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Home My WebLink About190-0497. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU WGI-08 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 190-049 50-029-22038-00-00 8907 Conductor Surface Intermediate Production Liner 8635 78 3440 8270 905 8860 20" 13-3/8" 9-5/8" 7" 8590 41 - 119 41 - 3481 38 - 8308 8000 - 8905 60 - 60 41 - 3481 38 - 8057 7761 - 8633 Unknown 470 2260 4760 7020 None 1490 5020 6870 8160 8357 - 8856 7-5/8" 29.7# x 7" 29# x 5-1/2" 17# L-80 36 - 7877, 7892 - 7941 8105 - 8586 Structural 5-1/2" HES TNT Packer 7679, 7465 7" Camco A-1 SSSV 2214, 2214 7979, 7831, 7892 7465, 7603, 7660 Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907-564-5683 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028302 36 - 7646, 7660 - 7705 Perforations from 8357 - 8856'MD See Attached Summary 155441 189521 5 50 3623 3573 325-318 13b. Pools active after work:Prudhoe Oil 7" Baker S3 Packer 7831, 7603 7" Baker SABL-3 Packer 7892, 7660 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:19 am, Aug 27, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.08.27 08:47:48 - 08'00' Bo York (1248) RBDMS JSB 082825 J.Lau 11/4/25 DSR-9/11/25 ACTIVITY DATE SUMMARY 8/9/2025 T/I/O = 2790/20/100 (TUBING WASH/PICKLE) Pump 10 bbls 50/50 for TBG spear. Pump 200 bbls of 180' Diesel down TBG. Pump 250 bbls FW w/ Surfactant down TBG and let soak for 2 hours. Over flush with remaining 328 bbls FW w/ Surfactant. Cap with 15 bbls 50/50. Well SI upon departure. DSO notified upon completion. FWHPs = 0/0/90 Daily Report of Well Operations PBU WGI-08 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC WGI-08 PRUDHOE BAY UNIT WGI-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 WGI-08 50-029-22038-00-00 190-049-0 G SPT 7603 1900490 1901 3731 3736 3737 3736 11 10 10 10 OTHER P Austin McLeod 5/12/2025 Post RWO. Sundry 325-019. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT WGI-08 Inspection Date: Tubing OA Packer Depth 180 2525 2533 2530IA 3734 11 45 Min 2525 60 Min Rel Insp Num: Insp Num:mitSAM250512201809 BBL Pumped:1.6 BBL Returned:2 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 9999 99 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 14:58:18 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: WAG Injector: WGI-08 (PTD #1900490) OA pressure bleeds Date:Monday, June 30, 2025 10:22:52 AM Attachments:WGI-08.pdf TIOChart.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 27, 2025 12:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: WAG Injector: WGI-08 (PTD #1900490) OA pressure bleeds Mr. Wallace, Gas Injector WGI-08 (PTD #1900490) had a RWO in April of 2025 to repair a production casing leak. The OA was cemented during a RWO in 2006. The well was recently shut-in for a drill by on L1-10 and after bringing the well back online, the OA pressure has continued to climb to ~300-400 psi where the operator has bled multiple times with only liquid returns. The IA pressure has stayed consistently ~5 psi so it does not appear to be IAxOA communication. This email is to notify you that we will continue to monitor and will make Under Evaluation if we suspect any IAxOA pressure communication. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. WELLI-EAD= WEVOY GEN2 ACTUATOR= BAKER OKB. R = 60' BF. ELEV = 21.89' KOP= 54D0' Max Angle = 30- @ 70D0' Datum MD = NIA DatumND= 88W SS 9-5/8- CSG, 47#, L-80 TCq D = 8.681" 2187' 7-5/8" CSG, 29.7# XO 7-5/8" CSG, 39#, D = 6.625" 3048' EXPANDABLE METAL CLAD PATCH — 5450' - 564i D = 7.673' Minimum ID = 3.725" @ 7855' XN NIPPLE REDUCER ITBG STUB(03/29125) 7768' 7-5/8" PC TBG, 29.7#, L-80 VAM TOP HC, 7798' 0459 bpf, ID=6.875" TBG PUNCH (03/25125) 7 I7" TBG, 29#, L-80 NSCC, .0371 bpf, D = 6.184" 7MV TOP OF 7" LNR 8000' 9-5/8' CSC, 47#, L-80, D = 8.681' PE RFORATDN SLAWRY REF LOG: FINAL CNP ON 04/03/90 ANGLE AT TOP PERF. 15" @ 8357' NDte: Refer to Production DB for historical oerf data —SE PG 2 FOR PEW SUATMRY- SAFETY NOTES: WELL REQUIRESA SSSV. DO NOT (1 PRESSUREOA ABOVE3000 PSI.*"WARNNG 2006 WG I O8 RWO TBG TALLY DISCREPANCY - WLBG IS 3 FEET ABOVE ORIGINAL PKR@ 7892'. ** OA CEMENT® FROM 22 TO SURFACE 68' 7" X 7-5/8" XO, D = 6.323" 2173' 9-5/8" HES ESSV CEMENTER 219T 7-5/8" X 7" XO, D = 6.184" 7" X 7-5/8" XO. D = 6.184" 6363' —j7-5/8" X 7" XO, D = 6.184" 762V 7" X 5-1/2" XO, D = 4.790" 762T BULLET SEAL, D=4.80" 7648' 7" X 5-1/2" XO, D = 4.80" 7679' H 9-58" X 5-1/2" TM PKR D = 4.820" 7T15-10" X I A MxNC NP D= 4 SR9" 7809' 1--1 7" HES R NP, D = 5.963" 7855 I 5.963' RN X 3.81' XN NP RED, D = 3.7 (03/17/25) 7677' 7" FULL MULESHOE WLEG, ID = 6.184" 7892' 9-5/8" X 7" BKR SABL-3 PKR. D = 6.0" 7926' H 6-5/8" HES RN NP, ID = 5.50- 7941' 7" WLEG, D=6.313" EXMD TT NOT LOGGE-D UNKNOWN H FGFt 2.70" X 7" R SUB (03120/06) PRJDHOE BAY UNIT WE-L: MI-08 PE MT No: 91900490 AR No: 5D-029-22038-00 SEC 11, T111A R14E, 963 F142 & 1060' FE - DATE REV BY COM E111TS DATE REV BY COMIENTS 04116U90 ORIGINAL COMPLETION 04/24/25 DB/JM) FINALIZE D INfE2VLNT10NS 06/03/99 WES LAST WORKOVER 011'18106 WES RWO 04/12125 WG NTERVLNTIONS RVVO 04/16/25 JM) UPDATED WBS Nlcorp North Slope, LLC 04/22/25 JGIJIW PULLED PLUG WGI-08 Minimum ID = 3.725" @ 7855' XN NIPPLE REDUCER PERFORATION SUMMRY RE= LOG: FINAL CNP ON 04/03/90 ANGLEAT TOP PERE 15' Q 8357' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 3-3/8" 4 8357 - 8403 O O6/02/90 3-318" 4 8442 - B488 O 06/02/90 3-318" 4 8492 -8691 O 06/02/90 3-318" 4 8697 - 8720 O 06/02/90 3-3/8" 4 8726 - 8788 O 06/02/90 3-3/8" 4 8794 - 8844 O 06/02/90 3-318" 4 8846 - 8856 O 06/02/90 PRUDHOE BAY UNIT WELL: WGFOB PERNTNo: 9900490 AR No: 50-029-22038-00 SEC 11, T11N, R14E, 963 FNL' & 1060' FEL DATE REV BY CONVENTS DATE REV BY CONVBNITS 04116190 ORIGINAL COMPLETION 04/2425 DB/JND FINALIZED INTERVENTIONS 06103/99 WES LAST WORKOVER 01/18/06 NOES RIND 04112125 IRIG INTERVENTIONS RVVO 04/16/25 JND UPDATED WBS lilcorp North Slope, LLC 04122/25 JG/JIVD PULLED PLUG W r 11 YY YY 111 11 11 11 11 111 11 11 11 11 YYY YY 11 11 11 111 11 11 11 11 YYY YY 11 ■ L=125 0410325 04/10/25 04/17/25 04124i25 05/01/25 ■ ■ 05,15125 0529125 300 29D ■ ■ ■ ■ ■ ■ 230 270 26D 250 240 230 220 210 200 190 130 170 1fi0 3 150 m m 140 m 130 120 110 100 90 30 70 fi0 50 40 30 20 10 Mi2125 W19125 0E12&25 TIO Plot f Tubing — On ■ Bleed * Operable + Not Oper ♦ Under Eval Man. IA —� Man. OA Man. OOA Man. OOOA O Man. WHT 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU WGI-08 Install Csg Clad, Tubing Swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 190-049 50-029-22038-00-00 8907 Conductor Surface Intermediate Production Liner 8635 78 3440 8270 905 8860 20" 13-3/8" 9-5/8" 7" 8590 41 - 119 41 - 3481 38 - 8308 8000 - 8905 60 - 60 41 - 3481 38 - 8057 7761 - 8633 Unknown 470 2260 4760 7020 None 1490 5020 6870 8160 8357 - 8856 7-5/8" 29.7# x 7" 29# x 5-1/2" 17# L-80 36 - 7877, 7892 - 7941 8105 - 8586 Structural 5-1/2" HES TNT Packer 7679, 7465 7" Camco A-1 SSSV 2214, 2214 7679, 7831, 7892 7465, 7603, 7660 Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907-564-4672 PRUDHOE BAY Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028302 36 - 7646, 7660 - 7705 N/A N/A 243342 163471 50 110 3707 3678 325-019 13b. Pools active after work:Prudhoe Oil 7" Baker S3 Packer 7831, 7603 7" Baker SABL-3 Packer 7892, 7660 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:18 am, May 22, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.21 16:45:46 - 08'00' Bo York (1248) JJL 6/13/25 RBDMS JSB 053025 DSR-6/3/25 ACTIVITY DATE SUMMARY 2/9/2025 T/I/O = SSV/630/20. Temp = SI. PPPOT-T, Cycle LDS-T. OA cemented to surface. Cycle all THA LDS, all function smoothly. Torque to 450 psi. Final WHPs = SSV/630/20. PPPOT-T: Stung into THA test void, 0 psi, bled small amount of fluid. Monitor for 10 min, no change in pressure. Increased void to 5000 psi for 30 min test. Lost 150 psi in 1st 15 min, lost 50 psi in 2nd 15 min for a PASS. Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG 16:30 2/16/2025 TFS U4, MIT-T Target of 4000 psi, MAP @ 4400 psi, Initial WHP T/IA/OA= 0/622/0, pressured up TBG to 4207 with 6 bbls diesel, First 15 minutes TBG lost 101 psi and IA lost 19 psi, Second 15 minutes TBG lost 26 psi, IA lost 2 psi, ****MIT-T PASSED**** Bled TBG down to 0 psi took back 6 bbls, Final WHP T/IA/OA = 0/622/0 2/28/2025 *** WELL S/I ON ARRIVAL*** OBJECTIVE WELLTEC TBG CUT RIG UP YJ ELINE. FUNCTION TESTED WIRELINE RIH W/ WELLTEC 4-1/4" MECHANICAL CUTTER ATTEMPT TO CUT 7-5/8" TBG @ 7768' 10' BELOW OF THE FULL JOINT, WELLTEC TOOL FAILURE AFTER SEVERAL STALLS TOOL LOST CURRENT NOTE: *** CUT NOT COMPLETE*** CORRELATED WITH TUBING TALLY DATED 1/15/2006 PRE ATTEMPT CUT T/I/O/260/600/0 PSI, POST ATTEMPT CUT T/I/O/= 260/600/0 ***PEFORMED MAN DOWN WITH CREW AND WELL SITE LEADER *** RDMO YELLOWJACKET ELINE JOB INCOMPLETE ***WELL S/I ON DEPARTURE**** 2/28/2025 T/I/OA= xx/xx/xx Assist E-Line to Confirm communication between IA and TBG. **JOB POSTPONED** 3/16/2025 (TFS unit 1 assist S-Line with load and test) ********WSR continued on 3-17- 2025********** 3/16/2025 ***WELL S/I ON ARRIVAL*** R/U POL-61 ***wSR CONT ON 3-17-25*** Daily Report of Well Operations PBU WGI-08 Daily Report of Well Operations PBU WGI-08 3/17/2025 ******WSR Continued from 3-16-2025******** T/I/O 80/600/0 (TFS unit 1 assist S- Line with load and test (MIT-T) Pumped 638 BBLS of brine down TBG for load. Pumped 115 BBLS of diesel down TBG for FP. Pumped 14.5 bbls of Crude down the TBG to test plug. MIT-T ******PASSED****** @ 3250 psi. Pumped a further 22 bbls of Crude down the TBG to reach a max applied psi of 3250 with a target of 3000 psi. 1st 15 min TBG lost 90 psi, 2nd 15 min TBG lost 10 psi for a total loss of 100 psi in a 30 min test. Bled TBG down to 500 psi bleeding back 4 bbls. Well left in S-Line control. Final WHPS 500/600/0 3/17/2025 ***WSR CONT FROM 3-17-25*** PULLED P-PRONG FROM PRN PLUG BODY @ 7855' MD PULLED PRN PLUG BODY FROM 7855' MD SET 5.963" RBXN w/ 3.81" XN PROFILE 7855' MD (5.963" RN x 3.81" XN Nipple reducer, 3.725" MIN ID) SET 3.81" XN PLUG (8 x1/8" ports, 25" oal) IN 5.963 RBXN AT 7855' MD T-BIRD PERFORMED PASSING MIT-T (see t-bird log) ***JOB COMPLETE, WELL LEFT S/I*** 3/18/2025 ***WSR CONT FROM 3-17-25*** R/D POL-61 ***WELL LEFT S/I*** 3/24/2025 WELL SI ON ARRIVAL OBJECTIVE TUBING PUNCH RIG UP ELINE FUNCTION TEST WL VALVES RIH WITH 5' TUBING PUNCH PUNCH 7.625" CASING LOG CORRELATED TO TUBING TALLY DATED 1-15-2006 SHOT TUBING @7804' AS PER TOWN CCL TO TOP SHOT 6.5' CCL STOP DEPTH 7797.5' GUN FIRED BUT LR WAS UNABLE TO CIRC RUN ANOTHER 5 FT TUBING PUNCH SHOOT TUBING @ 7780 FT CCL TO TOP SHOT 7.5' CCL STOP DEPTH 7772.5' LOG CORRELATED TO TUBING TALLY DATED 1-15-2006 UNABLE TO CIRCULATE LAID DOWN FOR THE NIGHT. CONTINUE OPERATIONS ON 03/25/2025 *** WELL SI ON DEPARTURE*** 3/24/2025 T/I/O= 925/615/9 (RWO EXPENSE) Asist E-line/circ-out. Pumped 3 bbls 60/40 MeOh into TBG to take returns up IA to OTT. TBG pressured up to1800 psi. Bled back TBG to 600 psi. Pumped 1 bbl 60/40 MeOh into IA to take returns up TBG to OTT. IA pressured up to 1500 psi. Bled back IA to 0 psi. Rolled 5 bbls 60/40 MeOh through hardline to OTT. Pressured TBG up to 2500 psi and monitored pressures. Bled back to 1200 psi. Job postponed. DSO notified upon departure. FWHP= 1200/507/9 Daily Report of Well Operations PBU WGI-08 3/25/2025 ***JOB CONTINUED FROM 03/24/25*** *** WELL S/I ON ARRIVAL*** OBJECTIVE SHOOT TUBING PUNCH RIG UP YJ ELINE. FUNCTION TESTED WIRELINE PRESSURE TEST 300 L/ 3000 H SHOOT TUBING PUNCH @ 7700' - 7705', CCL TO TOP SHOT 7.5', CCL STOP DEPTH 7692.5' CCL CORELATED TO TUBING TALLY DATED 1-15-2006 RDMO YELLOWJACKET ELINE JOB COMPLETE ***WELL S/I ON DEPARTURE**** 3/25/2025 T/I/O= 1000/584/15. Circulate Well (RWO EXPENSE) Pumped 32 bbls of 160*F diesel into the TBG to establish circulation. Pumped 100 bbls of Deep Clean, 360 bbls of 1% KCl, 600 bbls of 9.8 ppg NaCl brine and 19 bbls of 80* diesel into the TBG with IA returns to OTT. U-Tube TxIA for 30 minutes. Freeze Protect surface lines. Final WHPs = vac/vac/23 DSO notified upon LRS departure. 3/29/2025 T/I/O = 0/0/0. Pre I-Rig RWO. Set 6" J TWC #410. Removed 6" CIW Production Tree. Installed New 6" CIW MV (Tag 58). Torqued to API Specs. PT'd to 350/5000 psi against TWC. Passed. ***Job Complete*** Final WHP's = TWC/0/0. 3/29/2025 ***WELL SHUT IN ON ARRIVAL*** (TBG CUT) MIRU HES ELINE PERFORM MAN DOWN DRILL WITH CREW. FUNCTION TEST WIRELINE VALVES. PT PCE 300PSI LOW, 3000PSI HIGH. RIG W/ CH-1.375" FN/ 4.25" WELLTEC MECHANICAL CUTTER. CCL- CUTTER= 24.2', CCL STOP AT 7744'. CUT TUBING @ 7768'. RDMO HES ELINE ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE 3/30/2025 MIRU 3/31/2025 MIRU, Accept Rig at 09:00 hrs, N/D tree, N/U BOP,R/U and Test BOPE and associated equipment to 250/4000 psi as per Sundry 3/31/2025 T/I/O= 0/0/0 Bleed psi from void, monitor for 10 mins, psi @0+, N/D THA, clean up hanger and treads, M/U 7"xTCII XO 7 turns (good), remove XO and send to rig floor, install hanger neck protector, install new BX-160 ring gasket, Stand by for N/U and BOP test. 4/1/2025 T/I/O= 0/0/0 Pulled 6-3/8" J-plug with dry rod, M/U 4-1/2" IF X 7" TCII to a joint of 5" Drill pipe, RIH and make up 7.5 turns, B/O LDS to 4-3/8" C/B minimum and pull haneger to rig floor (220K), L/D hanger, prep hanger to get sent to tool service RKB to Tubing Hanger LDS = 21.50' RKB to IC-PO LDS = 23.87' Daily Report of Well Operations PBU WGI-08 4/1/2025 Cont testing BOP'S per sundrey AOGCC waived witness ( Adam Earl), Rock out DSL freeze protection, Pull hanger to floor, pump soap pill, POOH L/D tubing, Load pipe shed, P/U Clean out BHA 4/2/2025 POOH and L/D BHA, P/U test packer and RIH, test 9 5/8" casing below 5600' to 4000 psi for 10 min, Test 9 5/8" casing above 5500' to 4000 psi for 10 min, POOH 4/3/2025 POOH and L/D test packer, P/U lower completion and RIH, set packer and release from same, POOH and L/D running tool, Stage and tq inner string of casing patch 4/4/2025 Cont P/U WTF expandable casing patch per WFT rep, TIH to setting depth, anchor patch and attempt to expand patch with no succes. 