 79 3063.83 32.58 4.934 80 3096.41 38.59 4.943 81 3135.00 36.76 4.945 82 3171.76 34.48 4.936 83 3206.24 37.18 4.931 84 3243.42 34.04 4.940 85 3277.46 34.86 4.927 86 3312.32 34.83 4.941 87 3347.15 39.53 4.931 88 3386.68 38.14 4.945 89 3424.82 36.41 4.954 90 3461.23 35.39 4.945 91 3496.62 37.05 4.950 92 3533.67 37.40 4.944 93 3571.07 38.61 4.952 94 3609.68 36.70 4.948 95 3646.38 35.49 4.951 96 3681.87 34.21 4.959 97 3716.08 39.25 4.951 Joint Tally page I RECEIVED Alaska Oil &,¢ ,--.,. :"" "" * Cogs. Ar~chorage PDS .LIPER JOINT TALLY SHEET Pipe: 5.5 ins 17 ppf L-80 BTRS IPC Wall thickness. Body: 0.304ins Upset-- 0.304ins Nominal ID: 4.892 ins Well: 02-11A Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Date: July 28, 2000 Joint Depth Length Measured Type No. ID feet feet inches 98 3755.33 40.10 4.910 99 3795.43 37.50 4.965 100 3832.93 37.65 4.952 101 3870.58 37.14 4.944 102 3907.72 37.18 4.953 103 3944.90 36.13 4.938 104 3981.03 36.26 4.940 105 4017.29 39.29 4.937 106 4056.58 39.36 4.939 107 4095.94 39.56 4.935 108 4135.50 39.66 4.941 109 4175.16 39.19 4.935 110 4214.35 39.97 4.934 111 4254.32 39.42 4.950 112 4293.74 39.19 4.952 113 4332.93 39.14 4.941 114 4372.07 39.40 4.934 115 4411.47 39.65 4.944 116 4451.12 39.29 4.924 117 4490.41 39.78 4.940 118 4530.19 39.33 4.935 119 4569.52 39.54 4.939 120 4609.06 37.27 4.950 121 4646.33 40.19 4.941 122 4686.52 39.27 4.938 123 4725.79 39.19 4.926 124 4764.98 39.73 4.937 125 4804.71 39.65 4.922 126 4844.36 39.65 4.928 127 4884.01 39.03 4.935 128 4923.04 39.78 4.948 129 4962.82 34.31 4.930 130 4997.13 38.23 4.944 131 5035.36 35.24 4.943 132 5070.60 37.02 4.941 133 5107.62 35.61 4.940 134 5143.23 37.91 4.958 135 5181.14 37.43 4.935 136 5218.57 37.95 4.943 137 5256.52 38.78 4.947 138 5295.30 36.87 4.932 139 5332.17 39.87 4.938 140 5372.04 38.10 4.930 141 5410.14 37.07 4.930 142 5447.21 35.79 4.948 143 5483.00 38.25 4.935 144 5521.25 39.98 4.939 145 5561.23 38.56 4.929 146 5599.79 36.35 4.937 147 5636.14 36.02 4.934 Joint Depth Length Measured Type No. ID feet feet inches 148 5672.16 37.72 4.947 149 5709.88 37.51 4.927 150 5747.39 37.70 4.934 151 5785.09 37.43 4.916 152 5822.52 34.62 4.932 153 5857.14 36.61 4.943 154 5893.75 38.74 4.943 155 5932.49 36.89 4.918 156 5969.38 37.36 4.942 157 6006.74 37.42 4.924 158 6044.16 38.79 4.942 159 6082.95 38.46 4.935 160 6121.41 35.12 4.926 161 6156.53 37.72 4.952 162 6194.25 38.57 4.941 163 6232.82 37.88 4.929 164 6270.70 38.71 4.943 165 6309.41 37.70 4.932 166 6347.11 35.45 4.942 167 6382.56 37.88 4.917 168 6420.44 35.45 4.931 169 6455.89 37.64 4.945 170 6493.53 37.55 4.936 171 6531.08 36.42 4.929 172 6567.50 37.08 4.928 173 6604.58 35.61 4.931 174 6640.19 35.75 4.935 175 6675.94 38.41 4.938 176 6714.35 33.77 4.920 177 6748.12 36.91 4.933 178 6785.03 37.13 4.930 179 6822.16 36.36 4.938 180 6858.52 34.57 4.946 181 6893.09 38.69 4.935 182 6931.78 36.91 4.933 183 6968.69 37.04 4.942 184 7005.73 3 7.89 4.947 185 7043.62 36.84 4.952 186 7080.46 37.80 4.953 187 7118.26 35.26 4.936 188 7153.52 35.07 4.938 189 7188.59 34.49 4.925 190 7223.08 35.84 4.933 191 7258.92 36.63 4.937 192 7295.55 39.28 4.948 193 7334.83 33.01 4.939 194 7367.84 3 7.85 4.930 195 7405.69 37.84 4.927 196 7443.53 36.60 4.943 197 7480.13 37.76 4.931 Joint Tally page 2 RECEIVED AUG 0 9 200.[' Anchol'age PDS.. ..... LIPER JOINTTALLY SHEET Pipe: 5.5 ins 17 ppf L-80 BTRS IPC Wall thickness. Body: 0.304ins Upset-- 0.304ins Nominal ID: 4.892 ins Well: 02-11 A Field: Prudhoe Bay Company: BP Exploration (Alaska), Inc. Country: USA Date: July 28, 2000 Joint Depth Length Measured Type No. ID ~et ~et inches 198 7517.89 38.04 4.946 199 7555.93 39.77 4.947 200 7595.70 35.39 4.944 201 7631.09 35.01 4.929 202 7666.10 34.34 4.954 203 7700.44 34.54 4.939 204 7734.98 36.51 4.932 205 7771.49 37.53 4.940 206 7809.02 38.25 4.956 207 7847.27 34.88 4.954 208 7882.15 36.85 4.940 209 7919.00 36.79 4.936 210 7955.79 37.92 4.948 211 7993.71 35.77 4.950 212 8029.48 34.96 4.946 213 8064.44 36.84 4.924 214 8101.28 38.81 4.948 215 8140.09 37.08 4.956 216 8177.17 38.21 4.925 217 8215.38 36.42 4.938 218 8251.80 38.27 4.944 219 8290.07 37.78 4.957 220 8327.85 39.63 4.942 221 8367.48 38.87 4.940 222 8406.35 33.19 4.940 223 8439.54 34.00 4.901 224 8473.54 35.09 4.934 225 8508.63 35.21 4.934 226 8543.84 40.17 4.939 227 8584.01 34.16 4.936 228 8618.17 39.82 4.954 229 8657.99 33.94 4.943 230 8691.93 36.91 4.937 231 8728.84 39.30 4.954 232 8768.14 36.90 4.945 233 8805.04 35.00 4.947 234 8840.04 37.45 4.938 235 8877.49 36.82 4.946 236 8914.31 39.35 4.945 237 8953.66 35.87 4.938 238 8989.53 38.87 4.936 239 9028.40 34.71 4.954 240 9063.11 37.58 4.943 241 9100.69 39.25 4.933 242 9139.94 39.54 4.901 243 9179.48 37.02 4.950 244 9216.50 37.36 4.928 245 9253.86 36.94 4.951 246 9290.80 34.26 4.951 247 9325.06 38.57 4.955 Joint Depth Length Measured Type No. ID ~et ~et inches !248 9363.63 36.77 4.960 ,. 249 9400.40 37.15 4.962 250 9437.55 38.48 4.954 251 9476.03 34.12 4.952 252 9510.15 35.41 4.945 253 9545.56 38.11 4.946 254 9583.67 36.94 4.953 255 9620.61 37.79 4.954 256 9658.40 38.18 4.946 257 9696.58 36.56 4.942 258 9733.14 38.38 4.939 259 9771.52 36.99 4.953 260 9808.51 38.00 4.942 261 9846.51 34.62 4.924 262 9881.13 38.27 4.947 263 9919.40 38.49 4.947 264 9957.89 38.28 4.922 265 9996.17 39.84 4.946 266 10036.01 35.79 4.957 267 10071.80 36.11 4.935 268 10107.91 38.06 4.953 269 10145.97 37.19 4.950 270 10183.16 37.86 4.954 271 10221.02 34.72 4.954 272 10255.74 37.08 4.940 273 10292.82 39.76 4.949 274 10332.58 37.99 4.951 275 10370.57 36.78 4.953 276 10407.35 38.27 4.947 ~277 10445.62 37.42 4.948 278 10483.04 34.16 4.942 279 10517.20 38.07 4.953 280 10555.27 36.85 4.954 281 10592.12 34.52 4.943 282 10626.64 37.89 4.955 283 10664.53 38.62 4.942 284 10703.15 34.94 4.960 285 10738.09 36.42 4.942 285.1 10774.51 8.62 4.924 Pup 285.2 10783.13 6.25 nominal SIdSIv 285.3 10789.38 9.45 4.928 Pup 286 10798.83 38.25 4.955 287 10837.08 38.52 4.940 287.1 10875.60 5.90 nominal PBR 287.2 10881.50 15.49 4.921 Pup 287.3 10896.99 5.80 nominal Packer 287.4 10902.79 3.81 nominal Pup 288 10906.60 37.93 4.957 289 10944.53 39.27 4.947 289.1 10983.80 unknown 4.947 PUp Joint Tally page3 R E C E IV E D AUG 0 9 Alaska, Oil & (~,:s Co~s. Commission Anchorag~ Schlumberger NO. 363 7/26/00 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-I'N: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-11A LEAK DETECTION LOG 000707 I 1 D.S. 9-18 ,J,(I t. INJECTION PROFILE 000708 I 1 D.S. 9-19 ~ INJECTION PROFILE 000708 I 1 D.S. 17-01 STATIC PRESSURE SURVEY 000706 I I , D.S. 17-02 STATIC PRESSURE SURVEY 000706 I I / ? ?. o~/o l -~o- o'/O SlGNED~. DATE: AUG 04 2000 Alaska 0il & Gas Cons. Commission Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate_ Plugging _ Pertorate_ Pull tubing _ Alter casing _ Repair well _ Other_X (POGLM) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 56 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Ser~ce__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 918' FNL, 4364' FEL, Sec. 36, T11N, R14E, UM 02-11A At top of productive interval 9. Permit number / approval number 1808' FNL, 1976' FEL, Sec. 01, T10N, R14E, UM 98-126 At effective depth 10. APl number 50-029-20273-01 At total depth 11. Field / Pool 1545' FNL, 2851' FEL, Sec. 01, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 13337 feet Plugs (measured) Tagged PBTD @ 13300' MD (9/26/1998) true vertical 9026 feet Effective depth: measured 13300 feet Junk (measured) true vertical 9029 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 1 10' 20" 262 sx AS 1 1 0' 1 1 0' Surface 2655' 13-3/8" 2706 cubic it CS III & 460 cubic it 2711' 2702' Class G Production 11420' 9-5/8" 2218 cubic it Class G 1 1476' 8703' Liner 347' 3-1/2" / 2-7/8" 17.5 bbls 15.8 ppg Neat Class G 13337' 9026' Perforation depth: measured 12420'- 12820'; 13000'- 13300'. true vertical 9050' - 9061'; 9059' - 9029'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 11476' MD; 4-1/2", 12.6#, N-80 PCT @ 11814' MD. Packers & SSSV (fype & measured depth) 9 5/8" X 5 1/2" BOT RHR PACKER @ 10898' MD; 5 1/2" HES RCP @ 11026' MD. 5 1/2" OTIS RQM SSSV @ 2076' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) Subsequent to operation 1422 1287 898 225 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil ._X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~-,~t.