4/5/2025 Wait on orders, Release from swedge, POOH and L/D running tools, Prep fishing BHA 4/6/2025 Latch onto wedge and expand Patch. MIT 9 5/8¿ casing POOH L/D DP, TIH w/ remaining DP from derrick, Slip and cut drill line, POOH L/D DP and BHA, wedge, Screw in sub, 2 x X/O's and circ sub left in hole. Process 5¿ DP and P/U fishing BHA, RIH picking up 5¿ DP 4/7/2025 Process 5" DP and P/U fishing BHA, RIH picking up 5¿ DP, Tag Fish at 5651¿ Attempt to engage fish, Cont. to TIH to 7590¿ and engage fish, POOH and stand back BHA, recovered circ sub, 2 x X/O¿s and screw in sub (wedge left in hole) P/U fishing BHA and TIH, engage fish and POOH 4/8/2025 Test BOP¿s per sundrey (AOGCC witness Brian Bixby, P/U fishing BHA and RIH. Engage fish and POOH 4/9/2025 ***CONT. WSR FROM 4-8-25*** POOH with fish F/7605' T/221' with 25K-70K overpulls through CSG patch. L/D all fishing BHA components. RIH to PBR and polished as per Baker rep. POOH laying down all 5" DP and polish mill. Change out UPR's to 7" solid body and attempt to PT to 4000 PSI with no success- Rams leaking. Pulled test jt to look for any abnormalities finding none. ***CONT. WSR TO 4-10-25*** 4/10/2025 LRS 46. Assist I-Rig w/ Freeze Protect. (RWO EXPENSE) Pumped 14 bbls Diesel into IA. ***Job Continued to 04-11-2025*** 4/10/2025 ***CONT. WSR FROM 4-9-25*** Open UPR's and inspect seals. Changed out seals and buttoned up doors. Attempted to test 7" rams agian with no success. Trouble shoot rams and test good. R/U TRS and RIH with Upper completion as per tally. Perform space out, R/U and reverse in 14 bbls of diesel and 150 bbls of CI-Brine. ***CONT. WSR TO 4-11-25*** 4/11/2025 ***Continue Job from 04-10-2025*** Assist I-Rig w/ Freeze Protect (RWO EXPENSE) Pumped 5 bbls (total of 19 bbls) Diesel into IA. DSO notified upon LRS departure. 4/11/2025 T/I/O=0/0/0 Land Tubing hanger NU THA & Tree Land tubing hanger, verify landed throuigh IA, Run in lock down screws, set 6" J TWC #424, stand by for BOP nipple down, clean void, replace (4) lock down screws, install new BX-160, install new DX seal, install THA/dry hole tree, test void 500 psi/5 min, 5000 psi/30 min, good tests, bleed off, stand by for rig to test tree, pull 6" J TWC, RDMO Final WHP's T/I/O=0/0/0 Daily Report of Well Operations PBU WGI-08 4/11/2025 ***CONT. WSR FROM 4-10-25*** Pump 5 bbls of diesel Strip through bag 3' and engage seals. Open bag and suck out stack. Land hanger with 205K on hanger. RILDS and L/D landing jt. Perform MIT-T & MIT-I/A to 4000 PSI for 30 min each. Witness waived by AOGCC Rep Brian Bixby. Install BPV and flush surface lines with soap/CI pills. N/D BOPE and N/U Tree. PT hanger void and tree 500/5000 PSI. RDMO WGI-08, Rig was released at 18:00 hrs. ***FINAL WSR*** 4/12/2025 T/I/O=0/0/0. Post I-Rig, Removed dryhole tree cap and installed 6" x 7" CIW Upper tree assembly w/ Baker C actuator. Torqued flange to spec. Pressure tested upper tree against MV to 300/5000 psi. Passed. ***Job Complete*** Final WHP's 0/0/0. 4/13/2025 ***WELL S/I ON ARRIVAL*** PULLED BALL & ROD FROM RHC BODY @ 7713' MD RAN 5-1/2" GS TO RHC BODY @ 7713' MD (unable to latch) RAN 2.50" S. BAILER (msfb) TO 7716' SLM (recovered 2 pieces of packing & 6" x 1/4" piece of hard plastic) PULLED RHC FROM 7713' MD ( rhc full of assorted rig trash ) RAN 4-1/2" DOGLESS GS w/ EQ PRONG TO 3.81 XXN @ 7855' MD (unable to equalize, deep metal marks on bottom of GS skirt, no marks on EQ prong) STAND-BY FOR WINDS ***GO ON WEATHER TICKET*** 4/14/2025 ***WELL S/I, COME OFF WEATHER TICKET*** RAN KJ, 3.75" CENT, 2' x 1-7/8" STEM, 3.80" CENT, 3.50" MAGNET (M-09) (recovered metal shavings) RAN 10' x 2.50 PUMP BAILER TO 7859' SLM, RECOVERED 2 CUPS OF METAL SHAVINGS, SMALL METAL CHUNKS RAN KJ, 3.75" CENT, 2' x 1-7/8" STEM, 3.80" CENT, 2.14 MAGNET TO 7860' SLM, RECOVERED 1/2 CUP OF SMALL METEL CHUNKS RAN 4-1/2" GS w/ EQ PRONG TO 7869' SLM, UNABLE TO SHEAR, NO MARKS ON EQ PRONG *** WSR CONT ON 4/15 *** 4/15/2025 *** WSR CONT FROM 4/14 *** RAN 10' x 2.00" PUMP BAILER (fbb) TO 7853' SLM, S/D HARD, NO RECOVERY MADE 4 RUNS w/ 10' x 2.00" PUMP BAILER (msbb) WORK TOOLS FROM 7961' TO 7962' SLM, (recovered 1/4 cup metal chunks & coil shavings, large chunk of rubber, large chunk of threaded brass) RAN DOGLESS GS TO 3.81 XXN @ 7855' MD ( sheared ) RAN BAITED 1.75 HS BAILER w/ MODIFIED 2.53 FLAPPER, GR SHEARED, TOOL LIH *** WSR CONT ON 4/16 *** Daily Report of Well Operations PBU WGI-08 4/16/2025 *** WSR CONT FROM 4/15 *** PULLED BAITED 1.75 HS BAILER FROM 3.81 XN @ 7855' MD ( no recovery ) RAN 10' x 2" HS BAILER w/ 3.64 FLUTTER CAGE ( no recovery ) PULLED 4-1/2'' XXN PLUG FROM NIP REDUCER @ 7855'MD ON 2nd ATTEMPT ATTEMPTED TO SET A1 SSSV IN R-NIP @ 2213'MD (BAD SET) PULLED SSSV FROM 5-1/2'' XO @ 7648'MD MADE ANOTHER UNSUCCESSFUL ATTEMPT AT SETTING A1 SSSV IN R NIPPLE @ 2213' MD JOB INCOMPLETE, WILL RETURN AFTER BLOW *** WELL LEFT S/I ON DEPARTURE *** 4/19/2025 ***CONTINUED FROM 4-16-25*** RAN 7'' BRUSH, 5.76'' G. RING TO SSSV NIP @ 2213' MD ATTEMPT TO SET INJECTION VLV IN SSSV NIP @ 2213' MD (No Success) ***WSR CONT. ON 04-20-2025*** 4/20/2025 ***WSR CONT. FROM 04-19-2025*** SET 5.963'' RQ-LOCK, MOD. A1 SSSV(SN: BVS-261, 3.50'' choke) IN SSSV NIP @ 2213' MD ***WELL LEFT S/I ON DEPARTURE*** 5/4/2025 ***WELL S/I ON ARRIVAL*** DRIFTED 2'x1.875", 5.99" G-RING, DRIFT FREELY TO SD @ 2,171' SLM PULLED RQ-LOCK, MOD A-1 SSSV FROM 2171' SLM w/ 5.625" GS, 5'x1.25" PRONG BRUSHED R-NIP ~ 2198' SLM / 2214' MD w/ 7'' BLB, 5.75'' G-RING ***WSR CONT ON 5-5-25*** 5/5/2025 ***WSR CONT FROM 5-4-25*** FAILED ATTEMPT SETTING 5.963'' R-LOCK, A1 SSSV 2214' MD (pre-set) ***JOB INCOMPLETE, MOVE TO WEATHER TICKET*** 5/6/2025 ***WELL S/I ON ARRIVAL*** FAILED ATTEMPT SETTING 5.963" R-LOCK, XO,3.81" X EQ SUB w/ END CAP @ 2196' SLM/ 2214' MD (pre-set) DRIFTED 3'x1.875",5.99" GAUGE RING TO @ 2,194' SLM (hard tag) DRIFTED 2'x1.875",3.80" SWAGE, DRIFT FREELY TO 5500' SLM LOGGED READ 40 ARM CALIPER FROM 5400' SLM TO SURFACE PER- PROGRAM (good data) FAILED ATTEMPT SETTING 5.963'' R-LOCK, XO 3.81" X EQ SUB w/ END CAP @ 2,195' SLM / 2214' MD (ran with bar bell set up) (pre-set) RUNNING 5.12'' CENT, 3' x 1-7/8'' STEM, 5.74'' CENT, (1-3/4'' FQC) (1-3/4'' MQC) 5.963'' R-LOCK w/ 3.81" X EQ SUB, END CAP (cont on next day, see log) ***WSR CONT ON 5-7-25*** Daily Report of Well Operations PBU WGI-08 5/7/2025 ***WSR CONT FROM 5-6-25*** MULTIPLE ATTEMPTS TO SET 5.963" R-LOCK IN NIPPLE @ 2,214' MD SUCCESSFULLY SET R-LOCK w/ MODIFIED KEYS MULTIPLE TIMES SET A-1 ON 5.963" R-LOCK w/ MODIFIED KEYS @ 2,214' MD SUCCESSFUL DTT 2500# psi to1500# psi (monitor 30 min, held solid) ***JOB COMPLETE, WELL LEFT S/I*** 5/12/2025 T/I/O= 3731/180/11. Temp= 140*F. LRS 70 AOGCC (Austin McCloud) MIT-IA to 1900 psi (2533 psi max applied) PASSED at 2525 psi. IA gained 8 psi during the first 15 minutes. IA lost 3 psi during the second 15 minutes and 5 psi during the second 15 minutes. IA lost 8 psi during the 30 minute test. Pumped 1.6 bbls of 140*F diesel to achieve test pressure. Bled back 2 bbls to final T/I/O= 3733/165/11. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU WGI-08 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 190-049 50-029-22038-00-00 341J ADL 0028302 8907 Conductor Surface Intermediate Production Liner 8635 78 3440 8270 905 8860 20" 13-3/8" 9-5/8" 7" 8590 41 - 119 41 - 3481 38 - 8308 8000 - 8905 3650 60 - 60 41 - 3481 38 - 8057 7761 - 8633 Unknown 470 2260 4760 7020 None 1490 5020 6870 8160 8357 - 8856 8105 - 8586 7-5/8" 29.7# x 7" 29# x 5-1/2" 17#L-80 36 - 7877, 7892 - 7941 Structural 5-1/2" HES TNT Packer 7679, 7465 7" Baker S3 Packer 7831, 7603 7" Baker SABL-3 Packer 7892, 7660 7" Camco A-1 SSSV 2214, 2214 Date: Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907-564-4672 PRUDHOE BAY 6/15/2025 Current Pools: Prudhoe Oil Proposed Pools: Prudhoe Oil Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:10 am, May 22, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.21 16:41:31 - 08'00' Bo York (1248) 325-318 SFD 6/10/2025JJL 5/30/25 DSR-6/3/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.10 11:55:34 -08'00'06/10/25 RBDMS JSB 061025 Well Work Prognosis Well Name:WGI-08 API Number:50-029-22038-00 Current Status:Gas Injector Leg: Estimated Start Date:June 15, 2025 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:190-049 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Jerry Lau Cell: 907-360-6233 Gas Injection Rate: 175,000 Mscf/Day Injection Pressure: 3,650 psi Reservoir Pressure (Estimate): 3500 psi Program Objective(s): WGI-08 is a gas cap injection well that has demonstrated a decrease in injectivity post RWO. The well has not been water washed since 2021. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: May 21, 2025Subject: Changes to Approved Sundry Procedure for Well WGI-08Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:Clint Montague - (C) Cc:Regg, James B (OGC) Subject:RE: 10-426 PB WGI-08 Innovation following RWO Date:Monday, May 5, 2025 10:09:24 AM Attachments:MIT PBU WGI-08 04-11-25 Revised.xlsx Clint, Attached is a revised report changing the Packer TVD to 7603’, adding the Sundry #, and moving the waived by verbiage to the Notes. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Clint Montague - (C) <cmontague@hilcorp.com> Sent: Friday, April 11, 2025 8:41 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; David Bjork <David.Bjork@hilcorp.com>; Christopher Yearout - (C) <Christopher.Yearout@hilcorp.com> Subject: 10-426 PB WGI-08 Innovation following RWO Attached is the 10-426 form for PB WGI-06 following the RWO conducted on Innovation rig, pre- injection. Let me know if you have any questions/comments. Thanks, Clint Montague Attached is a revised report changing the Packer TVD to 7603’, adding the Sundry #, and moving theAttached is a revised report changing the Packer TVD to 7603’, adding the Sundry #, and moving theAttached is a revised report changing the Packer TVD to 7603’, adding the Sundry #, and moving the Hilcorp DSM Innovation 907-670-3094 Office 907-394-0776 Cell The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1900490 Type Inj N Tubing 0 4195 4164 4149 Type Test P Packer TVD 7603 BBL Pump 5.0 IA 0 888 883 877 Interval O Test psi 4000 BBL Return 4.9 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1900490 Type Inj N Tubing 610 1585 1574 1565 Type Test P Packer TVD 7603 BBL Pump 3.0 IA 0 4200 4176 4164 Interval O Test psi 4000 BBL Return 3.0 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska PBU WGI Christopher Yearout 04/11/25 Notes:Pre-Injection MIT-T following RWO as per sundry 325-019. Witness waived by Brian Bixby Notes: Notes: Notes: WGI-08 WGI-08 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Pre-Injection MIT-IA following RWO as per sundry 325-019. Witness waived by Brian Bixby Notes: Notes: Form 10-426 (Revised 01/2017)2025-0411_MIT_PBU_WGI-08_2tests 04/11/25 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: WGI-08 (PTD #1900490) MITs passed post-RWO Date:Monday, April 14, 2025 9:27:54 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, April 11, 2025 11:04 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: WGI-08 (PTD #1900490) MITs passed post-RWO Mr. Wallace, The rig landed the completion and performed a passing MIT-T to 4,149 psi and passing MIT-IA to 4,164 psi. Slickline still needs to pull the B&R, set an injection valve and Well Support needs to reconnect the surface piping before the well can be brought online. The well will now be classified as OPERABLE. An AOGCC MIT-IA will be performed when the well is on stabilized injection. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, November 26, 2024 2:14 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WGI-08 (PTD #1900490) failed AOGCC witnessed MIT-IA Mr. Wallace, WGI-08 (PTD # 1900490) passed a PPPOT-T to 5000 psi and a PPPOT-IC to 3500 psi on 11/25/24. Today it failed an AOGCC witnessed MIT-IA with a LLR ~0.25 bpm @ 1900 psi. The well has been shut-in and will now be classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, November 24, 2024 9:56 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WGI-08 (PTD #1900490) possible PC leak Mr. Wallace, The IA pressure climbed again after another increase in injection gas temperature. The IA pressure should have been thermally stable after the two recent bleeds and with only fluid returns, this could be indicative of a Production Casing leak. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Fullbore: AOGCC witnessed MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, November 23, 2024 9:23 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Gas Injector WGI-08 (PTD #1900490) IAP bleeds Mr. Wallace, Gas Injector WGI-08 (PTD #1900490) has had two IA bleeds recently, one on 11/19 and one on 11/22. Both bleeds happened after temperature spikes of the injection gas and returns from the bleeds were all fluid, so it does not appear they were a result of TxIA communication. We will be monitoring the well and will make it Under Evaluation if it exhibits any signs of communication. Please respond with any questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT WGI-08 JBR 05/14/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 5" and 7/58" Test Joints, 7 5/8" JT had to function LPR and passed retest. Precharge Bottles = 14@950psi and 6@975psi. GOOD TEST Test Results TEST DATA Rig Rep:Joel StureOperator:Hilcorp North Slope, LLC Operator Rep:Clinton Montague Rig Owner/Rig No.:Hilcorp Innovation PTD#:1900490 DATE:4/8/2025 Type Operation:WRKOV Annular: 250/4000Type Test:WKLY Valves: 250/4000 Rams: 250/4000 Test Pressures:Inspection No:bopBDB250411044212 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 2600 Sundry No: 325-019 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8"x5"P #2 Rams 1 Blinds P #3 Rams 1 7 5/8"FP #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 2 3 1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P1350 200 PSI Attained P22 Full Pressure Attained P101 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P6@2392 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P9 #2 Rams P9 #3 Rams P9 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 99 9 9999 9 9 9 9 function LPR FP#3 Rams 7 5/8" MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC WGI-08 PRUDHOE BAY UNIT WGI-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/24/2025 WGI-08 50-029-22038-00-00 190-049-0 G SPT 7603 1900490 1901 3712 3712 36 34 OTHER F Kam StJohn 11/26/2024 MIT-IA Well under Eval for PC leak. After 3 min IA dropped to 1580 psi a 620 psi loss in 3 minutes failed. Leak rate test was done and started at .3 bblm at 1900 psi but settled out at .25 bblm at 1900 psi . Inj tbg pressure still at 3712 psi and OA 34 psi. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT WGI-08 Inspection Date: Tubing OA Packer Depth 324 2200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS241126105659 BBL Pumped:2.2 BBL Returned:0.4 Friday, January 24, 2025 Page 1 of 1 9 9 9 9 99 9 99 99 9 9 9 Eval for PC leak After 3 min IA dropped to 1580 psi a 620 psi loss in 3 minutes James B. Regg Digitally signed by James B. Regg Date: 2025.01.24 19:13:21 -09'00' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU WGI-08 C/O Tubing, Run New Completion Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 190-049 50-029-22038-00-00 ADL 0028302 8907 Conductor Surface Intermediate Production Liner 8635 78 3440 8270 905 7855 20" 13-3/8" 9-5/8" 7" 7625 41 - 119 41 - 3481 38 - 8308 8000 - 8905 2600 60 - 60 41 - 3481 38 - 8057 60 - 60 8859 470 2260 4760 7020 7855 1490 5020 6870 8160 8357 - 8856 7-5/8" x 7" L-80 36 - 7947 8105 - 8586 Structural 7"Baker S-3 7" Camco A-1 SSSV 7831 / 2202 7603 / 2202 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com (907) - 564-4672 PRUDHOE BAY 4-15-2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:45 pm, Jan 17, 2025 325-019 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.01.16 13:53:15 - 09'00' Bo York (1248) AOGCC witnessed BOP test to 4000 psi, annular to 3500 psi. AOGCC witnessed MITIA to above injection pressure. *Variance to 20 AAC 25.412(b) granted for setting packer >200 feet measured depth above top perforations. Packer set at proposed depth with verified cement (CBL 1/12/06) provides equivalent level of conformity. X SFD 1/24/2025 SFD JJL 2/6/25 X DSR-1/22/25 10-404 *&: 2/06/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.06 16:01:55 -09'00' RBDMS JSB 021025 RWO WGI-08 PTD:190049 Well Name:WGI-08 API Number:500292203800 Current Status:Shut-In Rig:Hilcorp Innovation Estimated Start Date:04/15/2025 Estimated Duration:11 days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Carrie Janowski Permit to Drill Number:190049 First Call Engineer:Dave Bjork 907-564-4672 907-440-0331 Second Call Engineer:Jerry Lau 907-564-5280 907-360-6233 Current Bottom Hole Pressure:3,480 psi @ 8,800’ TVD 7.6 PPGE | calc from shut in WHP Max. Anticipated Surface Pressure:2,600 psi (Based on 0.1 psi/ft. gas gradient) LastSI WHP:2,600 psi (Taken on 08/09/21) Min ID:5.50” ID ‘RN’ nipple @ 7,926’ MD Max Angle:30 Deg @ 7,000’ Brief Well Summary: WGI-08 was drilled in April 1990 and completed as a 7” monobore injector. The wellbore was worked over in 99 and 06 to upsize the tubing to 7-5/8” and repair IA x OA communication. An MIT-IA failed in Nov 24. A plug was set and the tubing was MIT-T to 2,250-psi, a CMIT-TxIA failed at5gpm @ 2,300-psi. An LDL indicated a leakpoint at 5,546’. The wellbore is currently loaded with 8.6 ppg seawater/KCl and a diesel freeze protect cap. We will now pursue a RWO to repair the PC leak and install a stacker packer completion with new injection tubing. Objective: Pull the existing 7-5/8” Injection tubing. Isolate leak (5,546ft) with test packer. Install the lower completion (PBR and packer). Set expandable clad across leak at 5,546ft. Run new 7” and 7-5/8” Injection tubing. Achieve a passing MIT-IA & MIT-T. Pre RWO work: DHD– MIT-T – 4,000-psi Cycle LDS’s PPPOT-T – 5,000-psi E-line - Cut tubing with welltech mechanical cutter at 7,768ft (10ft down on first full joint of tubing) Fullbore Attempt to circ out wellbore with 9.8ppg brine and diesel cap (tubing may be in compression and will not allow circulation). Valve Shop – Set and test J TWC Pull wellhouse and injection line. RWO WGI-08 PTD:190049 Proposed RWO Procedure: 1. MIRU Hilcorp Innovation Rig. 2. ND Tree and NU 13-5/8” BOPE with four preventers configured top down (annular, 2-7/8” x 5-1/2” VBR’s, blinds, mud cross and 7-5/8” fixed rams. 3. Test BOPE to 250psi Low/4,000psi High, annular to 250psi Low/3,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Hilcorp Innovation BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Testthe 2-7/8” x 5-1/2” VBR’s with 5” test joint. Test the Annular preventer with a 5” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC. 5. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~210K 6. Pull 7-5/8” tubing to floor, circulate bottoms up. LD 7-5/8” tubing. 7. PU 5” DP with 9-5/8” RTTS. RIH and test above and below the casing leak at 5,546ft to 4,000psi 8. RIH with lower completion packer and PBR, on PBR running tool. 9. Drop 1-7/8” ball-n-rod and set packer at 7,688ft. 10. POOH with PBR running tool. SBDP 11. RIH Metal skin expandable clad assembly. Set clad across leak at 5,546ft. 12. MIT wellbore to 4,000-psi. 13. POOH LDDP 14. Set a test plug and change the upper rams to 7” fixed and test to 4,000-psi. Pull test plug. Notify AOGCC 24hrs before testing. 15. Run 7” x 7-5/8” L-80 Injection tubing with seal assembly as detailed on proposed schematic. 16. Reverse in corrosion inhibited 9.8ppg brine and diesel FP. 17. Land tubing hanger. 18. Perform MIT-T to 4,000 psi and MIT-IA to 4,000 psi for 30 charted minutes. Give the AOGCC 24hrs notice to witness MIT-IA test. Document on State of Alaska form 10-426 19. Set TWC 20. ND BOPE and NU 7” tree and adapter. 21. Test the tree and adapter void to 5,000-psi. 22. Rig down Hilcorp Innovation. Post Rig Work 1. Pull Ball and rod and RHC profile, pull PRN plug. Set Injection valve in landing nipple at 2,200ft. 2. Reconnect injection lines and set wellhouse. Stabilized MIT-IA to 2,500-psi. Give the AOGCC 24hrs notice to witness MIT-IA test. Document on State of Alaska form 10-426 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. MOC form RWO WGI-08 PTD:190049 Wellbore Schematic RWO WGI-08 PTD:190049 Proposed Wellbore Schematic RWO WGI-08 PTD:190049 Innovation Rig BOPs Innovation Rig Choke Manifold RWO WGI-08 PTD:190049 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WGI-08 (PTD #1900490) failed AOGCC witnessed MIT-IA Date:Monday, December 2, 2024 10:20:52 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, November 26, 2024 2:14 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WGI-08 (PTD #1900490) failed AOGCC witnessed MIT-IA Mr. Wallace, WGI-08 (PTD # 1900490) passed a PPPOT-T to 5000 psi and a PPPOT-IC to 3500 psi on 11/25/24. Today it failed an AOGCC witnessed MIT-IA with a LLR ~0.25 bpm @ 1900 psi. The well has been shut-in and will now be classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, November 24, 2024 9:56 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WGI-08 (PTD #1900490) possible PC leak Mr. Wallace, The IA pressure climbed again after another increase in injection gas temperature. The IA pressure should have been thermally stable after the two recent bleeds and with only fluid returns, this could be indicative of a Production Casing leak. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Fullbore: AOGCC witnessed MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, November 23, 2024 9:23 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Gas Injector WGI-08 (PTD #1900490) IAP bleeds Mr. Wallace, Gas Injector WGI-08 (PTD #1900490) has had two IA bleeds recently, one on 11/19 and one on 11/22. Both bleeds happened after temperature spikes of the injection gas and returns from the bleeds were all fluid, so it does not appear they were a result of TxIA communication. We will be monitoring the well and will make it Under Evaluation if it exhibits any signs of communication. Please respond with any questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WGI-08 (PTD #1900490) possible PC leak Date:Sunday, November 24, 2024 4:22:18 PM Attachments:WGI-08.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, November 24, 2024 9:56 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WGI-08 (PTD #1900490) possible PC leak Mr. Wallace, The IA pressure climbed again after another increase in injection gas temperature. The IA pressure should have been thermally stable after the two recent bleeds and with only fluid returns, this could be indicative of a Production Casing leak. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Fullbore: AOGCC witnessed MIT-IA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, November 23, 2024 9:23 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Gas Injector WGI-08 (PTD #1900490) IAP bleeds Mr. Wallace, Gas Injector WGI-08 (PTD #1900490) has had two IA bleeds recently, one on 11/19 and one on 11/22. Both bleeds happened after temperature spikes of the injection gas and returns from the bleeds were all fluid, so it does not appear they were a result of TxIA communication. We will be monitoring the well and will make it Under Evaluation if it exhibits any signs of communication. Please respond with any questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. TREE = 6-3/8' CAMERON WELLHEAD= McEVOYGEN2 ACTUATOR= BAKER OKB. ELEV = 60' BF. ELEV = 21.W KOP = 54W Max Angle = 30' Q 7OW Datum MD = WA n=a".. �n = aann- ca 9-5/8" CSG, 47#, L-80 TCi D = 8.681" 1--1 2187' I 1 13-3/8" CSG, 68#, K-55 & L-80, D = 12.415" I--1 3481' WGI-08 7-58" PC TBG, 29.7#, L-80 VAM TOP HC, I� 779W .0459 bpi, ID = 6.875" Minimum ID = 5.50" @ 7926' 6-5/8" HES RN NIPPLE '" TBG, 29#, L-80 TC4 .0371 bDf, ID = 6.184" TOPOF7"LNR 8000' 9-5/8" CSG, 47#, L-80, D = 8.681" PERFORATION SUMMARY REF LOG: FINAL CNP ON 04/03/90 ANGLE AT TOP PERF: 15' @ 8357' Note: Refer to Production DB for historical pert data SIZE SP7= MHZVAL Opn/ScFz SHOT SQZ 3-3/8" 4 8357 - 8403 O 06/02/90 33/6" 4 8442 - 8488 O 06/02190 33/6" 4 8492 -8691 O 06/02/90 3-3/8" 4 8697 - 8720 O 06/02/90 3-3/8" 4 8726 - 8788 0 06/02/90 3-3/8" 4 8794 - 8844 O 06/02190 33/8" 4 8846 - 8856 O 06/02/90 SAFETY NOTES: WELL REQUIRES SSSV. DO NOT PRESSURE OA ABOVE 3000 PSI.'*WARNNG: 2006 RWO TBG TALLY DISCREPANCY - WLEG IS 3 FELT ABOVE ORIGINAL PKR @ 7892'. - OA CEM ELATED FROM 22' TO SURFACE 20- 7" X 7-5/8" XO, D 6.323" 2173' 9-5W HES ESSV CEMIM 2 2178' 7-51W X 7" XO, D = 6.184" 218 I' 7" CAMOO DB-6 NP, ID= 6.00" 99nn- 1 7^X7-51a"X0 n=a lad" 7798' I--j 7-5/8" X 7" XO, D = 6.563" 7831' H 9-5/8" X 7" BKR S-3 PKR, D = 6.151 785W 7" HES RN NP, ID = 5.770' { 7877- 7" FULL MULESHOE WLEG, D = 6. 7892' 9-5/8" X 7" BKR SABL-3 PIQ2, D = 7926• 6-5/8- HES RN NP, D = 5.50" 7941' 7" WLEG, D=6.313" ELND TT NOT LOGGED UNKNOWN 1-i FISH: 2.70" X 7" P. SUB (03/20/06) DATE REV BY COMMENTS DATE REV BY COMMENTS 04/16/90 ORIGINAL COMPLETION 09/01/07 JMSV SAFETY NOTE UPDATED 06/03199 WES LAST WORKOVER 02111/11 MB/JMD ADDED SSSV SAFETY NOTE 01/18/06 NOES RWO 11l07l19 DD/JMD ADDED BF ELEV 012V06 KSB/TLH DRLGDRAFT CORRECTIONS =20/06 JDM/TLH FISH LEFT IN HOLE 00/19/07 MSS/PJC CMT 22' TO SURFACE OA PRUDHOE BAY UNIT WELL: WGI-08 PERMIT No: 1900490 API No: 50-029-22038-00 SEC 11, T11 N, R14E, 963 FNL' & 1060' FEL Filcorp North Slope, LLC Well: WG E 31D0 5,500 ■ ■ ■ 280 5.000 260 TIO Plot 4,50D 240 4,0OO 220 f Tubing 2W — On 3,500 180 m ■ Bleed 3.000 . O Operable �-0 .e E 8 e E E 5 8 5 5 D 140 m + Not Oper 2 500 120 m ♦ Under Eval 2,01M — Man. IA 100 —A Man. OA 1,500 80 Man. OOA 1 000 Mon. OOOA 40 n Man. WHT 500 IN 20 0&23i24 MNY24 OROD24 09A324 0921C24 D9127124 10104J24 1011124 10+18124 1a2524 11M1124 1110824 1111524 1112Z24 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg ` 1 DATE: Wednesday, August 11, 2021 P.I. Supervisor Cy SUBJECT: Mechanical Integrity Tests 11 Hileorp North Slope, LLC WGI-08 FROM: Jeff Jones PRUDHOE BAY UNIT WGI-08 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-08 API Well Number 50-029-22038-00-00 Inspector Name: Jeff Jones Permit Number: 190-049-0 Inspection Date: 7/21/2021 ' [nsp Num: mitJJ210810165139 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-08Type Inj G ,TVD 7603 Tubing 3526 3525 3523 3521 PTD 1900490 Type Test� SPT Test psi 1901 )A 2438 2506 2491 2491 BBL Pumped: 3.2 "iBBL Returned: 3.2 OA 200 z16 238 264 — - Interval 4YRTST �P/F I ✓� Notes: This well initially failed the MIT due to a leaking bull plug at surface on the well head (see mitJ.121081 l 100420). The leak was repaired, however the OA pressure failed to stabilize durin the test and additional diagnostics may be warranted. Test result is inconclusive. One well inspected, no excep iolt �s noted. Wednesday, August 11, 2021 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11, 2021 TO: Jim Regg SUBJECT: Mechanical Integrity Tests P.I. Supervisor �G( 22 ( Hilcorp North Slope, LLC WGI-08 FROM: Jeff Jones PRUDHOE BAY UNIT WGI-08 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J3&L NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-08 API Well Number 50-029-22038-00-00 Inspector Name: Jeff Jones Permit Number: 190-049-0 Inspection Date: 7/21/2021 Insp Num: mitJJ210811100420 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min T 900 3522 3526 - 3526' Well �- 1 D 7603 2 490 Type Test SPT Test -- 1901 Tubing IA' 50 523 2508 2476 2438�- Pumped: 3.2 BBL Returned: o OA 147 154 , 176 200 BBL -- T - - -�- - �___ Intervall 4YRTST p/j F Failed MIT due to a leaking bull plug at surface on the well head. Retested the same da (see MITJJ210810165139 Notes: g P g Y )� Wednesday, August 11, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg T2 P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2021 SUBJECT: Mechanical Integrity Tests Hilcoip North Slope, LLC WGI-08 PRUDHOE BAY UNIT WGI-08 Src: Inspector Reviewed By: P.I. Supry J Comm Well Name PRUDHOE BAY UNIT WGI-08 API Well Number 50-029-22038-00-00 Inspector Name: Matt Herrera Permit Number: 190-049-0 Inspection Date: 7/24/2021 Insp Num: mitMFH210724094311 Rel Insp Num: Monday, July 26, 2021 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-08 'Type In' � G -!TVD 7603 Tubing 3456 3457 3459 - 3465- PTD 19ooa90 T a Test38 p SPT- Test p SI � 1901 �� t 2456 � 2423 - 2419 BBL Pumped: p 3.8 BBL Returned 140 143 • 146 148 -- -- Interval ---- --- —- 4YRTST PIF P ✓`. - ----' - ---- -'— � Notes: MIT -IA Performed to 2500 PSI Per Operator. Previous MIT -IA inconclusive on 7/21/21. OA Bled down by Operations on 7/23/21. OA cemented at surface. Monday, July 26, 2021 Page I of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:190-049 6.50-029-22038-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 8907 8860 8590 7844 , 7907 8859 none 7615 , 7668 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 41 - 119 41 - 119 1490 470 Surface 3440 13-3/8" 41 - 3481 41 - 3481 5020 2260 Intermediate 8270 9-5/8" 38 - 8308 38 - 8057 6870 4760 Production Perforation Depth: Measured depth: 8357 - 8856 feet True vertical depth:8105 - 8586 feet Tubing (size, grade, measured and true vertical depth)7-5/8" x 7" L-80 36 - 7947 36 - 7713 7844 , 7907 7615 , 7668Packers and SSSV (type, measured and true vertical depth) 7"Baker S-3 , 7" Bkaer SABL-3 Liner 905 7" 8000 - 8905 7761 - 8633 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: David Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) - 564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ 5 WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8635 Sundry Number or N/A if C.O. Exempt: 320-540 7" Camco A-1 SSSV 2202 2202 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Water Wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028302 PBU WGI-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Meredith Guhl at 12:32 pm, May 17, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.17 10:39:11 -08'00' Bo York SFD 5/21/2021DSR-5/17/21 RBDMS HEW 5/17/2021MGR26JUL2021 REVISED ACTIVITYDATE SUMMARY 4/21/2021 T/I/O= 2700/200/0. LRS unit 72 Tubing Wash (TUBING WAS/PICKLE). Pumped 10 bbls of 60/40 MeOH, 50 bbls of 120*F diesel and 353 bbl of freshwater with 0.02% F- 103 surfactant. Let the diesel soak across the perfs for 2 hours. Pumped another 235 bbls of FW w/surfactant and 15 bbls of 60/40 MeOH.Final T/I/O= 0/100/0 Daily Report of Well Operations PBU WGI-08 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:190-049 6.50-029-22038-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 8907 8860 8590 7844 , 7907 8859 none 7615 , 7668 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 41 - 119 41 - 119 1490 470 Surface 3440 13-3/8" 41 - 3481 41 - 3481 5020 2260 Intermediate 8270 9-5/8" 38 - 8308 38 - 8057 6870 4760 Production Perforation Depth: Measured depth: 8357 - 8856 feet True vertical depth:8105 - 8586 feet Tubing (size, grade, measured and true vertical depth)7-5/8" x 7" L-80 36 - 7947 36 - 7713 7844 , 7907 7615 , 7668Packers and SSSV (type, measured and true vertical depth) 7"Baker S-3 , 7" Bkaer SABL-3 Liner 905 7" 8000 - 8905 7761 - 8633 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: David Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) - 564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ 5 WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8635 Sundry Number or N/A if C.O. Exempt: 320-540 7" Camco A-1 SSSV 2202 2202 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Water Wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028302 PBU WGI-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Meredith Guhl at 3:09 pm, May 13, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.13 14:35:56 -08'00' Bo York DSR-5/13/21 SFD 5/17/2021RBDMS HEW 5/13/2021 SUPERCEDED ACTIVITYDATE SUMMARY 4/21/2021 T/I/O= 2700/200/0. LRS unit 72 Tubing Wash (TUBING WAS/PICKLE). Pumped 10 bbls of 60/40 MeOH, 50 bbls of 120*F diesel and 353 bbl of freshwater with 0.02% F- 103 surfactant. Let the diesel soak across the perfs for 2 hours. 