~ % ~ Title Arco Wells Group Supervisor Date '~""'~- ~'? Erin Oba " Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE State of Alaska AOGCC, Lori Taylor 3001 Porcupine St. Anchorage, AK 99501 Well Reference Data: Well No: 02-1lA Field: County: State: Prudhoe Bay Unit North Slope Alaska Date: 03/19/99 API No: 500292027301 BHI Job#: 100256 Enclosed is the following data as listed below: Log Type Bluelines Navigamma USMPR DPR/MDL/MDP TOTALS: Log Type Navigamma USMPR MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks Survey Listing ASCII Disks LIS Tape Image File Disks LIS Verification Report & Listings Depth Shift Monitor Plot Upon Receipt, Please sign and fax to: Baker Hughes INTEQ 2 2 1999 Received by: ~] & Gas ' - mmi km GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12019 Companl Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 11/4/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape NOV 06 1998 SIGN DATE: anc~0rage Please sign and retu~ne copy of this transmi~al to Sherde at the above address or fax to (907) 562-6521. Thank " -~ STATE OF ALASKA ' - ---.. ALASKA OIL AND GAS CONSERVATION COMMISSION O~ EC~ ~ ~'~" ~ WELL COMPLETION OR RECOMPLETION REPORT AND L - 1 Status of Well Classification of Servic~%,~c~r.Ffr'~ Oil_X Gas__ Suspended__ Abandoned__ Service__ ' ~"~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 98-126 ~,lr~(~, 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20273-01 4 Location of well at surface ............... .. ~ ~ 9 Unit or Lease Name 921' FNL, 916' FWL, Sec 36, T11N, R14E, UM ~ ':;~;'.':'?i_dT~0~j i~H'~_ PRUDHOE BAY UNIT At Top Producing interval i~/'"~.~'~j~i';'/A i ~; ! 10Well Number 1808' FNL, 1976' FEL, Sec 1, T10N, ,14E, UM. _.._.~,-_/_.~.~,¢', 02-1 lA At Total Depth i ¥~XJ~P ~ ' 11 Field and Pool 1547' FNL, 2854' FEL, Sec 1, T10N, R14E, UM. i.'---'~''¢%~-~'--'~--''¢~ ,.~.-~. .......... ~.! PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 56' RKB ADL 28311 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 09/03/98 09/22/98 09/27/98 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 13337' MD / 9026' TVD 13300' MD / 9029' TVD YES_X NO 2075' MD 1900' (approx) 22 Type Electric or Other Logs Run GR/CCL/CNL & MWD. 23 CASING, LINER AND CEMENTING RECORD SE'I-I'ING DEPTH CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 96# H-40 Surface 110' 30" 262 Sx AS 13-3/8" 72# N-80 Surface 2711' 17-1/2" 2706 Ft3 CS III & 460 Ft'3 Class G 9-5/8" 47# N-80/S00-95 Surface 11476' 12-1/4" 2218 Ft'3 Class G 2-7/8" 6.5# L-80 11026' 13336.55' 3-3/4" 17-1/2 bbls of 15.8 ppg Neat 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 MD 5-1/2" Tbg 11476' 10897' 12420' - 12820' MD; 9050' - 9061' TVD; @ 4 spf. I 13000' - 13300' MD; 9059' -9029' TVD; @ 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27PRODUCTION lq D i k i ^ i Date First Production Method of Operation (Flowing, gas lift, etc.) ~ J not on production n/a Date of Test Hours Tested i PRODUCTION FOR OIL - BBL ~S - MCF WATER - BBL CHOKE SIZE I GOR I TEST PERIOD__ Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MOF WATER - BBL OIL GRAVITY - APl (tort) 24 HOUR RATE _X 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 i$ submitted as directed per the 10-401 form approved 7/10/98 (Permit # 98-126). Submit in duplicate --orm 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Sag River Top Shublik Top Top Sadlerochit Top Zone 2 (other pics) GEOLOGIC MARKERS MEAS DEPTH 11178' 11227' 11334' TRUE VERT DEPTH 8484' 8520' 8598' 9037' FORMATION TESTS 12320' Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. alaska 0ii ~,. 6a~ C0r~s. ~B~,I, Anchora§s 31 LIST OF ATTACHMENTS Summary of 02~1 lA CT Sidetrack Drilling Operations + Survey. 321 hereby cedify that the foregoing is true and correct to the best of my knowledge Erin Oba Engineering Supervisor Date INSTRUCTIONS Prepared by Paul Rauf 263-4990 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. 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 cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Rev. 7-1-80 DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 8/31/98 - 9/02/98: MIRU CTU. PT'd BOPE. RIH & tagged TOC @ 11372' MD. PT'd cement & 5-1/2" tbg to 1500 psi - ok. POOH. PT'd BOPE body to 3500 psi. RIH w/BHA & milled cement to 11470' MD. POOH w/BHA. 9/03/98: RIH w/window mill &time drilled f/11464' to 11466' MD. POOH w/BHA. 9/04/98: RIH &time drilled f/11467' to 11470'. POOH w/BHA. 9/05/98: RIH w/BHA & time drilled to 11471'. POOH w/BHA. RIH & milled window. 9/06/98: Milled to 11460' MD (corrected). POOH. RIH & tagged BTM. 9/07/98: Time milled to 11474'. POOH w/BHA. RIH & tagged BTM & began time milling. 9/08/98: Milled window through the 5-1/2" tbg & 9-5/8" casing. Corrected top of window @ 11476'. Corrected window BTM @ 11481'. Drilled into FM to 11490'. POOH. RIH & dressed window area. Drilled to 11476' MD. 9/09/98: POOH & PT'd BOPE. RIH w/bi-centered bit to 11476'. Unable to pass through window. POOH. 9/10/98: RIH & drilled to 11499'. Pumped water into FM to confirm casing exit. POOH w/BHA. Worked on reel motor. RIH to 11487'. 9/11/98: Drilled to 11581' MD. POOH. RIH w/& drilled to 11620'. Displaced well to FIo Pro. 9/12/98: Drilled to 11730'. PUH to window & performed LOT to 9.4 EMW. POOH. RIH to window. MWD trouble. 9/13/98: Drilled to 11958'. POOH to troubleshoot MWD equip. 9/14/98: RIH & drilled to 12240' w/periodic backreaming of selected intervals. 9115~98: Drilled to 12514' w/shod trips to window. Swap to new mud. Drilled to 12624'. 9/16/98: Drilled to 12755' & POOH. BOPE tested. 9/17/98: RIH & drilled to 12980'. Page 1 2-11A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS 9/18/98: Drill ahead to 12991' MD. POOH. RIH & drilled to 13130' MD. 9/19/98: Oriented & drilled to 13181' POOH to change out motor & add drill pipe for length. Performed rig maintenance. 9/20/98: Continued Rig maintenance. RIH w/2-1/16" CS Hydril pipe & BHA. 9121198: Drilled f/13181' to 13194'. MWD failure - POOH. RIH & reamed f/12275' to 12305'. Tagged BTM. 9/22/98: Drilled to 13207' w/shod trips to window. MWD malfunctioned, drilled on to TD @ 13307' MD. Reamed f/ 12283' to BTM. Conditioned OH & spotted new FIo Pro while POOH. 9/23/98: RIH w/liner assembly & landed it @ 13300'. 9/24/98: Pumped 17.5 bbls of 15.8 ppg Neat Class G Cement to cement liner in place. Bumped plug. Squeezed to a max pressure of 1000 psi. Pumped Biozan sweep to clean out liner. POOH. PT'd BOPE. 9/25/98: RIH w/GR/CNL./CCL logging tools. Tagged TOC @ 12945' MD. Logged OH & POOH. Identified TOL @ 11026'. TD corrected to 13337'. RIH & PT'd liner lap. Milled cement stringers to 13300'. Circulated clean FIo Pro in liner while POOH. 9/26/98: RIH w/perf guns & tagged PBTD @ 13300' (landing collar). Shot 700' of initial perforations located @: 12420' - 12820' MD (Zone 2) 13000' - 13300' MD (Zone 2) Used 2-1/8" carriers & shot all perfs @ 4 SPF. POOH w/guns. ASF. 9/27/98: RIH w/stinger/nozzle to 11026' MD. Displaced well to Crude. POOH. RDMOL. 10/14/98 - 10/15~98: RIH & ran a 5-1/2" RCP packer to the liner top @ 11038' SLM. Set rcp packer @ 11029' SLM. Placed well on initial production & obtained a valid well test. Page 2 ~ 8500 ~- 8600 8700- - 8800- 8900 I-- 9OOO I 9100 ARCO Alaska, Inc. Well ' 2-11A Location · North Slope, Alaska Structure · D.S. 2 Field · Prudhoe Bay East (feet) -> 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2;500 2400 2500 2600 2700 2800 2900 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I lie on - 8516.85 lvd, 5614.57 S, 2733,58 2-11 ehs ~~ 5 I.D. & find of Build - 8@85.00 lYd, 6036.51 $, 934.07 [ · 2-11bbs/ lTie on - 43.04 Inc, 11300.00 Md, 8516.85 Tvd, -1379.69 Vs Kick off Point ~3 2-1 lehs ..... i2-11bhs T.D. ,9 End of Build/Turn - 90.88 Inc, 13662.10 Md, 8985.00 Tvd, 468.63 Vs I I I I I I I I iI i I I I i I I I I i I I I i I I II I I I I I I I I I I I i I I I 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 .300 200 100 0 100 200 .500 400 500 600 Vertical Section (feet) -> Azimuth 256.80 with reference 0.00 N, 0.00 W from 02-11A 56OO 5700 5800 0 5900 ,,-I- 6000 ,,,,_,,. 6100 I v 6200 6300 6400 ARCO Alaska, [nc. O.S. 2 2-11A 02-11A Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 2-11A Our ref : svy223 License :API 50-029-20273-01 Date printed : 9-0ct-98 Date created : 16-Sep-98 Last revised : 9-0ct-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 686727.040,5951179.040,999.00000~N Slot location is n70 16 8.400,w148 28 56.169 Slot Grid coordinates are N 5950281.110, E 687666.510 Slot local coordinates are 921.02 S 916.96 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska~ Inc, SURVEY LISTING Page 1 D.S. 2,2-11A Your ref : 2-11A Prudhoe Bay,North Slope~ Alaska Last revised : 9o0ct-98 Measured Inclen Azim~Jth True Vert R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 11300.00 43.04 156.44 8516.85 5614.57S 2733.58E 1.84 -1379.69 690538.38 5944736.43 11400.00 42.26 156.84 8590.40 5676.775 2760.45E 0.83 -1391.65 690566.78 5944674.92 11450.00 41.88 156.79 8627.52 5707.56S 2773.64E 0.76 -1397.46 690580.73 5944644.46 11470.00 41.72 156.84 8642.43 5719.82S 2778.89E 0.82 -1399.77 690586.28 5944632.34 11536.70 31.60 149.70 8695.89 5755.42S 2796.49E 16.44 -1408.78 690604.76 5944597.19 11609.57 40.34 158.68 8754.85 5793.985 2814.74E 13.98 -1417.75 690623.96 5944559.10 11681.10 55.40 182.70 8803.08 5845.65S 2821.87E 32.36 -1412.89 690632.37 5944507.62 11702.79 60.30 188.30 8814.62 5863.915 2820.09E 31.42 -1406.99 690631.04 5944489.32 11774.30 71.10 198.50 8844.07 5927.05S 2804.79E 19.91 -1377.68 690617.32 5944425.83 11792.00 72.30 202.00 8849.63 5942.81S 2798.98E 19.96 -1368.42 690611.89 5944409.93 11801.40 72.60 203.80 8852.47 5951.07S 2795.49E 18.53 -1363.14 690608.61 5944401.59 11841.70 72.10 208.40 8864.69 5985.55S 2778.60E 10.95 -1338.83 690592.58 5944366.70 11892.40 69.50 214.00 8881.37 6026.49S 2753.83E 11.62 -1305.37 690568.84 5944325.16 11921.40 68.40 218.20 8891.79 6048.35S 2737.89E 14.04 -1284.86 690553.45 5944302.91 11979.70 70.60 225.60 8912.24 6088.94S 2701.43E 12.47 -1240.10 690518.01 5944261.43 12017.00 74.20 233.30 8923.53 6112.01S 2674.43E 21.91 -1208.54 690491.59 5944237.70 12031.00 75.20 236.80 8927.22 6119.75S 2663.37E 25.15 -1196.00 690480.72 5944229.69 12069.00 79.70 242.10 8935.48 6138.585 2631.44E 18.04 -1160.62 690449.27 5944210.08 12102.50 82.70 246.70 8940.61 6152.87S 2601.59E 16.26 -1128.30 690419.79 5944195.05 12175.30 82.97 261.00 8949.74 6172.90S 2532.39E 19.49 -1056.35 690351.12 5944173.31 12228.00 76.20 268.80 8959.27 6177.54S 2480.84E 19.41 -1005.11 690299.70 5944167.39 12263.50 76.20 276.20 8967.75 6176.045 2446.43E 20.24 -971.94 690265.26 5944168.04 12298.90 76.50 283.20 8976.12 6170.25S 2412.54E 19.23 -940.27 690231.24 5944172.99 12351.10 78.80 284.30 8987.28 6158.13S 2363.02E 4.86 -894.82 690181.43 5944183.88 12385.40 85.10 285.70 8992.08 6149.34S 2330.23E 18.81 -864.91 690148.44 5944191.85 12404.90 88.20 286.80 8993.22 6143.89S 2311.54E 16.87 -847.96 690129.63 5944196.83 12431.00 89.00 289.60 8993.86 6135.74S 2286.76E 11.15 -825.69 690104.65 5944204.36 12481.70 89.80 297.70 8994.39 6115.42S 2240.36E 16.05 -785.15 690057.76 5944223.52 12507.00 92.00 301.90 8993.99 6102.85S 2218.41E 18.74 -766.66 690035.51 5944235.54 12540.00 90.40 306.10 8993.30 6084.415 2191.07E 13.62 -744.24 690007.72 5944253.30 12587.10 91.10 315.60 8992.68 6053.64S 2155.48E 20.22 -716.62 689971.39 5944283.17 12620.90 91.40 318.40 8991.95 6028,93S 2132.44E 8.33 -699.83 689947.74 5944307.31 12669.50 89.10 323.30 8991.73 5991,25S 2101.77E 11.14 -678.57 689916.14 5944344.21 12719.70 85.60 315.90 8994.06 5953.10S 2069.30E 16.29 -655.67 689882.74 5944381.54 12774.60 81.50 308.70 9000.23 5916.40S 2028.99E 15.02 -624.80 689841.54 5944417.22 12819.60 86.80 303.30 9004.82 5890.12S 1992.80E 16.77 -595.56 689804.71 5944442.60 12879.30 90.90 295.50 9006.02 5860.85S 1940.85E 14.76 -551.67 689752.05 5944470.57 12891.90 91.60 294.10 9005.74 5855.56S 1929.41E 12.42 -541.74 689740.49 5944475.57 12915.90 93.30 296.60 9004.72 5845.30S 1907.75E 12.59 -522.99 689718.57 5944485.29 12957.70 89.20 288.20 9003.80 5829.40S 1869.15E 22.35 -489.04 689679.60 5944500.23 12998.20 93.30 285.00 9002.92 5817.83S 1830.36E 12.84 -453.92 689640.54 5944510.83 13003.80 94.90 285.40 9002.52 5816.37S 1824.97E 29.45 -449.00 689635.11 5944512.16 13029.30 99.10 279.70 8999.41 5810.865 1800.28E 27.63 -426.22 689610.30 5944517.05 13058.00 95.70 270..70 8995.71 5808.30S 1771.97E 33.27 -399.25 689581.93 5944518.91 13098.60 94.60 259.70 8992.05 5811.68S 1731.74E 27.12 -359.31 689541.80 5944514.54 13133.00 97.80 248.40 8988.33 5821.05S 1698.92E 33.95 -325.21 689509.22 5944504.35 13150.10 95.10 245.30 8986.40 5827.73S 1683.30E 23.95 -308.48 689493.77 5944497.29 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 02-11A and TVD from Mean Sea Level. Bottom hole distance is 6065.96 on azimuth 163.89 degrees from wellhead. Vertical section is from wellhead on azimuth 256.80 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO ALaska, [nc. D.S. 2,2-11A Prudhoe Bay,North SLope, ALaska SURVEY LISTING Page 2 Your ref : 2-11A Last revised : 9-0ct-98 Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2-11ehs 688750.000,5944270.000,999.00 8985.00 6036.51S 934.07E 15-Jun-98 2-11bbs 690270.000,5944250.0001999.00 8990.00 6094.22S 2453.20E 15-Jun-98 TONY KNOWLE$, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Jul,,.' 7. 