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PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU WGI-08 Permit to Drill Number: 190-049 Sundry Number: 319-511 Dear Mr. Brown: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a I a s ka . g a v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. 'Sincerely, J r 6 ChaPr1ice ir DATED this N day of November, 2019. ?BDMSt"' NOV 18 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n nnr 95 van Nov 0 7 into 0991 `q�C; (( 1311 z -i Form 10-403 Revised 04/2017 ORIGINAL Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate 1. Type of Request: Abandon ❑ Plug Perforations p Fracture Stimulate ❑ Repair Well ❑ Operations Shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Water Wash 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 190-049 3. Address: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029-22038-00-00 . 99519-6612 Stratigraphic ❑ Service 0. 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU WGf-08 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028302 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft) Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): PWgs (MD): Junk (MD): 8907 8635 8860 8590 8859 Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20" 41-119 41-119 1490 470 Surface 3440 13-3/8" Al - 3481 41 - 3481 5020 2260 Intermediate 8270 9-5/8" 38-8308 38-8057 6870 4760 Production Liner 905 7" 8000-8905 7761 -8633 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8357-8856 8105 - 8586 7-5/8" 29.7# x 7" 29# L-80 36-7949 Packers and SSSV Type: 7" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 7844/7615 7" Baker SABL-3 Packer 7901 /7668 7" Carrico A-1 SSSV 22021 2202 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work. Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: 11/29/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 ' Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Brown, Don L. be deviated from without prior written approval. Authorized Name: Brown; Don L. Contact Email: brcwd20BP.com Contact Phone: +1 9075644675 Authorized Title: Petroleum Engineer Authorized Signature: Date: -7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �/ I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ �� Other: 1BDMS6'NOV 102019—/ Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Required? ception Yes No UY Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 11 q 0991 `q�C; (( 1311 z -i Form 10-403 Revised 04/2017 ORIGINAL Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate 10-403 Sundry Application for Well PBU WGI-08 PTD #190-049 Expected Start Date: November 29, 2019 Current condition of well: Gas Injection Well, Operable, Online: Gas Injection Rate: 1217186 Mscf/Day Injection Pressure: 1 3466 psi Reservoir Pressure (Estimate): 1 3427 psi Program Objective(s): WGI-08 has had several successful water washes historically, the most recent being on 10/22/16. These water washes have been successful and injectivity in this well has decreased since the 2016 water wash. If this water wash goes to plan, injectivity should improve as the process is designed to dissolve salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Proposed Program: 1. Pump diesel/xylene water wash as per attached pumping template BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU WGI-08 PTD #190-049 Pump Schedule: Well WGI-08 Work Desc lVoi APE G Date 10,'30.+14 Engineer Don Brown Phone iH7Y_`b4-4675 H2S Value IVA H2S Date ivA Gear Increase well injectrvity, by performing a water wash. Use 2 fu!I upnghs of `fresh water mixed with 0.02% F-103 surfactant. Use 200 bbls of diesel/xylene. Pu SchMuk Stacie Fluid Type Pu Into lVoi " Rate Max Wes i 1 Spear Methanol l Yuater TBG 10 1-3 2SCC 2 Solvent Diaselr<ylene TBG 200 Max 2500 Over -Flush Fresh Water TBG 600 See Below 2500 4 Freeze Protect MemanalilVater TBG 10 1-3 25CO 5 6 7 1.)10 bbi 60140 McOH/water spear 2.i 200 bbls 50/50 oiese!/xylene heated to 80 degrees F or as hot as LRS can heat z. 3.) Pump 600 bbis of fresn water with 0.02% F-103 surfactant per following: a.) Pump 282 bbis of fresh water with 0.02% F-103 surfactant at 1-3 bpm, shut-dev, n pumps and let diesel/xylene soak across oerfs for 4 hours - this should aloes - 100 bbis of D/X to be pumped Into perfs and a reni 100 bb's tc soak. b.) Resume pumping at 0.5 bpm for next 200 bbis of fresh water with, 0.02% `--103 c} Once 482 bbls of fresh water with 0.02% F-103 surfactant has been pumped resume pumping at 1-3 bpm for remainder of overflush (-418 bbls). 4.) 10 bbis of 60/46 McOH/water freeze protect Directions When Ming out the pumping template, please note the following MIT 31 Test Type Target Pressure Max Applied Pressure Test Fluid integrity Lmits Confirmed ❑ MIT $2 Test Type Target Pressure idax Applied Pressure Test Fluid Integrity Lkrits Confxmed ❑ 41I 43 Test Type Target Pressure Max Applied Pressure Test Fluid Intei Limits Confirmed ❑ If "MIT' is selected as a stage, the corresponding MIT section must be filled out. The boxes are defined as foliov+s. Test Type: Type of test to be performed (MIT -T, MIT -IA, MIT -OA, etc) '. Target Pressure: This is the requested Mill test pressure ('ie MIT -T to 2500 psi) Max Applied Pressure: This is the max pressure that can be applied in order to achieve a passing MIT of the target test pressure, typic^, 10% greater than target pressure. SP practice 100218 (10-45) requires that the test pressure must remain above or equal to the target pressure during the entire test evaluation period. This pressure must not exceed the lowest rated working pressure (taking into account corrosion. erosionetc) of any well barrier element in the well barrier envelope. Test Fluid: The fluid to be used for the test. Integrity Limits Confirmed: By checking this boxyou have confirmed that the "Max Applied Pressure" requested is within the limits of the yells "Wall Barrier Envelope BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU WGI-08 PTD #190-049 Wellbore Schematic: TREE • 6318' CAMFN, MIELLHEAD. MC MGEN7' AMATORa _ BAKER: OKB. ELEV - 66 BF, ELEV- 21.66 KM- ,SWD• W.Anye= _ _ 30 omw Oaam MDQ WA' Oaa4n NDS BB Minimum 0) = 6.60" @7826' �6-6/8" HES RN NIPPLEI SAFETY MOTS: VAML REQMES A SSSV. DO MDT � � RmISWGI-08 iO FEET ABOVE MGMAL PKRfk MT. - OA CMMM FRM Zr TO MMACE 7 TM 29 a, L-80 TC1.0371 bf, D=6.1&1' 7871 TCA OF T'LNR -- w FEf0R4TDNSLMAARY REF Lo(T FH4L @AON 04!0390 ANCiEATTOPPERF, 15' Q 835T NPM' Refer b Rod hon B fm Mabr" Part daL WE SFF N19NAL opfrgz SFDT SOL b3f8' 4 8357-8103 O� 06002M,3-aW 4 8442-8488 O 06MM01 }W 4 8492 -8891 O OG/NA0 33!8' 4 8697 - 8720 O 0810280 3316' 4 8726 - 8786 O 089280 3318' 4 8794-58M O 0&O?NO 33W 4 am -am O OBN2A0 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 _-PRUDHOEBAYLWT - Y4ELL W M PERMITW: L 1900490 AMM: 50-029,Z?03800 SP Eapbra8on (ArYp • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,July 25,2017 P.I.Supervisor 7(7-V1 7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. WGI-08 FROM: Bob Noble PRUDHOE BAY UNIT WGI-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-08 API Well Number 50-029-22038-00-00 Inspector Name: Bob Noble Permit Number: 190-049-0 Inspection Date: 7/20/2017 Insp Num: mitRCN170720123336 Rd Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-08 Type Inj G TVD 7603 Tubing 3766 3767 3766 ' 3767 3767 - PTD 1900490 -Type Test SPT Test psi 1901 IA 18 2207 - 2195 . 2180 - 2173 - BBL Pumped: 3.5 BBL Returned: 2.6 OA 42 - 39 43 - 45 ' 47 , Interval 4YRTST P/F P Notes: SCANNED 3 E P 1 01 Tuesday,July 25,2017 Page 1 of 1 • (hT 190041 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, July 5, 2017 3:18 PM �� 7/5117 To: AK, GWO Well Integrity Well Information; AK, GWO Projects Well Integrity;Wallace, Chris D (DOA); Brooks, Phoebe L (DOA) Cc: AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Engineer; Bixby, Brian D (DOA) Subject: RE:June 2017 MIT Forms Attachments: MIT PBU 09-37 6-5-17 revised.xlsx; MIT PBU R-13 6-22-17 reivsed.xlsx; MIT PBU WGI-08 6-10-17 revised.xlsx PBU 09-37 (PTD 1940280): all 3 attempts are failed tests PBU R-13 (PTD ): deleted "Chuck Scheve waved witness" (AOGCC rep) ✓PBU WGI-08 (PTD 1900490): Increasing pressure on tested annulus does not equate to stabilization(failed test per our requirements, inconclusive at best); should have monitored pressure for additional 15-30 minutes. Revised reports attached. Jim Regg Supervisor, Inspections AOGCC (--p 491M 333 W.7th Ave,Suite 100 SC0451 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From:AK, GWO Well Integrity Well Information [mailto:akgwowellintegritywe@bp.com] Sent: Sunday,July 2, 2017 5:58 AM To:AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; Regg,James B (DOA) <jim.regg@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov> Cc:AK, GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Subject:June 2017 MIT Forms All, Attached are the filled out AOGCC MIT forms for tests performed by BP in June of 2017. Well: PTD: Notes: DS09-37 1940280 AA 04E.000 Well Failed an AOGCC MIT-IA on 06/05/17 and was made not operable D513-06 1972180 AA 4F.004 for shallow packer depth.: Passed MIT-IA on 6/19/2017 DS13-24 2042430 AA 4E.037 for TxIA communication: Passed MIT-IA on 6/5/17 A-08 1740040 AA 3.019 for slow TxIA communication: Passed MIT-IA on 6/10/2017 R-13 1830440 MIT-IA passed on 6/22/2017 1 0 11110 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reod(Malaska.00v' AOGCC.Inspectors(cDalaska.aov phoebe.brooksc alaska.00v chris.wallace(talaska.aov OPERATOR: BP Exploration(Alaska),Inc. 7// FIELD/UNIT/PAD: Prudhoe Bay/PBU/WGI -/}/. G�17 ' 7 DATE: 06/10/17 '''' It%l vl 1 OPERATOR REP: Mike Zimmer AOGCC REP: Brian Bixby Well WGI-08 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1900490' Type Inj G , Tubing 3406 - 3407- 3419 . 3428 Type Test P - Packer TVD 7603 - BBL Pump 4.8 • IA 227 2204 r 2209 - 2255 - Interval 4 _ Test psi 1901 -BBL Return 2.2 ' OA 37 • 36 - 38 • 40 • Result ......P"--- J•- Notes: Pre AA application test. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Retum OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD • BBL Pump IA Interval Test psi BBL Return OA - Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj TubingType Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: • Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing . Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result • Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT PBU WGI-08 6-10-2017 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 22,2017 TO: Jim Regg P.I.Supervisor (" efet ( '' 7SUBJECT: Mechanical Integrity Tests P BP EXPLORATION(ALASKA)INC. WGI-08 FROM: Brian Bixby PRUDHOE BAY UNIT WGI-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 5ga- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-08 API Well Number 50-029-22038-00-00 Inspector Name: Brian Bixby Permit Number: 190-049-0 Inspection Date: 6/10/2017 Insp Num: mitBDBI70610163413 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 WGI-08 Type Inj G TVD 7603 Tubing 3406 3407 3419 -r 3429 PTD 1900490 ' Type Test SPT Test psi 1901 IA 227 2204 ' 2209 2255 - BBL Pumped: 1 4.8 ' BBL Returned: 2.2 - OA 37 36 - 38 - 40 Interval 4YRTST P/FL I Notes: Pre ssL�� SCANNED AUG 2 22011, Thursday,June 22,2017 Page 1 of 1 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMI4)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate I! Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Water Wash WI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 190-049 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-22038-00-00 7. Property Designation(Lease Number): ADL 0028302 8. Well Name and Number: PBU WGI-08 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 8907 feet Plugs measured feet Jul_ true vertical 8635 feet Junk measured 8859 feet u �9 2 P 2016 Effective Depth: measured 8860 feet Packer measured See Attachment feet true vertical 8590 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 78 20"91.5#H-40 41 -119 41-119 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 904 7"29#L-80 8004-8908 7764-8636 8160 7020 Perforation Depth: Measured depth: 8357-8403 feet feet 8442-8488 feet 8492-8691 feet 8697-8720 feet 8726-8788 feet 8794-8844 feet 8846-8856 feet True vertical depth: 8105-8149 feet feet 8187-8231 feet 8235-8427 feet 8433-8455 feet 8461-8520 feet 8526-8574 feet 8576-8586 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 7"Camco A-1 SSSV 2206 2206 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8357'-8403',8442'-8488',8492'-8691',8697'-8720',8726'-8788',8794'-8844',8846'-8856'. Treatment descriptions including volumes used and final pressure: c7(I" to Bbls 50/50 Methanol/Water,100 Bbls Diesel,100 Bbls Xylene,445 Bbls Fresh Water Representative F-103 Surfactant,1391 psi. c ®p�E� # a LU 13. epresentative Daily Average Production orr InjectionData Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 246451 400 3431 Subsequent to operation: 280260 1000 3574 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ a 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: 315-241 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 7/27/16 Form 10-404 Revised 5/2015 1/71.. 1/21 1 G, RBDMS u,-, PG - 1 2016 Submit Original Only • • Packers and SSV's Attachment PBU WGI-08 SW Name Type MD TVD Depscription WGI-08 SSSV 2206.13 2206.13 7" Camco A-1 SSSV WGI-08 TBG PACKER 7847.98 7618.81 7" Baker S-3 Packer WGI-08 TBG PACKER 7905.02 7671.79 7" Baker SABL-3 Packer ® • .p p 0 0 0 0 0 p 0 0 0 O_ co Lf) O O CO N N O) N 6) N ti O - N ct N- N N- Ln V Cn/) CD CD CD 0 CD CD CD CD CD 0 CD CD 1.- 0) LO N N- N- CO CO 0) CO 0) CO "1- M V O CO CO a-- a- CO a- CO a- N m r M LC) co CO cocoCO co (D CO N- O N- CO 0 CO 6) N N- O) N 0) O CO CO O '— CO CO r. CO V N O M — N Ln CO N- CO N CO CO N N0V'' LC) CO CA O a- a- N CO O CO O r C) - CO 'Cr "Cr CO Cr) N N- CO a- N LC) CO N I- N N C O O N- N 00 LO CO CO LC) CO N O O O N- O) v CA LC) - CO V N CO O V N CO CO CA = CO N CO CO N N V 4.1 • O Q I OLO CO CO CO j n - N OO O O CO CO`J CO CO N O CO — N CO CA C N CO N N I` N- • W LC) O CD CD CL p O Lf) CO � co— co co CS) ' Y J J J co co J CO CO CO ▪ (y co co 4 �$ J J J J J U) '- - _ O CA N O N 6) co C13U 6) M -0O N N - N - N N M N co M (A t +-' 00 CO r V co a)00 O Ln LC) M O O r- = I"- V a- '- N LO I- LO C) CO N CO O N LC) J w w Q _Q = O w w a 0 U w 22 0 O O u_ c iI Z Z Z Z Z z ODDHHZDDDDDD UU) v) ZZjHHHHHH- • . CD? o \ f / / 5R _o * » 5 = o / co 4- 0.\ / a % / \ CC / ) .iEm = ® / / � / / \ R 7 o c c 6 \ R 2 R '' e c \ /- o & o ca = o c o = = e f y\ \ - \ Co w $ \ � o & ± o » £ co o f a / E I = U = I 0 2 �\ 32 / $ / � R \ ted = y ± U 0 , m / E R2c \ 9 J0 \ �\ \ Rf 3 � R 2 / / / $ # o m o) § 2 - = O ^ \ 3f � R/ 3 �o � --c't 2 / J 7 / / / y / / >+ E 2 / 6 2 W Cti § / » \ / 2 b / \ 5 / \ ) \ / 6 2 g e n / 6 r = w o 0 \ _ _ '- > c 45 \ s-- k § \ cam -® \ $ k o \ c » « / E % / _ ƒ C ƒ / \ / ƒ / i \ / / 5 X 2 w \ co e >- / \ ( / \ \ \ 6 6 « 9 • NOTES: WELL WELLHEAD= �M�EVOY GE3 2N WG 1_0 8 P'RFSSt1RE OA ABOVE 3000 PSIR**WARNNG: 20NOT 06 ACTUATOR= BAKER RWO TBG TALLY DISCREPANCY-WLEG IS 3 FEET KB.ELEV= 60' ABOVE ORIGINAL PKR@ 7892'.**OA CEMENTED BF.B_EV= ? J l FROM 22'TO SURFACE KOP= 5400' ►t• � 1 20' {7"X 7-518"XO,D 6.323" Max Angle= 30"@ 7000' �' Datum MD= N/A Datum TVD= 8800'SS •� 2173' —�9 518"t IM ESSV CEMENTER 1 �� 2178' —7-5/8"X 7"XO,D=6.184" •: 9-5/8"CSG,474,L-80 TCI,D=8.681" H 2187' 2189' —17"CAMCO 06-6 NP,D=6.00" 2200' ---17"X 7-5/8"XO,D=6.184" 13-3/8"CSG,684,K-55&L-80,D=12.415" H 3481' 7-5/8"FC TBG,29.7#,L-80 VAM TOP HC, H 7798' • 7788' —I 7-5/8"X 7"XO,D=6.563" .0459 bpf,D=6.875" I i 7809' H 7"FES R NP,D=5.963" Minimum ID =5.50" @ 7926' 6-518" HES RN NIPPLE 7 7831' H9-5/8"X 7"BKR S-3 PKR,D=6.151 I 7855' —I HES RN NP,ID=5.770" 7"TBG,29#,L-80 TCI,.0371 bpf,D=6.184" H 7877' I-----/ 7877" H 7"FULL MULESHOE WLEG,D=6.184" >< 7892' J--I9-5/8"X 7"BKR SA BL-3 PKR,D=6.0" I 7926' H6-5/8"FES RN NP,D=5.50' 7"TBG,29#,L-80 NSCC,.0371 bpf,D=6.184' 1 7941' _'_______/ 7941' H7"WLEG,D=6.313" TOP OF 7"LNR H 8000' {aMD TT NOT LOGGED 9-5/8"CSG,47#,L-80,D=8.681" — 8308' I---4 PERFORATION SUMMARY I REF LOG:FINAL CNP ON 04/03/90 I ANGLE AT TOP PERE:15"@ 8357' Note:Refer to R-oduction DB for historical perf data SIZE SPF NTEFNAL Opn/Sqz SHOT SQZ I 3-3/8" 4 8357-8403 0 06/02/90 3-3/8" 4 8442-8488 0 06/02/90 3-3/8" 4 8492 -8691 0 06/02/90 I 3-3/8" 4 8697-8720 0 06/02/90 3-3/8" 4 8726-8788 0 06/02/90 3-3/8" 4 8794-8844 0 06/02/90 I 3-3/8" 4 8846-8856 0 06/02/90 lik UNKNOWN H FISFt 2.70"X 7"P.SUB(03/20/06) 1 PBTD H 8860' �V��1�� 7'LNR,29#,L-80 BTC,.0371 bpf,D=6.184" —I 8905' DATE REV BY COMMENTS k DATE REV BY COMMENTS FRUDHOE BAY UMT 04/16/90 ORIGINAL COMPLETION 09/01/07 JIWSV SAFELY NOTE UPDATED WELL-: WGI-08 06/03/99 N7ES LAST WORKOVER 02/11/11 MB/JMD ADDED S-SSVSAFEIY NOTE PERMIT No:'1900490 01/18/06 N4ES RWO AR No: 50-029-22038-00 01/21/06 KSB/TLH DRLG DRAFT CORRECTIONS SEC 11,T11N R14E,963 FN..'&1060'FEL 03/20/06 JDMTL.H FISH LEFT N HOLE 08/19/07 MSS/PJC CMT 22'TO SURFACE(OA) BP Exploration(Alaska) • tioF r� yw\� I y 4THE STATE Alaska Oil and Gas ofA T �ASI�;A Conservation Commission __ fr# 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �FALAS' ' Fax 907.276.7542 www.aogcc.alaska.gov gAttW Jessica Sayers Well Integrity Engineer 190 - D`'f BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-08 Sundry Number: 315-473 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, //„.,7 /D)iii.„44s7CathyFoerster Chair DATED this /. day of August, 2015 Encl. 4[, i 7 STATE OF ALASKA ? ALASKA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPRO..-.LS iAl _', 0 ,1 ?.' 20 AAC 25.280 Vr ,' I 1) P w �7 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 i ier� s dgwn❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 ji, L9 Wet Plug for Redrill 0 Perforate New Pool 0 Repair Well ge a-enter Susp Well 0 Other Well Lolcck Treatrment4-51Z 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 190-049 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612Stratigraphic 0 Service 8. 6. API Number: 50-029-22038-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes 0 No m Will planned perforations require a spacing exception? PBU WGI-08 9 Property Designation(Lease Number): 10. Field/Pools: ADL 0028302 • PRUDHOE BAY,PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8908 ' 8636 ' 8860 8590 8859 Casing Length $12e MD ND Burst Collapse Structural Conductor 78 20"91 5#H-40 41 -119 41 -119 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 904 7"29#L-80 8004-8908 7764-8636 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type' See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 7"Camco A-1 SSSV 2206, 2206 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program RI Exploratory 0 Stratigraphic 0 Development ❑ Service IZI 14.Estimated Date for Commencing Operations: 8/18/15 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ® ' WAG 0 Abandoned ❑ Commission Representative: Op Shutdown 0 GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sayers,Jessica Email Jessica.Sayers@bp.com Printed Name ers,Jessica 0Title Well Integrity Engineer Signature Phone +1 907 564 4281 Date e 13` 15 11 / COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: `�Jl 31 J iii, Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 1 Other: ' Spacing Exception Required? Yes 0 No IT Subsequent Form Required: re - 4 0 4- APPROVED BYTHE Approved by: .fia(e4.7 A�_�.V..� COMMISSIONER COMMISSION Date d 'am( t� v r�8ItoliC , 8/644' ORIGINAL A 4?-1,. :s-- Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate RBDMS.A AUG 1 4 2015 o o 00000000000 LOCO CO CD N N O) N O) N O N N- N- Oo Oo N Oo . O0 - V 4 00) NON NO CO CO OO) CO 00) CO • .1- 0 CO CO - e- CO '- CO e- N CO e C) U) CO 00 O CO CO,CO CO CO N O ti e- CO Cn CO 0) N N • N 0) 0 CO Cr) e- O) A- CO CO A- CO N0 CO A!N CO CO N Cr) N CO CO N N N N N- ; III I II F- O CO CO 0) 0 e- N CO 0 CO 0 e- 0) e- CO N ✓ V CO CO N N C�) N N CO •a) (NJ 0) O N COe— N A- CO 0)U ) CO Tr N CO 0) ATe- N CO CO 0) Cr) N CO CO N N N N N V as 032Qto ^ �- e- N CD O O CO e- O � CO O NrCrCOCA) N0C AT NCO0) C a O Lo cO 0 co Ca = `1J i .iCO • CO ooCO C d cit oco4* -J -J J JJ N N I.0 CO CO 1 ) # O) *k *k Cl) Co CO - N N - N - N CO N (h C� o ti ti U tiin ti N co co _ Nr CO C en Tr Cf O O e- N CC) N OL() 0 Cr) N CO O N CU J W W Q Q CD O cU W w () pu. u_ rtmccZZ'ZZZZ ODDF" F' Z » D » O ci co co 1- 111- 1- I-- 1- d y co L O CO CO CO CO N N- • Ocj (O O4Lei y �_ N N Ccs N N- CO CO CDcococ co co O. O � COCO (OCOO) (0 L Lf) N. O CO LU O • 0. 4 CO 'xiN O CO (CO 0 N .4 LO > CO CO CO CO CO CO CC) W• 0 WLLI Z W H H W g g Y 00 o CaO O W Y Y g L CO CO O 00 CO J J J Q Q W Q' i� C. 000O) N 00 v- O < < Q W G CO (0 (0 (0 (00000 Z Z Z w J 0 O 0 = Z D D 00 1— O 2 00 U w 4.t .or Z 0 Z CCI Q a _ .t. N- N N N- CO CO O L O) O) N O) C 0 M V co f- 1- CO • co Cl co 00 co co CO Co co y L a m 2 0 cn co co cn cn d a. y 0 0 U O LL Q' Q' cccecece o a W W w W W W 0. 0 a, m a m ~- 00000000 0 0) () 0) 0000) ornrnrnrnrnrnrn zLLi ¢ w CC LU` LL N N N CN N N C V 0 Q W J 0 N U W w LL W O CO CO (O a0 (0 (0 (01.0 COO m 0Z' 0 W J J Q d W CL W < Qm0_ CO u ti LL CO 0 = aoaoaoaowaoao Z o 0 0 0 0 0 0 cn 0000000 LL 0_ co 0 LL N [Y LL to m a). ,r_ fin COn d 0: Packers and SSV's Attachment PBU WGI-08 SW Name Type MD ND Depscription WGI-08 SSSV 2206.13 2206.13 7" Camco A-1 SSSV WGI-08 PACKER 7847.98 7618.81 7" Baker S-3 Packer WGI-08 PACKER 7905.02 7671.79 7" Baker SABL-3 Packer bp . 0To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 08-03-15 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: WGI-08 WellLock OA Treatment Objective This program is for treating the annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use the small pneumatic pump to squeeze the WeIlLock into the micro-annulus with high pressure • and low volume. Once pressure fall off dissipates, nitrogen should be flushed across the OA valves to keep WeIlLock from setting up. Well Detail Current Status: Operable-GI Previous Test: 02-21-15 MIT-IA passed to 2310 psi Integrity Issues: Fully cemented OA, OA repressurizes when on-line (all gas) Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Temperature: Maintain 750-80° F throughout the entire job Relevant History: > 06/30/13: AOGCC MIT-IA Passed to 2300 psi > 07/05/15: DSO bled OPA 450-20 psi 1 min fluid > 07/31/15: DSO bled OAP 500-20 psi 1 min fluid Well Program: 1 D Strap TOC and clean annulus between TOC and OA valve; bleed IA. 2 D *** Use pneumatic pump to pump WeIlLock into OA. 3 D Maintain 2,500 psi for two hours by pumping more WeIlLock at signs of pressure fall off. This is to squeeze the WeIlLock into the microannulus. Record pressure and temperature readings on casing every hour. Do not exceed 3,500 psi. • 4 D Shut-in su, ase pump and returns, blow nitrogen path across valves. 5 D Pressure up and leave 500 psi nitrogen cap on well. 6 D Leave crystal gauge on well and take pressure and temperature readings on casing, twice daily. Record in AWGS. 7 D After seven days, put well under-eval to check for OA pressure stability *** Collect approximately one cup sample of WellLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period. 2 of 2 TREE= 6-318"CAMERON A i i O c Y NOTES WELL REQIARESA SSSV. DO NOT WELLHEAD= McEVOY Gf3N2 P JURE OA ABOVE 3000 PSL""WARNNG: 2006 ACTUATOR=_ — BAKER TBG TALLY DISCREPANCY-WLEG IS 3 FEET KB.EZEV- — 60 ABOVE ORIGINAL PIR@ 7892'."`OA CEMENTED F.ELEV=-- — ? ) i1 FROM 22'TO SURFACE KOP= 5400' �. 20217' -8' H--177-_5/X87.-x5/87". (r7-5/8 X 7-518"X7"'XOXO,,DD 6=.6323.184" ' Max Angie= — 30 @ 7000' �1 Datum MD' PYA A 2173' --I 9-5/8"f ESSV CEMENTER Datum TVD= 8800'SS 1 9-5/8"CSG,47#,L-80 TCI,ID=8.681" — 2187' • 1 2189' Hr CAMCO 013-6 NAP,D=6.00" 2200' —+7"X 7-5/8"XO,D=6.184" , 13-3/8"CSG,68#,K-55&L-80,D.12.415' H 3481' 7-5/8"IFC TBG,29.7#,L-80 VAM TOP HC, hi 7798' • 7.798' H 7-5/8'X 7'XO,D=6.563" I.0459 bpf,D=6.875' I I 7809' —7"HES R NP,D=5.963" Minimum ID =5.60" @ 7926' X Ilta_44 7831' H 9-5/8"X r BKR S-3 PKR,D=6.151 6-5/8" HES RN NIPPLE I 7855' H7"FES RN NP,D=5.770" 7"TBG,29#,L-80 TCI, .0371 bpf,ID=6.184" —1 7877' 1---/ 7877' H7"FILL MILESHOE WLEG,D=6.184" 7892' —9-5/8"X r BKR SABL-3 PKR,D=6.0" I 7926' —16-5/8"HES RN NP,D=5.50" r TBG,29#,L-80 NSCC,.0371 bpf,D=6.184" —{ 7941' / 7941' H r WLEG D=6.313" !TOP OF 7"LW? H 8000' —j ELMD TT NOT LOGGED 9-5/8"CSG,47#,L-80,D=8.681" —I 8308' • PERFORATION SUMMARY REF LOG:FNAL CAP ON 04/03/90 ANGLE AT TOP FE RE:15'@ 8357 I Note:Refer to Production DB for historical perf data SIZE ( SPF INTERVAL Opn/Sqz SHOT SOZ I 3-3/8" It 4 8357-8403 0 06/02/90 3-3/8" 4 8442-8488 0 06/02/90 3-3/8" 4 8492 -8691 0 06/02/90 3-38" 4 8697-8720 0 06/02/90 I 3-3/8' 4 8726-8788 0 06/02/90 3-3/8' 4 8794-8844 0 06/02/90 3-3/8" 4 8846-8856 0 06/02/90 I ilk UNKNOWN H FBFt 2.70"X 7"P.SUB(03/20/06) 8311) H 8860' 1---4111141114 111114441111111* 7"LNR,29#,L-80 BTC, .0371 bpf,D=6.184" -1 8906' �� DATE REV BY COMMENTS DATE REV BY COMNE NTS R 1)HOE BAY UW 04/16/90 ORIGINAL COMPLETION 09/01/07 JM/SV SAFETY NOTE UPDTED WELL: WGI-08 06/03/99 N7ES LAST miaow ER 02/11/11 RE/1413 ADCED SSSV SAFtIY NOTE PERK Nb:'1900490 01/18/06 N4ES RWO API No: 50-029-22038-00 01/21/06 KSBITLH DRLG DRAFT CORRECTIONS SEC 11,T11 N,R14E,963 FAL'&1060'FEL 03/20/06 JDNTLH RSH LEFT N HOLE 08/19/07 MSS/PJC CMT 22'TO SURFACE(OA) i I BP Exploration(Alaska) ti OF T� I 1 D- 04°) row D.\\I y/:'sv THE STATE Alaska Oil and Gas ofALASKA Conservation Commission 333 West Seventh Avenue 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1 433 OF ALAS*P Fax: 907 276 7542 www.aogcc.alaska.gov SCANNED APR 2 9 2015 Spencer Morrison Petroleum Engineer n BP Exploration(Alaska), Inc. (q 0 +++07 `� ` P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-08 Sundry Number: 315-241 Dear Mr. Morrison: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, tylikyhje-'"'" Cathy P. oerster Chair DATED this Z day of April, 2015 Encl. • 13 cr1 STATE OF ALASKA APR 2 1. 415 ALASKA OIL AND GAS CONSERVATION COMMISSION /7-S ,¢(2 7/1 g-- APPLICATION FOR SUNDRY APPROVALS .A0GCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool El Repair Well❑ Change Approved Program El Suspend Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Water Wash . 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Exploratory ❑ Development ❑ 190-049-0 • 3.Address: Stratigraphic ❑ Service 0 • 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22038-00-00 • 7 If perforating: 8 Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU WGI-08 ' Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028302 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8908 ' 8636 • 8860 8590 None 8859 Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"91 5#H-40 41.48-119.48 41.38-119 38 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 904 7"29#L-80 8003.66-8908.07 7764.36-8635.67 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths 7"Camco A-1 SSSV 2206 13',2206.03' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 - 14 Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/10/15 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16 Verbal Approval: Date: WINJ ❑ GINJ 0 • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Spencer Morrison Email Spencer.Morrison@BP Corn Printed Name Spencer Morrison Title Petroleum Engineer Signature Phone 564-5773 1-1/114 Date Prepared by Garry Catron 564-4424 �� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 15- 22-{ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Cher: Spacing Exception Required? Yes ❑ No L7 Subsequent Form Required: ,r _ 4 G `T /1 J APPROVED BY Approved by: 9e24 Yk. COMMISSIONER THE COMMISSION Date. 4— z,7_./..c ill-L- 4/643//S Ai- 4,zz./.5— Form 5"Form 10-403 Revised 10/2012 0 RAL } jicfslp is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate VVV 1 III�� /�"1 RBDMS ( APR 2 9 2015 — 4 a//,-- ,-0 O O O O O LO 0 CD O O O CD co V CO CO C() C10 LO CO CO CO CO CO CO = J J J J Y J J J ... J J CD a) Q O CD 0 0 0 0 0 0 0 0 CD 0 (6 t` CO (fl N N LDA .7r O CN-� O) N N p N- N. (-\I c-- LC) I- V V I- I,- 0 112 Fr)) o F...:). O O O o 0 0 0 0 0 (3) ro CO N Ln v (0 CO 0 (0 V a0 00 - CD N '- CO COCIO CO a- CD CO CO LO CO N- CO CO (D CO co a) (6CD a- CD O � N LO O) N- CO -" 0 CO CO (A N CO 0) CO a- a- N O2) V C0 I- (0 '- L() N N a0 M M N- N- N- F- Q 2 CD C)) (}) N- LO ~ a- CO O CD N r- CO 00 a- a- O) CO O � MNNCIOv LO "4- i I (6 (N E O E M cc4 O r N a0 O co Ln LO CO CO - m O ( O O) N Ln O C) CO N I D (NN co O V co CA co ,- co N NI- (f) (n O 0 ' CV CO CO M N- N- N N- N OO J CU Q O v M (O CO LD CO o O N a- CD a- a 0 CO U O 'r co N O CO C) CIO 'f N '- CO LJ N CO I- N- N N O O O CD LO O O CO LO CO CO V 0000 OJ Y O O J J O O = J J OO CO CO C10 CO () 4# Lt *k Jco* J J J J ) V a) (0 CD (O 0) N N O0) 0) 0) zo0) - - N o0 00 N N _ _ N N N (A (A MM Lo Lo c- c- I� L 00 0o V 00 m 00 co — V O c- c- C}) LO (A CO N N- a- T C7 V' LC) N .