1998 Erin Oba Engineering Supetwisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 ac~ Pmdhoe Bav Unit 2-1 lA ARCO Alaska. Inc. Permit No. 98-126 Sur. Loc. 921'FNL. 916'FWL. Scc. 36. TIlN. RI4E. UM Btmnholc Loc. 1678'FNL. 3434'FEL. Sec. 1, T10N, R14E, UM Dear Ms. Oba: Encloscd is thc approvcd application for permit to rcdrill thc above refcrcnccd wcll. Thc permit to rcdrill docs not exempt you from obtaining additional permits required bv la~v from othcr governmental agcncics, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Bloxx-out prevention equipmcnt (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given bx'. contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosurcs cc: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation xv/o cncl. STATE OF ALASKA -_-~ ALASKAOIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 2,5.005 la. Type of Work Drill_ Redrill ~ lb. Type of Well Exploratory_ Stratigraphic Test_ Development Oil_~X Re-Entry__ Deepen _ Service_ Development Gas_ Single Zone ~ Multiple Zone_ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 56' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 028311 Prudhoe Bay Oil Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 921' FNL, 916' FW/, Sec 36, T11N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1163' FNL, 1420' FEL, Sec 1, T10N, R14E, UM 2-11A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1678' FNL, 3434' FEL, Sec 1, T10N, R14E, UM July, 1998 $200,000 12. Distance to nearest I 13. Distance to nearest well !4. Number of acres in property 15. Proposed depth (MD and -IYD) property line No Close Approach 13703' MD / 9046' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 8740' MD Maximum hole an~lle 88° Maximum surface 2500 psi9 At total depth (TVD) 3400 psi9 @ 8800' 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Couplin9 Len~h MD TVD MD TVD (include stage data) 4-1/2" 3-1/2" 9.3 L-80 FL4S 2703' 11000' 8354' 13703' 9046' 27 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12180 feet Plugs(measured) Bottom tagged @ 11928' MD (6/5/98) true vedlcal 9266 feet Effective depth: measured 11928 feet Junk (measured) ~-~.~.~ true vertical 9048 feet ~' \ Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 262 Sx AS 110' 11 O' Surface 2655' 13-3/8" 5800 Sx PF ,, 2711' .~= 274 ¥'~ ~ ~ Production 12106' 9-518" 1200 Sx CIG 12162' Perforation depth: measured 11760'- 11781" 11855'- 11870'; 11912'- 11932' true vertical 8937'- 8953'; 9010' - 9022'; 9055'- 9070' 20. Attachments Filing fee ~ Property plat _ BOP Sketch _x Diverter Sketch _ Drilling program Drilling fluid program ~ Time vs depth pict _ Refraction analysis _ Seabed report~ 20 AAC 25.050 requirements 21. Iherebycedifythattheforegoingistrueandcorrecttothebestofmyknowledge Questions: Call Steve Ward @ 265-1505. Si~Ined ~ % · ~ Titlle Engineering Supervisor Date Erin Oba Commission Use Only Prepared by Paul Paul263-4990 N,~ ~.r /<~. i AP, ri,tuber I I See cover ,eUer for Permit. - ,~' 50- ~-.~ - .2. <:~ .~..~'.~'.-. ~::~ ./ ~ ' other requirements Conditions of approval Samples required Yes L~qO Mud Icg required Yes Hydrogen sulfide measures ~Yes _ No Directional survey required_Xf~5~¥e; _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M 0 psi for CTU Other: drigina. l Signed By David W. Johnston by order ot , Approved by Commissioner the commission Date Form 10-401 Rev. 7~24-89 Submit in triplicate DS 2-1lA CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well existing wellbore. Complete with 3-1/2" cemented liner. from the Intended Procedure: · RU CTU and BOPE. Test BOPE to 3500 psi Cement squeeze the current perforations and plugback the existing completion to - 11420' md. Mill window in 5-1/2" tubing and 9-5/8" casing at -11460' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight ( 8.9 ppg Flo Pro as drilling fluid). Directionally drill 4.5" x 2000' horizontal well to access Zone 2 reserves. Build angle to -90°. · Run and cement 3-1/2" liner to TD. · Perforate selected intervals. · Return well to production. June 17, 1998 ARCO Alaska, Inc. Structure · D.S. 2 Field · Prudhoe Bey Slot · 02-11A Lodation : North Slope, Alaska East (feet) -> N 111U£ Uo~ne~Jc N<~.h I~ 28.25 d~ [a~ ef ~U[ N~h To ca~ azimuth from ~gne~c to TRUE o~ 28.25 8400- - 8500- 8600- 8700 .~ 8800 ..~ 8900 9000 9100 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 I I I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I .I I I I WELLPROFILE DATA Tie 8516.85 Tvd, 5614.57 $, 27`35.58 E Point MD Inc Dir I'VD No~h East V. Sect Deg/lO0 on -- X Tie in Position 11300.00 43.04 156.44 8516.85 -5614.57 2733.58 0.00 0.00 Kick off Point 11460.00 41,76 157.26 8635.01 -5713.76 2776,01 -16.72 0.87 5 11515.27 50.00 158.00 9672.06 -5749.10 2790.55 -22.11 15.50 4 11855.42 56.30 225.00 8891.45 -5986.98 2735.54 89.91 15.50 5 12182.69 90.01 269.12 8990.00 -6094.22 2453.20 389.76 16.20 T.D. 13703.64 89.99 275.23 8990.00 -6036.51 934.07 1848.01 0.40 - T.D. & End of Drop - 8990.00 Tvd, 6056.51 S, 954.07 E --' 2-1labs 2-11bhs [ 55O0 5600 5700 Cf) 0 c- 5800 5900 .~_ I 60o0 v Tie on - 43.04 Inc, 11500.00 Md, 8516.85 Tvd, 0.00 Vs Kick off Point t6100 6200 2-11bhs T.D. & End of Drop/Turn - 89.99 Inc, 1570.3.64 Md, 8990.00 Tvd, 1848.01 Vs " I I I I I i I i i I I i [ I i i i i I I I I i I I ii I i i i I i i i i i i i i i i 1 O0 0 100 200 500 400 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 1900 2000 Vertical Section (feet) -> Azimuth 255.76 with reference 5614.57 S, 275.5.58 E from 02-11A ARCO Alaska, Inc. D.S. 2,02-11A Prudhoe Bay, North SLope, ALaska PROPOSAL LZST]NG Page I Your ref : 02-11A CT Sidetrack Last revised = 16-Jun-98 Measured [nc[in Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S Oepth Oegrees Oegrees Oepth C 0 0 R D ! N A T E S Oeg/lOOft Sect Easting Northing 11300.00 43.04 156.44 8516.85 5614.57S 2733.58E 0.00 0.00 690538.38 5944736.43 11350.00 42.64 156.69 8553.52 5645.76S 2747.11E 0.87 -5.43 690552.67 5944705.58 11400.00 42.24 156.95 8590.42 5676.78S 2760.39E 0.87 -10.68 690566.72 5944674.90 11460.00 41.76 157.26 8635.01 5713.76S 2776.01E 0.87 -16.72 690583.25 5944638.32 11500.00 47.95 157.83 8663.35 5739.83S 2786.77E 15.50 -20.74 690594.65 5944612.53 11513.27 50.00 158.00 8672.06 5749.10S 2790.53E 15.50 -22.11 690598.65 5944603.35 11600.00 47.66 175.62 8729.40 5812.15S 2805.49E 15.50 -21.10 690615.17 5944540.70 11700.00 48.46 196.48 8796.65 5885.34S 2797.65E 15.50 4.51 690609.14 5944467.35 11800.00 52.80 215.78 8860.43 5953.95S 2763.54E 15.50 54.45 690576.74 5944397.91 11853.42 56.30 225.00 8891.45 5986.98S 2735.34E 15.50 89.91 690549.37 5944364.20 11900.00 60.28 232.54 8915.95 6013.02S 2705.54E 16.20 125.20 690520.23 5944337.43 12000.00 70.03 246.83 8958.10 6058.23S 2627.35E 16.20 212.11 690443.19 5944290.30 12100.00 80.78 259.36 8983.35 6086.01S 2535.02E 16.20 308.43 690351.59 5944260.23~ 12182.69 90.01 269.12 8990.00 6094.22S 2453.20E 16.20 389.76 690270.00 5944250.00 12200.00 90.01 269.19 8990.00 6094.48S 2435.89E 0.40 406.60 690252.70 5944249.3'1 12300.00 90.00 269.59 8989.99 6095.54S 2335.90E 0.40 503.78 690152.77 5944245.77 12400.00 90.00 269.99 8989.98 6095.90S 2235.90E 0.40 600.80 690052.82 5944242.92 12500.00 90.00 270.39 8989.97 6095.57S 2135.90E 0.40 697.64 689952.85 5944240.78 12600.00 90.00 270.80 8989.97 6094.53S 2035.90E 0.40 794.31 689852.87 5944239.34 12700.00 90.00 271.20 8989.97 6092.79S 1935.92E 0.40 890.79 689732.88 5944238.60 12800.00 90.00 271.60 8989.96 6090.35S 1835.95E 0.40 987.09 689652.88 