- LO N Ln J N CO O CO N L() W uJ Q Q a� OCIa WW N U W W O p Ct � u_ Z Z Z Z Z Z Z W W W CC CC CO CO CO CO m m 0 Z Z =;(n U) I- F- I- H F- F- Packers and SSV's Attachment ADL0028302 Well Facility Type MD Top Description TVD Top WGI-08 SSSV 2206 7" Camco A-1 SSSV 2206 WGI-08 PACKER 7848 7" Baker S-3 Packer 7619 WGI-08 PACKER 7905 7" Baker SABL-3 Packer 7672 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15/ General Information Well Name: WGI-08 Well Type: Gas Injection Well API Number: 50-029-22038-00 Well Activity Conventional 4 Classification: Activity Description: Water wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: TREAMENTS Estimated Cost, $K: Other regulatory AWGRS Job Scope: TUBING WASH/PICKLE None requirements? Sundry Form 10-403 Required? Yes — Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Spencer Morrison Contact numbers: (907) 564-5773 (713) 557-281 Well Intervention Engineer: Contact numbers: No Data No Data Lead Engineer: Chris Stone Contact numbers: (907) 564-5518 (907)440-401 Date Created: April 6, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate lnj Rate Gas Injection GOR Gas Lift Rate FTP or Injectic Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut (%) (Mscf/Day) (psi) 4/5/2015 295,369 3,569 Current Status: Operable Flowing Inclination>70°at Depth(ft) Maximum Deviation (Angle and Recent H2S (date,ppm) NA 0 ppm Depth) 300 7,000' MD — Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 3° 8,100' MD Reservoir pressure(date, psig) 3,400 psi Minimum ID and Depth 5.50"Q 7,926 Reservoir Temp, F 130° F Shut-in Wellhead Pressure 2,400 psi Known mech. integrity None, passing MIT-IA and MIT-T problems(specifics) Last downhole operation(date, 6/27/2013 SL pressure test integrity, set plug at 7845, pulled after operation) Most recent TD tag (date,depth, 7/31/2007 8,800' MD 4.5"centralizer toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, WGI-08's last water wash was on 9/6/2002 where we pumped 678 bbls of 150 F FW with .02% F-103 background information, surfactant at a rate of 5 BPM. The water wash was unsuccessful. etc: It has been 13 years since this last water wash and there is likely organic material that has built up in the ' tubing and perforations. i nis sui.....er mere wiii oe an ivui restoration project mat will incivae signiricant gown time ror me r ui wells. I have included the tentative schedule below. To reduce the impact of having the NGI wells shut in for work, water washes are needed on good candidates on AGI and WGI. NGI Restoration schedule: 1.Well lateral line work starts April 15 when we will take 2 NGI wells down at a time for repairs lasting 7-9 days per set. We will start with wells 13/14 and work south until complete with pre-TAR scope. 2. Starting on June 26th we will take down NGI wells 1-12 to support blinding and repairs in the vicinity of FV6302/6203 for 9 days-This is outage one. 3. Following outage one and roughly on July 4th we will restart NGI wells 8-12(13 and 14 were already on line)and wells 1-7 will remain down for approximately 30 days for outage 2. 4. Following completion of outage 2 we will restart wells 1-7 and take down NGI wells 8-14 and begin repairs on the north end of NGI headers/laterals. This is outage 3 and duration is roughly 30 days. 5. Following outage 3 we will need to restart NGI wells 11-14 and take down NGI wells 1-10 to allow for blind removal at FV6302/6203. This is outage 4 and I estimate 2 days for this outage. 6. Finally we then will restart all of the NGI pipelines and wells that were down for blind removal and be back to normal with repairs in place. This is the base schedule and if we find additional corrosion damage the extends our scope of work then we could have some wells off line for longer duration. If the water washes go to plan,we will improve injectivity by dissolving salts and possibly asphaltenes in ., the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Well Intervention Details Suspected Well Problem: Oragnic deposition Specific Intervention or Well Objectives: 1 Increase well injectivity by cleaning the tubing and perforations 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Service Line Activity Step# 1 Pump Water Wash as per attached template 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: Post job POP instructions: Bring back well to injection Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: d 1 .1r g 7 \ ) �'� z } _�_, � - 333 West Seventh Avenue "%'" GovERAOR SLA PARNELT, Anchorage, Alaska 99501-3572 Main: 907.279.1 433 �7 �_ �� pe 107.27;,.7542 Javier Farinez SCP414° JUL 2 2 L014 GPB GDE Lead PE O ©4 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-08 Sundry Number: 314-217 Dear Mr. Farinez: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i);x_,,,,c1--,----- . Cathy Foerster Chair DATED this It'"day of April, 2014. Encl. RECEIVED STATE OF ALASKA APR 0 3 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Water Wash ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 190-049-0 3.Address: Stratigraphic ❑ Service D6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22038-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU WGI-08 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028302 • PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8908 . 8636 - 8860 8590 None 8859 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 39-119 39-119 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 905 7"29#L-80 8000-8905 7761 -8632.88 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(It): See Attachment for Packer Depths 7"Camco A-1 SSSV 2189',2189' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Development ❑ Service U 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ Q • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Javier Farinez Email Javier.Farinez@BP.Com Printed Name Javi- •-z Title GPB BDE Lead PE Signature Phone 564-5043 Date '- / Z.I Iii Prepared by Garry Catron 564-4424 COMMISSION USE ONLY L' Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ?j\"1- IV-1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS MAY 1 0 2014 Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: c _ 4 G// �/ APPROVED BY Approved by: u h.Q-et°1fr--- COMMISSIONER THE COMMISSION Date: 4--/J-4 � S (4101)4 7b7b ' r' Form 10-403 Revised 10/2012 ()Re'tepjjicptlisslit for 12 months from t e date of approval. Submit Form nd Attachments in upli to Vt-F 4/4114- �,J t L ,,/ 0.4,.. a) 0 0 0 0 U 010 0 010 0 0 v ao CO Co CO CO CO ICC) ao CO Co CO CO 0 = J J J J Y J J J J J J N 0.• 0000000000000 CO CO O CN gr) tt CCA... N- O O N C- O X 0 0 0 0 0 0 0 0 0 0 0 0 0 CA N- N- CD N LO CD O) CA CD CD CD 7 AT 00 03 A- O NA- CO CO A- A- A- m e- CO CO CO LD M 1- co co co CO 03 03 a) Cl) CO Co N- MOD CO M 0) T- M m 1.0 O r- O N M CMO U) 0 CO CO CO A 0) A-- • 0) 0) O CO 'Cr CO CO CO A- CO O CO M M M COLO N M A- M I� N N- r- N- N N 03 CN Eos M cooaoao � s- op o) to 00 m 0) CD 0 0 CO v v CO o Co '- v 0 M 0) N- O) O CrO Ac-‘1 N M 0) 0 0 N Co CO M N- N- N CD O ti) Q H 0) N- 0)) 0 Cr co coo s v 03 0 0 U p M M O I� M CO CO N M A- Mo N CO N- N- N N 03 000 u) 0 C 00 OD - J -I CO0 - �1 00 CO J J CO CO CO .11 CO U) CO CO CO 0) N N 0) 0) ) 0)) O Eo N -00 CO N N _ _ N N N N CA O) C) M r r O N- CD a O• O CO - O CD CO 0) 0) a (V CO O M f- N O J N co O M LO N O W W Q Q CT c F- , „ CO 2 QQU0000000 O p r u W W Z Z Z Z Z Z Z Z W W W CC CCm m m m m a m F- I- Z DDDDDDDDD 0 Z Z J fn fn l- F- F- F- F- F- F- Packers and s Attachment ADL0028302 Well Facility Type MD Top Description TVD Top WGI-08 SSSV 2189 7" Camco A-1 SSSV 2189 WGI-08 PACKER _ 7842 7" Baker S-3 Packer 7613 WGI-08 PACKER 7899 7" Baker SABL-3 Packer 7666 TREE.= * 6-3/8"CAMERON S. (NOTES: WELL REQUIRES A SSSV. DO NOT WELLHEAD=McEVOY GEN2R WGI-08 PREbSURWO TBG OA ALLYBOVE DISC3000 REPANCY-WLEGInIS 3 FEET G: 2006 ''r�CTUATOR= BAKER KB.ELEV= 60' ABOVE ORIGINAL PKR @ 7892'.**OA CEMENTED BF.ELEV= ? 1 \I 4, FROM 22'TO SURFACE KOP= 5400' 13-3/8"CSG,68#, —1 74' 1 t Max Angle= 30 @ 7000' 1. •1 20' —17"X 7-5/8"XO,ID 6.323" K-55, ID=12.415" Datum MD= N/A 14 o1 Datum TVD= 8800'SS 1• •: 2173' —9-5/8"HES ESSV CEMENTER 14 o1 .A .1 2178' —17-518"X 7"XO,ID=6.184" 9-5/8"CSG,47#,L-80 TCI!, ID=8.681" — 2186' { 2189' —17"CAMCO DB-6 NIP,ID=6.00" 2200' —7"X 7-5/8"XO,ID=6.184" 13-3/8"CSG,68#,K-55&L-80, ID=12.415" —I 3481' I--, , 7-5/8"TBG,29.7#,L-80 IPC, .0459 bpf, ID=6.875" 779$' I-- i 7798'_J-17-5/8"X 7"XO,ID=6.563" I 7809' —I 7"HES R NIP,ID=5.963" Minimum ID = 5.0" @ 7926' 1 6-5/8" HES RN NIPPLE >ff 7831' 9-5/8"X 7"BKR S-3 PKR, ID=6.151 I - 7855' —17"HES RN NIP,ID=5.770" I 7"TBG,29#,L-80 TCII, .0371 bpf,ID=6.184" 7877' I \_ I 7877' —17"FULL MULESHOE WLEG,ID=6.184" 7892' —9-5/8"X 7"BKR SABL-3 PKR, ID=6.0" I I 7926' —16-5/8"HES RN NIP,ID=5.5" 7"TBG-NSCC,29#,L-80, .0371 bpf, ID=6.184" — 7941' i 7941' H7"WLEG,ID=6.313" TOP OF 7"LNR H 8000' -ELMD TT NOT LOGGED 9-5/8"CSG,47#,L-80,ID=8.681" -I 8308' I--, , PERFORATION SUMMARY I REF LOG:FINAL CNP ON 04/03/90 ANGLE AT TOP PERF: 15 @ 8357' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8357-8403 0 06/02/90 3-3/8" 4 8442-8488 0 06/02/90 3-3/8" 4 8492 -8691 0 06/02/90 3-3/8" 4 8697-8720 0 06/02/90 3-3/8" 4 8726-8788 0 06/02/90 3-3/8" 4 8794-8844 0 06/02/90 3-3/8" 4 8846-8856 0 06/02/90 1111, UNKNOWN!—FISH: 2.70"X 7"P.SUB(03/20/06) PBTD —I 8860' 1-44•4.4..0 7"LNR,29#,L-80, .0371 bpf, ID=6,184" — 8905' 1/111/1111/111 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/16/90 ORIGINAL COMPLETION 03/20/06 JDM/TLH FISH LEFT IN HOLE WELL: WGI-08 06/03/99 LAST WORKOVER 12/04/06 RAC/TLH TREE CORRECTION PERMIT No: 1900490 01/18/06 N4ES RWO 08/07/07 DSM/SV TREE C/O AR No: 50-029-22038-00 01/21/06 KSB/TLH DRLG DRAFT CORRECTIONS 08/19/07 MSS/PJC CMT 22'TO SURFACE(OA) SEC 11,T11N,R14E, 17.44 FEL'& 160.03'FNL 02/12/06 SRB/PAG MILLED PLUG @ 7926 09/01/07 JM/SV SAFETY NOTE UPDATED 02/16/06 TWS/TLH PRN PLUG PULLED 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.3 DBR,LHD,EA201/15/141 �• General Information Well Name: WGI-08 Well Type: Injector API Number: 500292203800 Well Activity Classification: Conventional 4 Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: Job Type: Water Wash Estimated Cost, SM: AWGRS Job Scope: PARAFFIN/ASPHALTENE REMOVAL Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Well Intervention Engineer: Contact numbers: Lead Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Date Created: March 25,2014 Revisions(date,who,what changed): Current Well Status Information Recent WT or Inj Rate&Pressure 3/24/2014 N/A N/A 275.MMscfpd N/A N/A N/A 3,600 psi Current Status: Operable If inoperable or under evaluation, why? N/A Recent H2S (date,ppm) N/A 0 ppm Maximum Deviation(angle and depth) 30° 7,000'MD Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 5"(a 7,926' Reservoir pressure(date,psig) N/A 3,300 psi Reservoir temperature,F 176°F Shut in wellhead pressure 2,420 psi Known mechanical integrity problems(specifics) None Last downhole operation(date,operation) 6/27/2013.Integirty Test Most recent TD tag,(date,depth,toolstring OD) 6/26/2013.TAG STICKY BTM AT 8805'MD W/4.50"CENT,TEL,S.BAILER(-51'of fill,no sample) Comments,well history, Improve infectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used r/ background information,etc: successfully in the past on the NGI/WGI/AGI gas injectors to improve infectivity. Well Intervention Details Suspected Well Problem: Oragnic deposition Specific Intervention or Well Objectives: 1 •Increase well injectevity by cleaning the tubing and perforations 2 •3 Key risks,critical issues: Mitigation plan: 1 • 2 3 Summary Step Service Line Activity 1 F Pump Water Wash as per schedule form 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD' MMSCFD BWPD FTP(psi): Choke setting: Post job POP instructions: Bring back well to injection Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 x '3 FEE' 2, 2 2012 Mr. Tom Maunder t 0 0 `1"9 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 1 JAS G- I Anchorage, Alaska 99501 `� " Subject: Corrosion Inhibitor Treatments of WGI Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from WGI 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, ../t/ c Y— 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) WGI Date: 09/15/11 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD # API # cement pumped cement off date inhibitor sealant date WGI - 1790310 500292036900 Sealed conductor NA NA NA NA NA WGI-02 1790430 500292037900 Sealed conductor NA NA NA NA NA WGI-03 1790490 500292038500 Sealed conductor NA NA NA NA NA WGI-04 1790500 500292038600 Sealed conductor NA NA NA NA NA WGI -05 1900250 500292201500 Dust Cover NA NA NA NA NA WGI -06 1900300 500292202100 0.3 NA 0.3 NA 3.4 9/15/2011 WGI -07 1900400 500292203100 0.3 NA 0.3 NA 3.4 9/15/2011 ---) WG1-08 1900490 500292203800 0.3 NA 0.3 NA 3.4 9/15/2011 WGI-09 2061460 500292332700 1.3 NA 1.3 NA 10.2 9/15/2011 MEMORANDUM TO: Jim Regg ~ a ~, Z ~l7 ~~ G P.I. Supervisor `~`~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 09, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-08 PRUDHOE BAY UNIT WGI-O8 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~' Comm Well Name: PRUDHOE BAY UNIT WGI-08 API Well Number: 50-029-22038-00-00 Inspector Name: John Crisp Insp Num: mitJCr1o0208160931 Permit Number: 190-049-0 Inspection Date: 2/5/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI-08 Type Inj. G 'T D 7603 ~ IA 240 2500 ~ 2520 2520 i P.T.D I9ooa9o TypeTest SPT Test psi f I9oo ~~ OA o ~ 0 0 0 P ~ Interval 4YRTST p~ Tubing ~ 3700 ± 3700 3700 3700 Notes: Injection rate from the gas plant did not change during MIT. Slight pressure increase thermal . ~ ~~L„v:1"~J~~_s~ t~ t~_. ~ Vin' Gam' L U F i' Tuesday, February 09, 2010 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks @alaska.gov; tom.maunder @alaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / WGI pad DATE: 02/05/10 OPERATOR REP: Torin Roschinger AOGCC REP: John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well WGI -03 Type Inj. G TVD 7,184' Tubing 2,560 2,880 2,880 2,880 Interval V P.T.D. 1790490 Type test P Test psi 1796 Casing 780 4,450 4,220 4,160 P/F P Notes: MIT -IA to 4450 psi for 2 -year AA compliance testing OA 0 0 0 0 with tubing loaded. --- Well WGI -08 Type Inj. G TVD 7,603' Tubing 3,700 3,700 3,700 3,700 Interval 4 P.T.D. 1900490 Type test P Test psi 1900.75 Casing 240 2,500 2,500 2,520 P/F P Notes: MIT -IA to 2500 psi for 4 -year compliance testing OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) D APR 201'r MIT Report Form BFL 11/27/07 MIT PBU WGI -03 08 02- 05- 10.xls 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: _ STATE OF ALASKA I AL~ OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS D D D 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic D Stimulate D ''&IìIer E:r Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 190-0490' r;; 6. API Number: 50-029-22038-00-00 9. Well Name and Number: Exploratory Service 59.9 KB WGI-08 . 