5944238.56 12900.00 90.00 272.00 8989.96 6087.20S 1736.00E 0.40 1083.19 689552.89 5944239.22 13000.00 90.00 272.40 8989.96 6083.36S 1636.07E 0.40 1179.10 689452.91 5944240.58 13100.00 90.00 272.81 8989.96 6078.81S 1536.18E 0.40 1274.81 689352.93 5944242.65 13200.00 90.00 273.21 8989.97 6073.57S 1436.31E 0.40 1370.32 689252.98 5944245.41 13300.00 90.00 273.61 8989.97 6067.62S 1336.49E 0.40 1465.61 689153.04 5944248.88 13400.00 90.00 274.01 8989.98 6060.98S 1236.71E 0.40 1560.69 689053.14 5944253.05 13500.00 90.00 274.41 8989.98 6053.63S 1136.98E 0.40 1655.55 688953.26 5944257.92 13600.00 90.00 274.82 8989.99 6045.59S 1037.31E 0.40 1750.18 688853.42 5944263.49 13700.00 89.99 275.22 8990.00 6036.84S 937.69E 0.40 1844.58 688753.63 5944269.76 13703.64 89.99 275.23 8990.00 6036.51S 934.07E 0.40 1848.01 688750.00 5944270.00 ALl data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 02-11A and TVD from Mean Sea Level. Bottom hole distance is 6108.35 on azimuth 171.20 degrees from wetthead. Vertical section is from tie at S 5614.57 E 2733.58 on azimuth 255.76 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ DS 2-11A PROPOSED CTD COMPLETION 5-1/2" Tubing 5-1/2" Otis Sliding 10778' Sleeve 9-5/8" BOT RHR Pkr. 10897' 2075' 5-1/2" Otis RQ SSSV Nipple (4.562" ID) 4-1/2" GS FN on top of liner @ +11000' Window Cut in 5-1/2" & 9-5/8" casing with CT. ~ 11460' - 11465' Initial Perorations 9-5/8" Baker F-1 Pkr. 11794' ,%.,, ,., ',. % % % % % ",, % % ,., ,., ,,, ,,, ,., .,, .,,, .,, ,,, 4-1/2" Open hole TD @ + 137'00' 3-1/2" FL4S liner Original perforations cement sqz'd. 9-5/8" Casing Shoe @ 12162' Drilling Wellhead Detail ~ CT Injector Head Methanol Injection )tis 7" WLA Quick onnect ' ~ I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ----- 7" Riser I I Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual ~ Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve O.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus Alaska LAYOUT STATE OF ALASKA ALASKa,OIL AND GAS CONSERVATION COMMIS'"'~ION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill _ Redrill ~ lb. Type of Well Exploratory_ Stratigraphic Test_ Development Oil_~X Re-Entry._, Deepen _ Service_ Development Gas _ Single Zone_~X Multiple Zone_ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 56' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 028311 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 921' FNL, 916' FWL, Sec 36, T11N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1163' FNL, 1420' FEL, Sec 1, T10N, R14E, UM 2-11A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1678' FNL, 3434' FEL, Sec 1, T10N, R14E, UM July, 1998 $20O,0O0 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 13703' MD / 9046' TVD 16. To be com'pleted for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 8740' MD Maximum hole ancjle 88° Maximum surface 2500 psig At total depth (TVD) 3400 psig @ 88O0' 18. Casing program Setting Depth Size Specilication Top Bottom Quantity of cement Hole Casing Weight Grade Couplin,q Len,c]th MD TVD I MD I TVD (include stage data) 4-1/2" 3-1/2" 9.3 L-80 FL4S 2703' 11000' 8354'I 13703' 9046' 27 bbls 191 To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12180 feet Plugs(measured) Bottom tagged @ 11928' MD (6/5/98) true vertical 9266 feet Effective depth: measured 11928 feet Junk (measured) true vertical 9048 leet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 262 Sx AS 110' 110' Surface 2655' 13-3/8' 5800 Sx PF II 2711' 2711' Production 12106' 9-5/8" 1200 Sx CIG 12162' 9525' Pedorationdepth: measured 11760'- 11781" 11855'- 11870'; 11912'- 11932' true vertical 8937' - 8953'; 9010' - 9022'; 9055' - 9070' · 20. Attachments Filing fee ~ Property plat _ BOP Sketch .~X Diverter Sketch _ Drilling progr~n'? ~0 Drlllin9 fluid program ~ Time vs depth pict Refraction analysis _ Seabed report 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions: Call Steve Ward @ 265-1305. Signed ~ ~ · ~ Titlle En,cjineerin9 Supervisor Date ~,, / Erin Oba Commission Use Only Prepared by Paul Rauf 263-4990 m~,N~.rn~,r.2_. I APl number I Approval date,~,,.../, ~ I Se ecover letter for Per - ~' 50- C) ~--? --' ~...4:3.2- ~',,~ '" ~ ! ~ '~ other requirements Con~liti~ns of approval Samples required_Yes ~-4'No Mud Icg required _ Yes .,~4'No Hydrogen sulfide measures ~es _ No Directional survey required ,~%~'es _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M~500 psi for CTU Other: dr g na 5 gneo f av d W. Johnston by order of ,Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DS 2-1lA CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well existing wellbore. Complete with 3-1/2" cemented liner. from the Intended Procedure: · RU CTU and BOPE. Test BOPE to 3500 psi Cement squeeze the current perforations and plugback the existing completion to - 11420' md. Mill window in 5-1/2" tubing and 9-5/8" casing at -11460' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight ( 8.9 ppg Flo Pro as drilling fluid). Directionally drill 4.5" x 2000' horizontal well to access Zone 2 reserves. Build angle to -90°. · Run and cement 3-1/2" liner to TD. · Perforate selected intervals. · Return well to production. June 17, 1998 ARCO Alaska, Inc. Structure · D.S. 2 Field · Prudhoe Bay Slot · 02-11A Lodation · North Slope, Alaska East (feet) -> N Idiotic(lc N<)r~ [$ 28.2.5 d~rm E~ of ~UE N~h azimuth f~ ~gn~c to t~ o~ 2Q.2~ deg 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2500 2400 2500 2600 2700 2800 2900 I I I t I I I I I I I I I I I I I I I I I I I I I I I WELL PROFILE DATA ..... Po;hr ..... MO Inc D;r ~ No,th Ee,t V. Sect 0e9/100 Tie in Position 11300.00 43.04 156.44 8516.85-5614.57 2733.58 0.00 0.00 Kick off Point 11460.00 41.76 157.26 86,35.01 -5713.76 2776.01 -16.72 0.87 3 1151.3.27 50.00 158.00 8672.06-5749.10 2790.53 -22.11 15.50 4 1185.3.42 56.`30 225.00 8891,45-5986.98 2735..34 89.91 15.50 5 12182.69 90.01 269.12 8990.00-6094.22 2453.20 389.76 16.20 T.D. 13703.64 89.99 275.23 6990.00-6036.51 934.07 1848.01 0.40 Tie on - 8516.85 Tvd, 5614.57 $, 2733.58 E Kick off Point T.D. & End of Drop - 8990.00 Tvd, 6036.51 S, 934.07 E 2-1 1ohs 8400- - 8500- c' 8600- .4- 8700 ~ 8800 >. 8900 Tie on - 43.04 Inc, 11300.00 Md, 8516.85 Tvd, 0.00 Vs Kick off Point 2-11bhs 2-11ohs 5500 5600 5700 (7) ,r:: O ! 5800 5900 ._+. I 6000 V 6100 620O T.D. & End of Drop/Turn - 89.99 Inc, 13705.64 Md, 8990.00 Tvd, 1848.01 Vs 1 O0 0 100 200 300 400 500 600 700 800 900 1000 11 O0 1200 1,300 Vertical Section (feet) -> i i i i i i i i i i i i 1400 1500 1600 1700 1800 1900 2000 Azimuth 255.76 with reference 5614.57 S, 27;5.5.58 E from 02-11A ARCO ALaska, D.S. 2,02-11A Pr~hoe Bay,North SL~, Alaska Measured %ncLin Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N 11300.00 43.04 156.44 8516.85 5614.57S 11350.00 42.6~ 156.69 8553.52 56~5.76S 11400.00 42.24 156.95 8590.42 5676.78S 11460.00 41.76 157.26 8635.01 5713.76S 11500.00 47.95 157.83 8663.35 5739.83S 11513.27 50.00 158.00 8672.06 5749.10S 11600.00 47.66 175.62 8729.40 5812.15S 11700.00 48.46 196.48 8796.65 5885.34S 11800.00 52.80 215.78 8860.43 5953.95S 11853.42 56.30 225.00 8891.45 5986.98S 11900.00 60.28 232.54 8915.95 6013.02S 12000.00 70.03 246.83 8958.10 6058.23S 12100.00 80.78 259.36 8983.35 6086.01S 12182.69 90.01 269.12 8990.00 6094.22S 12200.00 90.01 269.19 8990.00 6094.48S 12300.00 90.00 269.59 8989.99 6095.54S 12400.00 90.00 269.99 8989.98 6095.90S 12500.00 90.00 270.39 8989.97 6095.575 12600.00 90.00 270.80 8989.97 6094.53S 12700.00 90.00 271.20 8989.97 6092.79S 12800.00 90.00 271.60 8989.96 6090.35S 12900.00 90.00 272.00 8989.96 6087.20S 13000.00 90.00 272.40 8989.96 6083.36S 13100.00 90.00 272.81 8989.96 6078.81S 13200.00 90.00 273.21 8989.97 6073.57S 13300.00 90.00 273.61 8989.97 6067.62S 13~00.00 90.00 274.01 8989.98 6060.98S 13500.00 90.00 274.41 8989.98 6053.63S 13600.00 90.00 274.82 8989.99 60~5.59S 13700.00 89.99 275.22 8990.00 6036.8~S 13703.64 89,99 275.23 8990.00 6036.51S ULAR ATES 2733.58E 2747.11E 2760.39E 2776.01E 2786.77E 2790.53E 2805.49E 2797.65E 2763.54E 2735.34E 2705.54E 2627.35E 2535.02E 2453.20E 2435.89E 2335.90E 2235,90E 2135.90E 2035,90E 1935,92E 1835,95E 1736,00E 1636,07E 1536,18E 1436,31E 1336,49E 1236.71E 1136.98E 1037.31E 937.69E 934.07E PROPOSAL LISTING Page 1 Your ref : 02-11A CT Sidetrack Last revised : 16-Jun-98 Dogleg Vert G R I D C 0 0 R D S Deg/lOOft Sect Easting Northing 0.00 0.00 690538.38 5944736.43 0.87 -5.43 690552.67 5944705.58 0.87 -10.68 690566.72 5944674.90 0.87 -16.72 690583.25 5944638.32 15.50 -20.74 690594.65 5944612.53 15.50 -22.11 690598.65 5944603.35 15.50 -21.10 690615.17 5944540.70 15.50 4.51 690609.14 594~67.35 15.50 54.45 690576.74 5944397.91 15.50 89.91 690549.37 594436~.20 16,20 125,20 690520,23 5944337,43 16,20 212,11 690~3,19 5944290,30 16.20 308.43 690351,59 5944260,23.~- 16.20 389.76 690270.00 5944250.00 0.40 406.60 690252.70 5944249.31 0.40 503.78 690152.77 5944245.77 0.40 600.80 690052.82 5944242.92 0.40 697.6~ 689952.85 5944240.78 0.40 794.31 689852.87 5944239.34 0.40 890.79 689752.88 5944238.60 0.40 987.09 689652.88 5944238.56 0.40 1083.19 689552.89 5944239.22 0,40 1179.10 689452.91 5944240.58 0.40 1274.81 689352.93 5944242.65 0.40 1370.32 689252.98 5944245.41 0.40 1465.61 689153.04 5944248.88 0.40 1560.69 689053.14 5944253.05 0.40 1655.55 688953.26 5944257.92 0.40 1750.18 688853.42 5944263.49 0.40 18~4.58 688753.63 5944269.76 0.40 1848.01 688750.00 5944270.00 Att data in feet unLess otherwise stated. CaLculation uses minirm~n curvature method. Coordinates from 02-11A and TVO from Mean Sea Level. Bottom hole distance is 6108.35 on azimuth 171.20 degrees from wellhead. Vertical section is from tie at S 5614.57 E 2733.58 on azimuth 255.76 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the CLarke - 1866 spheroid Presented by Baker Hughes INTEQ DS 2-11A PROPOSED CTD COMPLETION 5-1/2" Tubing 2075' 5-1/2" Otis RQ SSSV Nipple (4.562" ID) 5-1/2" Otis Sliding Sleeve 9-5/8" BOT RHR Pkr. 10778' 10897' 4-1/2" GS FN on top of liner @ +11000' Window Cut in 5-1/2" & 9-5/8" casing with CT, ~ 11460' - 11465' % Initial Perforations 9-5/8" Baker F-1 Pkr. 11794' 4-1/2" Open hole TD @ +_ 13700' 3-1/2" FL4S liner Original perforations cement sqz'd. 9-5/8" Casing Shoe @ 12162' Drilling Wellhead Detail ~ CT Injector Head Methanol Injection tis7" WLA Quick onnect -- % Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I -- 7" Riser ! I Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate ROPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Cutters or Combination CuttedBlinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate ROPE Manualover .Hydraulic 7-1/16" ID witi~ Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus ~'-~ :?,~, '.-.;~ .__ · WELL PERMIT CHECKLIST COMPANY FIELD & POOL INIT CLASS WELL NAME_~ ~/ ~_...////Z~? PROGRAM: exp [] dev~redrl~serv [] wellbore segll ann. disposal para reql, /---'~,, ~/ GEOL AREA ~;="~:C:~ UNIT# -' .///~--~,_~",,.--.) ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~,F"~) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ......... ... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Con, tact name/phone for weekly progress reports ....... lexploratory only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N__ pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: DWJ BEW'~I~'/~/'~/~WM "~ ~°J~"g[eJ~ RNC JDH co Comments/Instructions: M:chel~list rev 05/29/98 dlf: C :\m sof'lice\wordian\diar~a',(;ho, r;kli~t Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Tape Subfile 1 is type: LIS **** REEL HEADER MWD 99/ 3/19 BHI 01 LIS Customer Format Tape **** TAPE HEADER MWD 99/ 3/19 100256 01 1 3/4" NaviGamma, Gamma Ray Data LIS COMMENT RECORD(s): ~234567890~23456789~~234567890~23456789~~234567890~234567890~234567890~23456789~ !!!!!!!!!!~!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!I!!! Extract File: Header.las -Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame ~Well Information Block Data Type Information #MNEM.UNIT STRT.F 11357.0000: Starting Depth STOP.F 13407.0000: Ending Depth STEP.F 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ARCO Alaska, Inc. WELL. WELL: 02-1lA FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 921' FNL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1 3/4" NaviGamma REF . JOB REFERENCE: 100256 DATE. LOG DATE: 21 Sep 98 API. API NUMBER: 500292027301 ~Parameter Information Block #MNEM.UNIT Value Description FL. 916' FWL : Field Location SECT 36 : Section TOWN.N liN : Township RANG. 14E : Range PDAT. M.S.L. : Permanent Datum LMF . KB : Log Measured From FAPD. FT 56 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .M 56' : Elevation Of Kelly Bushing EDF .M N/A : Elevation Of Derrick Floor EGL .M N/A : Elevation Of Ground Level CASE.F 11476 : Casing Depth OS2 . DIRECTIONAL : Other Services Line 2 -Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 02-I1A is represented by runs 12, 13, 14, 15, 16, 17, 18 and 19 which are all Directional with Gamma Ray. (5) The well was kicked off @ 11476' MD (8646' TVD) from the RECEIVED t .,4AR 22 1999 Alaska Oa & Gas Cons. Commiasion wellbore originally drilled for Well 02-11. 6) Run 1 through run 11 were milling runs, and no logging data was acquired in new hole. 7) The break in the log from 11717' MD (8820' TVD) to 11730' MD (8827' TVD) was due to a depth adjustment applied after a tie-in. 8) The break in the log from 12548' MD (8993' TVD) to 12559' MD (8993' TVD) was due to a depth adjustment applied after a tie-in. 9) The break in the log from 12728' MD (8994' TVD) to 12738' MD (8995' TVD) was due to a depth adjustment applied after a tie-in. 10) The break in the log from 13031' MD (8999' TVD) to 13043' MD (8997' TVD) was due to a depth adjustment applied after a tie-in. 11) The break in the log from 13248' MD (8986' TV/)) to 13258' MD (8986' TVD) was due to a depth adjustment applied after a tie-in. (12) The interval from 13272' MD (8986' TVD) to 13307' MD (8986' TVD) was not logged due to the sensor to bit offset. (13) Well 02-11A was drilled to TD @ 13307' MD (8986' TVD) on Run 19. (14) The Gamma Ray log has been depth shifted to match the Schlumberger CNL Gamma Ray logged on 21 September 1998. (15) A Magnetic Declination correction of 28.01 degrees has been applied to the Directional Surveys, -Mnemonics -> GRAX = Gamma Ray MWD-API [MWD] (MWD-API units) -> ROPS = Rate of Penetration (ft/hr) -> TVD = True Vertical Depth (feet) -Sensor Offsets RUN # DIRECTIONAL GAMMA 12 36.00 ft. 30.98 ft. 13 28.40 ft. 23.90 ft. 14 28.58 ft. 24,10 ft. 15 32.36 ft. 28.05 ft. 16 31.73 ft. 39.25 ft. 17 30.51 ft. 38.03 ft. 18 28.50 ft. 36.02 ft. 19 29.13 ft. 36.65 ft. Tape Subfile: 1 82 records.,. Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS FILE HEADER **** ~ .001 1024 INFORMATION TABLE: CONS MN EM VB~LU LCC 150 CN ARCO Alaska, Inc. WN 02-1lA FN , Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !l!!!!t!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by Arco Alaska, Inc. 3. The PDC used is the Schlumberger's CNL Gamma Ray data, dated SePt. 24, 1998. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX 2 ROP ROPS * FORMAT RECORD (TYPE# 64) Entry Type 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: 1 Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 0.0 0o0 Rep Code Count Bytes 68 2 8 Sum: fndun a IF ] 2 8 8 1. 00000000 3 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: API API API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 GR MWD 68 1 API 4 4 99 995 99 1 2 ROP MWD 68 1 4 4 99 995 99 1 8 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 45 Tape File Start Depth = 11455.000000 Tape File End Depth = 13308.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 11125 datums Rep Code: 79 2 datums Tape Subfile: 2 52 records... , Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 02-1lA FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~234567890~23456789~~23456789~~234567890~23456789~~234567890~234567890 !!!!!!!!!~!!!!!!!!t Remark File Version 1.000 1. The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( i) Size 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size. 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size~ 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size, 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size~ 1) Repcode( 66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size! 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size 4) Repcode(65) Frame spacing units: F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type( 13) Size( 1) Repcode( 66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode( 66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 1 4 2 ROPS MWD 68 1 4 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 DATA RECORD (TYPE# 0) Total Data Records: 45 1014 BYTES * Tape File Start Depth = 11455.000000 Tape File End Depth = 13308.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 11125 datums Rep Code: 79 2 datums Tape Subfile: 3 52 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS *~** TAPE TRAILER **** MWD 99/ 3/19 100256 01 **** REEL TRAILER **** MWD 99/ 3/19 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 19 MAR 99 ll:15a Elapsed execution time = 1.37 seconds. SYSTEM RETURN CODE = 0 [] Tape Tape Subfile 1 is type: LIS Subfile 2 is type: LIS DEPTH GR ROP 11455.0000 -999.2500 -999.2500 11455.5000 9.7340 -999.2500 11500.0000 29.4920 30.5700 11600.0000 30.4930 48.1630 11700.0000 27.7160 15.2100 11800.0000 55.4950 78.2870 11900.0000 88,6250 27.6610 12000.0000 26.9620 74.4550 12100.0000 19.6910 30.7830 12200.0000 23.8230 36.4770 12300.0000 165.0040 26.3790 12400.0000 19.8940 44.2600 12500.0000 29.3980 45,1200 12600.0000 22.6400 48.5500 12700.0000 62.2560 77.7420 12800.0000 31.8670 70.3870 12900.0000 74.2650 65.5770 13000,0000 24.1590 141.1700 13100.0000 25.2900 41.2780 13200.0000 36.0340 38.7840 13300.0000 -999.2500 45.9830 13308.0000 -999.2500 -999.2500 [] Tape Tape File Start Depth = 11455.000000 Tape File End Depth = 13308.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Subfile 3 is type: LIS DEPTH GRAX 11455.0000 -999.2500 11455.5000 -999.2500 11500.0000 42.1610 11600.0000 27.4680 11700.0000 24.8400 11800.0000 65.0500 11900.0000 104.4500 12000.0000 26.3750 12100.0000 20.6450 12200.0000 26.6470 12300.0000 173.2540 12400.0000 21.3950 12500.0000 34.1500 12600.0000 26.2830 12700.0000 63.1010 12800.0000 34.3540 12900.0000 63.2190 13000.0000 28.4890 13100.0000 26.5790 13200.0000 29.3950 13300.0000 -999.2500 13308.0000 -999.2500 ROPS -999.2500 -999.2500 30.6850 36.8080 15.2100 77.3760 31.6230 74,3830 55.7000 35.8340 40 0560 49 0040 42 1320 39 6010 77 7420 235460 76 6120 139.9890 33.4720 40.4720 46.8830 -999.2500 Tape File Start Depth = 11455.000000 Tape File End Depth = 13308.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS RECEIVED Alad(a & Gas Cons. Cor issi°n kn ot' * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : D.S. 2-1lA FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292027301 REFERENCE NO : 98555 ~IS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN · FLIC REEL NAME : 98555 CONTINUATION # : PREVIOUS REEL : CO~R4ENT · ARCO ALASKA, INC., PRUDHOE BAY, 2-1lA, #50-029-20273-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC TAPE NAME · 98555 CONTINUATION # : 1 PREVIOUS TAPE : CO~R~ENT : ARCO ALASKA, INC., PRUDHOE BAY, 2-1lA, #50-029-20273-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 2-1lA API NUMBER: 500292027301 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 3-NOV-98 JOB NUMBER: 98555 LOGGING ENGINEER: J. SPENCER OPERATOR WITNESS: B. MIZE SURFACE LOCATION SECTION: 36 TOWNSHIP: liN RANGE: 14E FNL: 921 FSL: FEL: FWL : 916 ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 56.00 GROUND LEVEL: 30.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 3.188 11569.0 6.20 2ND STRING 2. 875 13337.0 6.50 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 13-JAN-77 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888 0 11427 5 11342 5 11336 5 11330 0 11290 5 11279 5 11234 5 11227 5 11199 0 11187 5 11034 5 10973 5 10904 5 10870 0 10849 0 10816 5 10815 5 10804 0 10796 5 10792 5 10792 0 10788 5 10782 5 100.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH MCNL 88888. 11427. 11342. 11337. 11330. 11291. 11279. 11234. 11227. 11199. 11187. 11034. 10972. 10904. 10870. 10849. 10815. 10803. 10796. 10792. 10789. 10782. 99. 0 88888 0 5 11427 5 5 11342 5 0 11337 0 0 11330 0 0 11291 0 5 11279 5 0 11234 0 5 11227 5 0 5 11187.5 0 11034.0 5 1 0972.5 5 10904.5 5 10870.5 5 10849.5 10815.5 5 0 10803.0 5 10796.5 0 10792.0 0 10789.0 0 10782.0 5 99.5 REMARKS: CONTAINED HEREIN IS THE MCNL DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 2-1lA ON 23-SEP-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT MCNL MAIN PASS GRCH TO THE GAi~4A RAY PROVIDED BY THE CLIENT (GR.BCS); AND MCNL MAIN PASS NRAT TO GR.BCS. ALL OTHER MCNL CURVES WERE CARRIED WITH THE NRAT SHIFT. *NOTE: NO CORRELATIONS WERE MADE TO THE BASELINE GAMMA RAY BELOW THE KICK-OFF POINT AT 11460'. $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE . FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NIIMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SO?4FiARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12982.0 10768.0 MCNL 12992.0 10768.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH MCNL REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MCNL MAIN PASS. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 4 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFIB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNT V 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12991.992 GRCH. CNT -999.250 NCNT. CNT 6095.333 FCNT. CNT 308.676 NRAT. CNT 18.414 CCL. CNT -999.250 GR.BCS -999.250 DEPT. 9650.492 GRCH. CNT -999.250 NCNT. CNT -999.250 FCNT. CNT -999.250 NRAT. CNT -999.250 CCL. CNT -999.250 GR.BCS 60.590 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : · LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUP24ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12984.0 12698.0 MCNL 12994.0 12698.