8. Property Designation: ADL-028302 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool ' Total Depth measured 8908 feet Plugs (measured) None true vertical 8635.77 feet Junk (measured) 8860 Effective Depth measured 8860 feet true vertical 8589.57 feet S.G,~N\\lE(\ ¡¡¡II "f c-í vI.) " I ¿, Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 3452 13-3/8" 68# K-55 29 - 3481 29 - 6481 3450 1950 Production 8280 9-5/8" 47# L-80 28 - 8308 28 - 8057.12 6870 4760 Liner 860 7" 29# L-80 8000 - 8860 7761 - 8589.57 8160 7020 Perforation depth: Measured depth: 8357 - 8403 8794 - 8844 True Vertical depth: 8104.56 - 8149.07 8526.06 - 8574.18 8442 - 8488 8846 - 8856 8186.78 - 8231.2 8576.1 - 8585.72 8492 - 8691 8697 - 8720 8726 - 8788 8235.06 - 8426.88 8432.66 - 8454.81 8460.59 - 8520.28 Tubing: (size, grade, and measured depth) 7-5/8" 29.7#n" 29# 7"29# L-80 L-80 20 - 7877 7892 - 7941 Packers and SSSV (type and measured depth) 7" Baker S-3 Packer 7" Baker S-3 Packer 7831 7892 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft MAY 2 4 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 Tubing pressure o o x 15. Well Class after proposed work: Exploratory Development Service r;; 16. Well Status after proposed work: Oil Di Gas D WAG GINJ R1 ¡ WINJ WDSPL D Contact Sharmaine Vestal Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Data Mgmt Engr Signatu Phone 564-4424 Date 5/18/2006 Form 10-404 Revised 04/2004 1"''''''''101',1\ , ~ ~ .z.tf.D{,. Submit Original Only .. e WGI-08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY e ACTIVITYDATE I SUMMARY 2/4/2006 CTU #8, Pull TTP; ... Cont' from WSR 02/03/2006... MU BHA #1: iCoil tools (pressure / temp / eel), BKR MHA with hydraulic centralizer and 2" JSN. iCoil tools failed, no eel for depth control. RIH and tag plug. Jet on plug for 30 min pumping 73 bbls XS 1% KCL, did not make any hole. POOH. MU BHA #2: iCoil tools (pressure / temp / eel)" BKR MHA with hrdraulic centralizer and venturi junk basket. RIH and ...Set down @ 7910' Venturi on Plug and recip pipe. several cyeles. Run jewlery log from 7911 to 7650. POH w/ Venturi JB. ... Job in progress - Cont' on WSR 02/05/2006... 2/5/2006 CTU #8, Pull TTP; ... Cont' from WSR 02/04/2006 ... POH w/ Baker 3.13" Venturi JB.. NOTHING in Venturi JB.. LD Collar locator and disconnect I-Coil. MU Baker BHA. BHA= DBV's 3.13", Bowen U/D jars 3.13", Disco 3.38" (5/8" ball), Circ Sub 3.15" (1/2" ball) & 5" GS Spear. Attempt to latch plug but was unsuccessful despite many attempts, including 5 down jar licks. POOH. LD tools and inspect GS spear; found several marks on top of spear. RBIH and turn well over to clean fluids for video log. RIH with 2" DJN, tag plug and proceed to pump 290 bbls fresh water with L-64 stabilizer. POOH and freeze protect well with 100 bbls 60/40 Meth. *** Job Incomplete *** 2/6/2006 T/I/O - 0/340/0 - Perform Video log to view obstruction on top of PRN plug set at 7926'. Final WHP's T/I/O - 0/340/0. 2/7/2006 *** WELL SI ON ARRIVAL *** RIG UP SURFACE EQUIP & PREP FOR PT *** JOB IN PROGRESS/ CONT ON 02-08-06 WSR *** 2/8/2006 *** CONT FROM 02-07-06 WSR *** RAN 2.50 TAPERED LIB ON BARBELL SETUP W/ DECENT, LIB INCONCLUSIVE, ONE MARK ON SIDE OF LIB @ 3:00, RAN 4.50 CENT & 5' X 3" PUMP BAILER SET @ 7904' WLM ,SMALL SAMPLE ?, RAN 3.25 G-RING ON BARBELL SETUP SET TO 7904' WLM, RAN 3.6 HYDRO STATIC BAILER TO 7904' WLM, NO SAMPLE. RDMO *** JOB INCOMPLETE, DSO NOTIFIED, WELL SI *** 2/10/2006 CTU #5, FCO/Mill; MIRU DS CTU #5. Standby to swap out BOP's. Cont' on WSR 2/11/06 ... 2/11/2006 CTU #5, FCO/Mill; Cont' from Weather Standby WSR 2/10/06... NU 7- 1/16" BOP stack. Perform full BOP test - passed. RIH with Baker 4.750" venturi / junk basket. Continued on WSR 2/12/06... 2/12/2006 CTU #5, FCO/Mill; Continued from WSR 2/11/06... Continue RIH with venturi/junk basket. Recovered 1/4 to 1/2 cup of pieces of control line and 3 small pieces of stainless steel band. Prepare to run mill and motor. RIH with 3.06" round nose junk mill and stabilized motor. Milled through prong housing in bottom of plug body. Well went on vac." POOH with mill and motor assy. Inspect tools. Medium wear on mill. Found wear on XO 1.39' above end of mill. Did not see wear on stabilizer brass 2.58' above end of mill. This is a positive indication that the mill exited the bottom of the plug but may also indicate that the fishing neck is no longer intact. Put well on gas ..r injection, well is taking gas and warming up rapidly. *** Job Complete *** FLUIDS PUMPED BBLS 1084 Meth 287 1 % KCL 607 2% KCL 1 Diesel 1979 TOTAL MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'Kê11 ,((kID~ DATE: Wednesday, February 22, 2006 FROM: Chuck Scheve Petroleum Inspector SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-08 PRUDHOE BAY UNIT WGI-08 Src: Inspector /o~q \C\O Reviewed By: P.I. Suprv "5812- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT WGI-08 API Well Number 50-029-22038-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060220063630 Permit Number: 190-049-0 Inspection Date: 2/19/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i WGJ-08 -,- TVD I I , i I i IType Inj. I G i 7603 IA ! 650 2500 2480 2480 I I P.T. I 1900490 ITypeTest I SPT i Test psi I 1900.75 lOA 0 0 0 1 0 I I ì I Interval WRKOVR P/F P Tubing i 3800 3800 3800 , 3800 i ! I Notes The pretest pressures were observed and found stable. j!(~/~M "I;;':' ""%i" ~v '"'.' o,;~'.;'" Wednesday, February 22, 2006 Page 1 of 1 t~=¡~'~~~·-11j t:=Ù Schlumberger ~J:"B. r, 'J -_?fl~_- . iì 1d - t.. ~ ~~V~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .-.. .....,n ;~. ·...-UH;: fH~~!al, A.ncherage Well Job # Log Description Date BL 13-31A .Q 05 - iloD 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 DS 18-03B ;J05 ~Or'.(~ 11057071 SBHP SURVEY 12102/05 1 NK-43 rQ~/-ðc) I 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A /C¡C¡ - 057 11183463 LEAK DETECTION LOG 01/28/06 1 DS 06-22A Iq?y~c5 7 N/A SENSAlMEM LDL 01/28/06 1 DS 11-26 Ißú:'~ 134- 11183462 INJECTION PROFILE 01/28/06 1 P1-09 J 91.t·· /51- 11098756 PROD PROFILE W/DEFT & GHOST 01/30/06 1 L5-05 Jf:.7-CCcC¡· 11058541 RST 11/11/05 1 Z-29 i e:q - C(" ç- 11051081 RST 08/10/05 1 L5-09 f C¡O -I-V~ 11090725 RST 11/11/05 1 15-44 ,qf..t - I (() 11194155 RST 01/15/06 1 C-20B -¥O{-I f 4- 11075913 MCNL 08/29/05 1 02-14A .QO~ ~ 1~5 11075901 MCNL 07/29/05 1 Z-21 A ,go I-jot 11076449 RST 06/30/05 1 F-27 A d05-1é(4- 10928641 MCNL 09/01/05 1 MPH-15 -QC r¿; -. /5 '1 11076486 USIT 12/15/05 13-31 A -Q05-/IßÖ 11133211 SCMT 12/23/05 WGI-04 J7CJ-oSD 11183461 USIT 01/26/06 WGI-04 nq -C'.SL) 11211566 USIT 02/03/06 WGI-08 1'10 - 044 10987559 USIT 01/02/06 WGI-08 ;'10 - c4Q 11058259 US IT 01/12/06 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 '" '" On" l~l)."i\.iMt:r' Y:-!:f')ü- ,2<.~ (' Z db ~~(i1J'i'J~~~~:- ~ k= = Date Delivered: n I -... ---:;} ( O· . _~/ r:J ¡/ . c. 02/09/06 NO. 3677 \~ ....ol{C{ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD ~ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ::~e:e~y t;cD1J(j ) ... STATE OF ALASKA A ALASKAWL AND GAS CONSERVATION C~ISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS· ~j. ...... FEB 1 7 2006 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend 181 Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver Alask~Gas Cons. o Other Anchorage o Re-Enter Suspended Well o Time Extension , sìön 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 5. Permit 0 Dr II Number: 190-049 6. API Number: 50-029-22038-00-00 99519-6612 59.9' 9. Well Name and Number: PBU WGI-oS ADL 028302 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. Property Designation: 11. Present well condition summary Total depth: measured 8907 feet true vertical 8635 feet Plugs (measured) None Effective depth: measured 8860 feet Junk (measured) None true vertical 8590 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3481' 13-3/8" 3481' 3481' .. 3450 1950 Intermediate 8308' 9-5/8" 8308' 8057' 6870 4760 Production Liner 905' 7" 8000' - 8905' 7761' - 8633' 8160 7020 c, c' t (:, Perforation Depth MD (ft): Perforation Depth TVD (ft): 8357' - 8856' 8105' - 8586' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7",26# x 7-5/8",29.7# & 7", 29# 9-5/8" x 7" Baker 'SABL-3' packer; 9-517" x 7" Baker 'S-3' packer L-80 7877' 7892' - 7941' 7892'; 7831' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft f EB ;ï } 2006 Treatment description including volumes used and final pressure: Cut and pulled 9-5/8" casing from surface to 2187'. Run new 9-5/8" casing and cement through ESSV Cementer at 2173'. Pumped 160 BBls Arcticset I, 15.7 ppg. Oil-Bbl Re resentative Dail Gas-Mcf Water-Bbl Tubin Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 17. I hereby certl Contact Printed Name Terrie Hubble correct to the 15. Well Class after proposed work: o Exploratory 0 Development 181 Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG 181 GINJ 0 WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: 305-274 o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Title Technical Assistant Signature Form 10-404 Revised 04/2004 Phone o;¿~ Date 17 D Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only Well: Field: API: Permit: e e 12/27/05 NIA 01/18/06 Nabors 4ES 11/23/05 DRIFTED W/5.85 G-RING TO TOP OF TIP AT 7900' SLM. DUMPED BAIL SLUGGITS, TOTAL OF 5 EA, 50 LB BAGS OF SLUGGITS DUMPED, FINAL TAG AT7890' WLM. SECURE WELL. WGI-08 Prudhoe Bay Unit 50-029-22038-00-00 190-049 1 Sundry: 305-274 Accept: Spud: Release: Rig: 12/18/05 TAGGED PLUG AT 7912'. SHOT LARGE TUBING PUNCH HOLES IN FIRST FULL JOINT ABOVE THE PACKER. INTERVAL FROM 7860'-7862' (TOP SHOT 14' BELOW TOP OF JOINT) REFERENCE TUBING TALLY. JOB COMPLETE. PRE-RIG WORK 12/19/05 TUBING PUNCH 7" CASING FROM 7818' -7823' WITH 5' OF 4 SPF LARGE CHARGES (PRE RWO) GOOD INDICATION OF FIRE. Page 1 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: WGI-08 Common Well Name: WGI-08 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES . ..~~~.=____I_ From - To I Hours L Task 12/27/2005 1/18/2006 Spud Date: 4/3/1990 End: 1/18/2006 Start: Rig Release: Rig Number: i Code I NPT ¡ Phase Begin moving Rig and Modules from MPF-Pad to WGI-Pad in GPB. Continue with Rig move to WGI-08. Rig and Modules arrive on WGI Drill-Site at Midnight. Lay Herculite and Mats. Spot Sub Base over Well. Spot Pits, Pipe Shed, and Camp. Raise and Scope Derrick. Take on 120 deg Sea Water in Pits. Accept Rig at 04:00. Spot Tiger Tank. Lay Lines. Test Lines at 1000/3,500 psi. Good. Pick-up Lubricator. Pull BPV. Lay down same. Tubing pressure 30 psi. Circulate Well with 120 deg Sea Water at 3.0 bpm/1150 psi. (Load and Tally 3 1/2" Drill Pipe in Pipe Shed). Monitor Well dead. Blow down Lines. Set and test TWC to 4,000 psi. Blow down Lines. Bleed tubing void. N/D X-mas tree. N/U BOPE. Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 4000 psi. Had 1 failure: lower kelly valve. re-placed valve. BOP test witnessing waived by John Crisp w/ AOGCC. R/D & blow down test equip & lines. Drain BOP stack. P/U lubricator & pull TWC. UD lubricator & TWC. Monitor well, Dead. P/U, tally & M/U BHA #1 as follows: 5 1/2" cutter dressed w/8" knives, Fixed Blade Stabilizer & 9 ea 4 3/4' DCs. TL = 286.68'. R/u tools to P/U & RIH w/3 1/2" DP. P/U 31/2" DP 1x1 & RIH w/ BHA #1. Tagged up on SSSV @ 2216'. POOH, stand back DP & UD Cutter & stabilizer. Continue to single in with Drill Pipe from Pipe Shed. While discussing a plan forward with Anch Eng. TOH and stand back Drill Pipe (42 Stds). Make-up BHA #1 as follows: 5 1/2" Baker Multi-String cutter w/8" Blades. TIH with BHA #1 and 3 1/2" Drill Pipe from Derrick. Continue to TIH with singles from Pipe Shed with a total of 248 Jts. Pick-up Kelly. Establish parameters as follows: PUW =117K, SOW =115K. 300 amps, 31/2 bpm/600 psi. DECOMP Made two attempts to cut 7 5/8" Tubing at 7,853'. First attempt at 3 1/2 bpm for 35 minutes. Saw no indications thata cut was made. Second attempt was made at 41/2 bpm/900 psi. for 45 minutes. Again no indication of a cut. Disscuss plan forward with Anch Eng. POOH w/ BHA #1 & standback DP. Break out & UD BHA #1. Inspect cutter; No broken cutters, 1 /2" of knife wear on individual cutters. 1 cutter had good showing of a shoulder track indicating full extension. M/U landing jt into hanger 8 3/4 turns. BOLDS. Pull on completion w/ 225K. Completion bumped free & weight dropped to +/- 220K. Pulled up approx 6' . Cut is good. weight running 220K. Slack off & rei and completion. RILDS. DECOMP Set TWC w/ T-bar. Test TWC to 1000 psi, Ok. 12/26/2005 06:00 - 00:00 18.00 MOB P PRE 12/27/2005 00:00 - 06:00 6.00 MOB P PRE 06:00 - 00:00 18.00 MOB P PRE 12/28/2005 00:00 - 02:00 2.00 RIGU P PRE 02:00 - 04:00 2.00 RIGU P PRE 04:00 - 05:00 1.00 RIGU P DECOMP 05:00 - 07:00 2.00 KILL P DECOMP 07:00 - 11 :00 4.00 KILL P DECOMP 11 :00 - 11 :30 0.50 KILL P DECOMP 11 :30 - 13:00 1.50 WHSUR P DECOMP 13:00 - 14:30 1.50 WHSUR P DECOMP 14:30 - 17:00 2.50 BOPSU P DECOMP 17:00 - 23:00 6.00 BOPSU P DECOMP 23:00 - 00:00 1.00 WHSUR P DECOMP 12/29/2005 00:00 - 01 :30 1.50 PULL P DECOMP 01 :30 - 04:00 2.50 PULL P DECOMP 04:00 - 08:30 4.50 PULL P DECOMP 08:30 - 10:00 1.50 PULL P DECOMP 10:00 - 10:30 0.50 PULL P DECOMP 10:30 - 14:00 3.50 PULL P DECOMP 14:00 - 15:30 1.50 PULL P 15:30 - 19:00 3.50 PULL P DECOMP 19:00 - 19:30 0.50 PULL P DECOMP 19:30 - 20:30 1.00 PULL P DECOMP 20:30 - 21 :00 0.50 PULL P Description of Operations ....- ...... -.-. Printed: 1/23/2006 1 :06:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To ---.------ ..... - ..-----.--.--.