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 12981.5 12978.5 12974.0 12972.5 12972.0 12968.5 12966.0 12956.5 12956.0 12955.0 12953 0 12947 5 12945 0 12939 5 12937 0 12929 5 12928 5 12923 5 12920.5 12920.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH MCNL .............. 88887.5 88886.5 12978.0 12974.0 12971.5 12965.5 12956.0 12945.0 12938.5 12928.5 12919.5 12980.0 12972.0 12967.5 12956.0 12954.0 12953.0 12949.0 12936.5 12930.0 12921.5 12920.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 12913.0 12912.5 12907.5 12904.0 12901.5 12893.0 12888.5 12886.5 12883.0 12880.5 12875.5 12875.0 12869.0 12868.5 12862.5 12857.0 12853.5 12845.5 12840.0 12837.5 12832.0 12823 5 12823 0 12810 0 12804 0 12794 5 12794 0 12789 0 12781 5 12778 5 127715 12770.5 12765.0 12763.0 12755.0 12754.0 12751.5 12750.0 12744.0 12736.5 12734.0 12730.5 12719.0 12715.5 12711.0 12704.0 100.0 $ RE~b%RKS: 12912.0 12907.0 12904.0 12887.0 12879.5 12874.5 12868.0 12861.5 12856.5 12845.0 12839.5 12831.5 12823.0 12803.5 12794.5 12778.5 12771.0 12765.0 12763.5 12756.0 12751.5 12732.5 12717.5 12715.0 12709.0 98.0 12912.5 12902.0 12895.0 12887.5 12881.5 12875.0 12868.5 12856.5 12853.0 12845.0 12837.0 12821.5 12808.5 12794.0 12789.0 12780.5 12771.5 12756.0 12751.0 12745.5 12737.0 12730.5 12714.5 12701.0 97.0 THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MCNL REPEAT PASS. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE REPEAT PASS GRCH TO THE MAIN PASS GRCH; AND THE REPEAT PASS NRAT TO THE MAIN PASS NRAT. ALL OTHER MCNL CURVES WERE CARRIED WITH THE N-RAT SHIFT. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNT V 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12992.434 GRCH. CNT -999.250 NRAT. CNT 18.992 CCL. CNT -999.250 DEPT. 12695.934 GRCH. CNT -999.250 NRAT. CNT 21.577 CCL.CNT 85.820 NCNT. CNT 6053.995 FCNT. CNT 299.936 NCNT. CNT 5773 . 125 FCNT. CNT 265. 586 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, MCNL $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 9 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNAV GAPI 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 CVEL CNAV F/HR 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNAV CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNAV CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNAV 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12991. 934 GRCH. CNAV -999. 250 CVEL. CNAV FCNT. CNAV 304. 487 NRAT. CNAV 18. 569 20.240 NCNT. CNAV 6079.056 DEPT. 10768.434 GRCH. CNAV 84.432 CVEL.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 NRAT. CNAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 10 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.1 FILE SUM~UkRY VENDOR TOOL CODE START DEPTH STOP DEPTH 12999.49 10751.19 MCNL $ LOG HEADER DATA DATE LOGGED: 23 - SEP- 98 SOFTWARE VERSION: 0033A TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 13337.0 TD LOGGER (FT) : 13000.0 TOP LOG INTERVAL (FT) : 10763.0 BOTTOM LOG INTERVAL (FT) : 12997.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER MGR-18 LTTN-A13 11569.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 11 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) '. GAS~OIL RATIO '. CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -20 FAR COUNT RATE HIGH SCALE (CPS): 1080 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO ARCO PDC LOG DATED 19-MAY-98. VERIFIED ON DEPTH WITH ORIGINAL WELL SWS BHCS DATED 13-NOV-77. TAGGED TD AT 13000' FiD (337' HIGHER THAN EXPECTED). CLIENT BELIEVES THAT CEMENT IS PREVENTING FURTHER DESCENT. DEPTH CORRECTED MAIN PASS: ADDED 55.0 FT. DEPTH CORRECTED REPEAT PASS: ADDED 54.5 FT. FOUND NEW 3.5" LINER TOP AT 11026 FT MD. SURFACE LOCATION AND API # WERE TAKEN FROM BAKER HUGHES INTEQ GAFk4A RAW MWD LOG DATED 30-AUG-98 TO 21-SEP-98. THIS FILE CONTAINS THE RAW MCNL DATA FOR THE MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 12 TYPE REPR CODE VALUE 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 CVEL PSl F/HR 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 GR PSl GAPI 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT PS1 CPS 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT PS1 CPS 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 RTNR PS1 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 CCL PS1 V 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12999.492 CVEL.PS1 -999.250 GR.PS1 -999.250 RCNT. PS1 RCFT. PS1 -999.250 RTNR.PS1 -999.250 CCL.PS1 -999.250 DEPT. 10751.191 CVEL.PS1 -999.250 GR.PS1 -999.250 RCNT. PS1 RCFT. PS1 -999.250 RTNR.PS1 -999.250 CCL.PS1 85.000 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE ' FLIC VERSION · O01CO1 DATE · 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : · · LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 13 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 1 FILE SUM~L~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 13001 . 43 12680.73 MCNL $ LOG HEADER DATA DATE LOGGED: 23-SEP-98 SOFTWARE VERSION: 0033A TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 13337.0 TD LOGGER (FT) : 13000.0 TOP LOG INTERVAL (FT): 10763.0 BOTTOM LOG INTERVAL (FT) : 12997.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~IA RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER MGR - 18 LTTN-A13 11569.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 14 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2: 6~ BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -20 FAR COUNT RATE HIGH SCALE (CPS): 1080 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO ARCO PDC LOG DATED 19-MAY-98. VERIFIED ON DEPTH WITH ORIGINAL WELL SWS BHCS DATED 13-NOV-77. TAGGED TD AT 13000' MD (337' HIGHER ~EXPECTED). CLIENT BELIEVES THAT CEMENT IS PREVENTING FURTHER DESCENT. DEPTH CORRECTED MAIN PASS: ADDED 55.0 FT. DEPTH CORRECTED REPEAT PASS: ADDED 54.5 FT. FOUND NEW3.5" LINER TOP AT 11026 FTI~D. SURFACE LOCATION ANDAPI # WERE TAKEN FROM BAKER HUGHES INTEQ GANff4A RAW MWD LOG DATED 30-AUG-98 TO 21-SEP-98. THIS FILE CONTAINS THE RAW MCNL DATA FOR THE REPEAT PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 15 TYPE REPR CODE VALUE 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE ~ CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 CVEL PS2 F/HR 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS2 CPS 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS2 CPS 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS2 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS2 V 0000000 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 13001.434 CVEL.PS2 -999.250 GR.PS2 -999.250 RCNT. PS2 -999.250 RCFT. PS2 -999.250 RTNR.PS2 -999.250 CCL.PS2 -999.250 DEPT. 12680.734 CVEL.PS2 -999.250 GR.PS2 -999.250 RCNT. PS2 RCFT. PS2 -999.250 RTNR.PS2 -999.250 CCL.PS2 84.167 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:24 PAGE: 16 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC TAPE NAME : 98555 CONTINUATION # : 1 PREVIOUS TAPE : COM~4ENT : ARCO ALASKA, INC., PRUDHOE BAY, 2-1lA, #50-029-20273-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC REEL NAME : 98555 CONTINUATION # : PREVIOUS REEL : COM~ENT : ARCO ALASKA, INC., PRUDHOE BAY, 2-1lA, #50-029-20273-01