- 12/29/2005 21 :00 - 23:00 23:00 - 00:00 12/30/2005 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:30 02:30 - 06:00 06:00 - 06:30 06:30 - 09:30 09:30 - 10:00 10:00 - 16:30 16:30 - 17:30 17:30 - 18:00 Page 2 of13 BP EXPLORATION Operations Summary Report Change out rams for 7 5/8" casing. test as follows: LP 250 psi, Hp 4000 psi. Charted same. R/U handling equip to pull & UD 7 5/8" tubing. Wait on DSM to pull TWC. Con't to R/U handling equip for 7 5/8" tubing. Wait on DSM to pull TWC. RlU lubricator & pull TWC. UD same. M/U landing jt into hanger. BOLDS. Pull hanger to floor. P/U Wt 212-220K. LID & break out hanger, XOs & landing jt. R/U spooling unit & connect SS control lines to unit. POOH & UD 7 5/8" completion string. Number & install thread protectors on all jts. Spool up SSSV control line. Lub Rig. Inspect Derrick. Finish laying down 7 5/8" Completion Tubing and spool Control Lines. Had to work Tubing to make progress because of SS Bands lost in hole. Also had trouble working through Wellhead. Left 26 SS Bands and -40' of Control Line in the Hole. Lay down SSSV Assembly. DECOMP Rig-down SWS/Camco Spooling Unit. DECOMP Continue to Single down remaining 7 5/8" Completion Tubing to cut. Recovered 191 Joints of 7 5/8", 29.7Ib/ft, L-80, ST-L IPC Flush Joint Tubing. SSSV Assembly, and a 15.60' Cut-off Stub. Cut is good. Depth of Cut was 7,853' 4eskbl7,860' elmd. Note: -30 Joints on bottom of String had a light coating of Scale on the outside. SWS Tubing Punch Holes at 7,818' -7,823' just barely penetrated the Tubing. The Tubing Punch holes from 7,860' - 7,863' did not penetrate. DECOMP Clear & clean rig floor. RID 7 5/8" tubing handling tools. DECOMP Have bird nested control line & SS bands lodged in BOP stack. P/U wireline spear & 1 jt of 31/2" DP. RIH & fish out bird nested SS control lines. Made 2 runs & recovered 4 SS bands & estimated 15-20' of control line. Noticed some small pieces of control line falling down hole when pulling thru stack. UD spear & DP. Set test plug. Change out rams in BOP from 75/8" to 2 7/8" x 5" Variable Rams. Had to replace snap ring in door of BOP. Function test same. Test variable bore rams, LP 250 psi, HP 4000 psi. Charted test. Tested Ok. RID test equip. UD test jt. P/U running tool & pull test plug. Set Wear bushing & UD running tool. P/U & M/U BHA #2 as follows: 77/8" Rev. Circ. junk Basket, 2 Boot baskets, Bit Sub, Bumper Sub, Jars, 9 * 4 3/4" DCs, Accelerator. TL 325.18' RIH wI BHA #2 on 31/2" DP. Occasionally appear to be pushing some junk ahead of shoe. Con't to RIH wI BHA #2. RIH wI 27 stands. Problem wI drawworks brakes. Install TIW. secure well. Coolant pump on Dyna-matic brake burned up. Replace pump motor. Con't to RIH wI BHA #2 on 3 1/2" DP. Lub Rig. Inspect Derrick. Finish TIH with BHA #2 and 31/2" Drill Pipe to 7,815'. Pick-up 2.00 BOPSU P DECOMP 1.00 PULL P DECOMP 0.50 PULL P DECOMP 0.50 WHSUR P DECOMP 1.50 PULL P DECOMP 3.50 PULL P DECOMP 0.50 PULL P DECOMP 3.00 PULL P DECOMP 0.50 PULL P 6.50 PULL P 1.00 PULL P 0.50 PULL P 18:00 - 20:00 2.00 BOPSU P DECOMP 20:00 - 21 :30 1.50 BOPSU P DECOMP 21 :30 - 22:00 0.50 WHSUR P DECOMP 22:00 - 23:30 1 .50 CLEAN P DECOMP 23:30 - 00:00 0.50 CLEAN P DECOMP 12/31/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP 01 :00 - 05:00 4.00 CLEAN N RREP DECOMP 05:00 - 06:00 1.00 CLEAN P DECOMP 06:00 - 06:30 0.50 CLEAN P DECOMP 06:30 - 07:30 1.00 CLEAN P DECOMP WGI-08 WGI-08 WORKOVER Start: 12/27/2005 NABORS ALASKA DRILLING I Rig Release: 111812006 NABORS 4ES Rig Number: Hours I Task I Code I NPT ¡Phase .. on_ _~_.------L _... . Spud Date: 4/311990 End: 1/18/2006 Description of Operations Printed: 1/23/2006 1 :06:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I Date I From - To .__.... n.__.___.____._.__ __ 12/31/2005 06:30 - 07:30 07:30 - 08:00 08:00 - 08:30 08:30 - 11 :30 11 :30 - 12:00 Page 3 of 13 BP EXPLORATION Operations Summary Report DECOMP Kelly. DECOMP Bring Pump on line at 5112 bpm/1875 psi. Wash and rotate down to hard bottom at 7,852'. Short trip Kelly three time. Tag hard bottom at same place each time. Did a final short trip with Pump off and no rotation. Tag at same place. DECOMP Set back Kelly. DECOMP TOH with 31/2" Drill Pipe and BHA #2. DECOMP Lay down Reverse Junk Basket. Recovered 1 Band and 2 dozen pieces-2"-8" of Control Line. Lay down Boot Baskets. Recovered several small pieces of Band and several 1" -2" pieces of Control Line. Also recovered -3 qts of scale, grit, and metal fines. Second Boot Basket was empty. Clear and Clean Floor. Bring BHA #3 to Floor. Make-up BHA #3 as follows: Bull Nose, ITCO Spear w/6.767" Nom catch Grapple, XO, Stop Sub, XO, XO, Bumper Sub, Oil Jar, 9 ea 4 3/4" Drill Collars, Accelerator. TIH with BHA #3 and Drill Pipe. Pick-up Kelly. PUW = 135K. SOW = 121K. Tagged top of Tubing Stump at 7,852'. Plant Spear with no problems. Jar K-Anchor 6 times at 40K over String weight. Rotate K-Anchor with 25K over String weight. Rotated 9 turns and K-Anchor released. Now have normal string weight and free rotation. DECOMP POOH wI BHA # 3. No recovery... UD spear. DECOMP Clear & clean rig floor. Drill out brass shear pin in spear. Re-dress spear wI new grapple. DECOMP M/U BHA #4. Bull nosed Spear wI 6.767" nom. grapple, X-Over, Stop Sub, X-Over, X-Over, Bumper Sub, Jars, 9 * 4 3/4" DCs, Accelerator. TL 320.41'. RIH wI same. WGI-08 WGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours Task I Code NPT· Phase 1.00 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 3.00 CLEAN P 0.50 CLEAN P 12:00 - 13:00 1.00 CLEAN P DECOMP 13:00 - 13:30 0.50 CLEAN P DECOMP 13:30 - 16:00 2.50 CLEAN P DECOMP 16:00 - 16:30 0.50 CLEAN P DECOMP 16:30 - 20:30 20:30 - 21 :30 21 :30 - 22:30 22:30 - 23:30 23:30 - 00:00 1/1/2006 00:00 - 02:00 02:00 - 04:30 4.00 CLEAN P 1.00 CLEAN P 1.00 CLEAN P Start: Rig Release: Rig Number: Spud Date: 4/3/1990 End: 1/18/2006 12/27/2005 1/18/2006 Description of Operations - ....__...__........_u. .., .... .-.--... ..__.... ___._.____._.._u____.. DECOMP Cut & slip 84' of drilling line. DECOMP Con't to RIH wI BHA #4 on 31/2" DP. DECOMP Con't to RIH wI BHA # 4. Ran 79 stands. DECOMP P/U single jt & kelly. RIH & establish fishing parameters. P/U 125K, SIO 120K, Rot 123K, 90 amps rot. Break circulation. 3 BPM @ 280 psi. RIH & tag fish @ 7852'. Swallow 7' to 7859' (Stop Sub). P/U & jar on fish wI 50K over pull. jarred 6 times. P/U w/25k over pull & rotate 14 turns. lost torq. Attempt to verify fish on by relatching. Repeat P/U & rotation. Same torq. Grapple appears to be spinning. Repeat increasing P/U wt to 45K over pull 3 additional times to Max allowable torq of 10K. Final time tagged 2' high & apeared to have some drag off bottom. Set Back kelly & UD single. Start to POOH with 31/2" Drill Pipe and BHA #4. Lub Rig. Inspect Derrick. Finish POOH with 31/2" Drill Pipe and BHA #4. No recovery. Lay down Spear minus the 6.676" Grapple. Spear has marks and gouges where junk got behind the Grapple causing it to beak. Clear and clean Floor. Prep for the next BHA. Discuss plan forward with Anch Eng. Make-up BHA #5 as follows: 8.500" Reversing Junk Basket, 2 ea Boot Baskets, Bit Sub, XO, Bumper Sub, Oil Jar, XO, XO, 9 ea 4 3/4" Drill Collars. 1.00 CLEAN P 0.50 CLEAN P 2.00 CLEAN P 2.50 CLEAN P 04:30 - 06:00 1.50 CLEAN P DECOMP 06:00 - 06:30 0.50 CLEAN P DECOMP 06:30 - 08:00 1.50 CLEAN P DECOMP 08:00 - 08:30 0.50 CLEAN P DECOMP 08:30 - 09:00 0.50 CLEAN P DECOMP 09:00 - 09:30 0.50 CLEAN P DECOMP Printed: 1/23/2006 1 :06:04 PM Page 4 of 13 BP EXPLORATION Operations Summary Report DECOMP TIH with BHA #5 and 3 1/2" Drill Pipe. Pick-up Kelly. DECOMP Bring Pump on line at 5.0 bpm/1600 psi. Wash and rotate down to top of 7 5/8" Tubing Stump at 7,852'. Short-trip Kelly three times and tagged at the same place each time. Dry tag at the same place. DECOMP Set back Kelly. DECOMP POOH with 31/2" Drill Pipe and BHA #5. No recovery. However, the 9 5/8" Casing has beed drifted "clean" and any junk that was in the Casing has been pushed down into the Tubing Stump. Break out & UD BHA #5. Clear & Clean rig floor. M/U BHA # 6 as follows: 53/4" RCJB, X-Over, 2 Boot Baskets, Bit Sub, Bumper Sub, Jars, 9 * 4 3/4" DCs, Accelerator. TL = 238.17'. RIH wI BHA #6 on 31/2" DP. 79 stands + 1 single. P/U kelly Break circulation. 5 BPM @ 1600 psi. Tag top of cut @ 7852'. Rotate 50 RPMs & work reverse circulating junk basket down thru cut of tbg & pup jt to 7879' DPM. Tagged up on 7 5/8" x 7" X-Over. P/U Wt = 125K, SIO Wt = 120K, Rot Wt = 123K. Set back kelly & BID lines. POOH wI BHA #6 on 31/2" DP. POOH wI BHA #6 on 3 1/2" DP. Break out & LID BHA #6. Empty boot baskets, v. small amt of scale. RCJG, 2 complete slip segments, 1 1/2" square pc of slip. & 1 - 6" pc of control line. Clear & clean rig floor. M/U BHA #7 as follows: 4 1/2' Bull Nose, 75/8" type B Spear, Spear Extension, X-over, Stop Sub, X-over, X-Over, Bumper Sub, Jars, 9 * 4 3/4" Drill Collars, accelerator. TL = 324.48'. RIH wI BHA #7 on 3 1/2" DP. Lub Rig. Inspect Derrick. Finish TIH with BHA #7 and 3 1/2" Drill Pipe. Pick-up Kelly. PUW = 125K. SOW = 121 K. Tag top of 7 5/8" Tubing Stump at 7,852' Plant Spear. Jar 10 times then rotate 16 -18 turns at surface = -11- 12 turns at bottom. Did this for 10 cycles. Final cycle we were firing the Jars at 250K (125K over). Released K-Anchor. with 173/4" turns on surface. Now rotating free. Looks good! POOH with 3 1/2" Drill Pipe and BHA #7. BHA at surface. Fish recovered. Lay down BHA #7. Lay down Fish complete as follows: 7 5/8" tubing Stump (25.60'), 75/8" Pup Joint, 75/8" x 7" XO, K-Anchor. K-Anchor packed full! of SS Bands and Control Line. Pull Wear Bushing. Make-up BHA #8 as follows: 8 1/2" Bit, 9 5/8" Casing Scraper, Bit Sub, Bumper Jar, Oil Jar, 9 ea 4 3/4" Drill Collars. RIH wI BHA #8 & scrape casing tagged pkr & 7892'. Reverse circulate & pump 40 bbls Hi-Vis sweep. 5 BPM @ 1170 psi. Very small amount of scale & black silt in returns. POOH wI BHA c#8 & stand back 31/2" DP. Break out & UD BHA #8. Clear & clean rig floor. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-08 WGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date I From - To Hours, Task ! Code NPT Phase .----........... 1/1/2006 09:30 - 12:00 12:00 - 12:30 2.50 CLEAN P 0.50 CLEAN P 12:30 - 13:00 13:00 - 15:30 0.50 CLEAN P 2.50 CLEAN P 15:30 - 16:00 0.50 CLEAN P DECOMP 16:00 - 17:00 1.00 CLEAN P DECOMP 17:00 - 18:00 1.00 CLEAN P DECOMP 18:00 - 20:30 2.50 CLEAN P DECOMP 20:30 - 21 :30 1.00 CLEAN P DECOMP 21 :30 - 00:00 2.50 CLEAN P DECOMP 1/212006 00:00 - 01 :00 1.00 CLEAN P DECOMP 01 :00 - 02:00 1.00 CLEAN P DECOMP 02:00 - 03:00 1.00 CLEAN P DECOMP 03:00 - 03:30 0.50 FISH P DECOMP 03:30 - 06:00 2.50 FISH P DECOMP 06:00 - 06:30 0.50 FISH P DECOMP 06:30 - 07:30 1.00 FISH P DECOMP 07:30 - 08:00 0.50 FISH P DECOMP 08:00 - 09:00 1.00 FISH P DECOMP 09:00 - 12:00 3.00 FISH P DECOMP 12:00 - 12:30 0.50 FISH P DECOMP 12:30 - 14:00 1.50 FISH P DECOMP 14:00 - 14:30 0.50 CLEAN P DECOMP 14:30 - 16:00 1.50 CLEAN P DECOMP 16:00 - 19:30 3.50 CLEAN P DECOMP 19:30 - 22:30 3.00 CLEAN P DECOMP 22:30 - 23:30 1.00 CLEAN P DECOMP 23:30 - 00:00 0.50 CLEAN P DECOMP Start: Rig Release: Rig Number: 12/27/2005 1/18/2006 Spud Date: 4/3/1990 End: 1/18/2006 Description of Operations ..- -- ...- ---- ---.--.--..-- __n.._____u____.___ Printed: 1/23/2006 1 :06:04 PM BP EXPLORATION Operations Summary Report Page 5 of 13 WGI-08 WGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Fro~_- To I ~~urs J_~ask 00:00 - 04:30 4.50 CLEAN 04:30 - 06:00 1.50 CLEAN 06:00 - 07:30 1.50 CLEAN 07:30 - 08:30 1.00 CLEAN 08:30 - 10:00 1.50 EV AL 10:00-11:00 1.00 EVAL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date -- ..-.-.- 1/3/2006 11 :00 - 12:30 1.50 EVAL 12:30 - 14:30 2.00 EVAL 14:30 - 17:00 2.50 EVAL 17:00 - 20:00 3.00 EVAL Spud Date: 4/3/1990 End: 1/18/2006 Start: 12/27/2005 Rig Release: 1/18/2006 Rig Number: I Code L~PT ; ~hase L . _______ ..?=~~riPti~_n_ of OP~~~_~~_~~ P DECOMP R/U shooting flange & R/U E-line equip. M/U logging tools. P DECOMP RIH & Log USIT. P DECOMP PJSM. RID Eline. P DECOMP PJSM. Install air boot & flow riser. P DECOMP PJSM. M/U Halliburton RTTS & set @ 2250'. P DECOMP PJSM. Test casing f/2250' -7892' @ 2500 psi 115 minutes, OK. Test @ 4000 psi 130 minutes, charted, OK. Bleed pressure. DECOMP PJSM. POOH & UD RTTS. DECOMP PJSM. M/U Halliburton Ret Bridge Plug on (3) stands DCs & (44) stands DP. & set @ 4460' DPM. (4460 middle of rubbers, top of retrieving head @ 4455') DECOMP PJSM. Dump 30 sacks, (1500#),20/40 river sand on top of Bridge Plug @ 4460'. DECOMP Swap hole over to 9.8 ppg heated NaCL brine taking returns to tiger tank @ 5 bpm @ 600 psi. PT RBP to 1000 psi to ensure competent barrier. Had some sand in flowline from displacement. RIH & verify sd top. Tag sand @ 4429'. DECOMP Circulate well with heated 9.8 ppg NaCL brine to bring well in balance. Last truckload of brine was 9.7 ppg heavy. DECOMP POH with setting tools. UD setting tools. DECOMP Clear & clean rig floor. R/U tools & equip to test BOPE. Set test Plug. DECOMP Test BOPE to 250/4000 psi. AOGCC notified prior to test and witness of test waived by Jeff Jones. DECOMP PJSM. Stand back kelly, BOLD.s, pull test plug. INTERV PJSM. Pick up Multi string cutter to cut 9 5/8" x 47# casing, complete w/8 7/16" stabilizer & (9) 43/4" drill collars. INTERV PJSM. RIH wI cutting BHA on 31/2" DP. 19 stands & (1) single. Establish parameters, 45K up wt, 50K down wt. Pick up kelly & break circulation @ 1 bpm I 500 psi, cutter blades now extended. INTERV Slack off slowly & take weight 22' in on kelly, indicating casing collar @ 2150'. Shut down pump. Pick up 24' pup & kelly up. RIH 21' & engage rotary table @ 45 RPM. Torque = 1000 - 1500 ftllbs. Rotate for a few minutes to get stretch out of pipe & bring on pump to extend cutter blades. Increase pump pressure to 1200 psi @ 5 bpm. Increase rotary table speed to 80 RPM. After 2 - 3 minutes, note pump pressure dropped to 600 psi & pump rate increased to 5.5 bpm. OIA pressure increased from 0 psi to 250 psi. All indications of successful cut. Disengage rotary table. INTERV PJSM. Close annular preventor. Line up to pump heated 9.8 ppg brine down DP, taking returns up 9 5/8" x 13 3/8" annulus, thru choke & out to tiger tank. Pump 75 bbls heated 9.8 ppg brine followed wI 50 bbls 9.8 ppg heated brine mixed wI (5) bbls Safe-Surf-O. INTERV PJSM. Rig up Little Red Hot Oil, PT lines to 2500 psi, OK. INTERV Line up & pump (50) bbls 110 degree diesel & chase wI 25 bbls 9.8 ppg brine. Allow to soak & take on 9 .8 ppg brine. Pump (25) bbls 110 deg diesel & chase wI 155 bbls heated 9.8 ppg brine @ 5.5 bpm I 750 psi, taking all returns thru choke to tiger tank. P P P P 20:00 - 21 :00 1.00 EVAL 21 :00 - 23:00 2.00 EVAL 23:00 - 00:00 1.00 EVAL 1/4/2006 00:00 - 06:00 6.00 06:00 - 07:00 1.00 BOPSU 07:00 - 08:00 1.00 CASRE 08:00 - 09:30 1.50 CASRE 09:30 - 10:30 1.00 CASRE P 10:30 - 12:00 1.50 CASRE P 12:00 - 13:00 13:00 - 17:00 1.00 CASRE P 4.00 CASRE P P P Printed: 1/23/2006 1 :06:04 PM Page 6 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: WGI-08 Common Well Name: WGI-08 Event Name: WORKOVER Start: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 4ES Rig Number: .~.~__I From _~ To J Ho~rs I Task ¡Code NPT ¡ Phase 1/4/2006 17:00 -19:30 2.50 CASRE P INTERV 19:30 - 21 :00 1.50 BOPSU INTERV INTERV 21 :00 - 22:30 1.50 CASRE 22:30 - 00:00 1.50 CASRE INTERV 1/5/2006 00:00 - 03:00 3.00 CASRE INTERV 03:00 - 06:00 3.00 CASRE INTERV 06:00 - 07:00 1.00 CASRE INTERV 07:00 - 08:00 1.00 BOPSU INTERV 08:00 - 11 :30 INTERV 11 :30 - 13:00 1.50 INTERV 13:00 - 15:00 2.00 INTERV 15:00 - 16:00 1.00 INTERV 16:00 - 16:30 0.50 INTERV 16:30 - 17:30 1.00 DECOMP 17:30 - 18:30 1.00 DECOMP 18:30 - 19:30 1.00 PULL P DECOMP 19:30 - 20:30 1.00 PULL P DECOMP 20:30 - 21 :30 1.00 PULL P DECOMP 21 :30 - 23:00 1.50 PULL P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 1/6/2006 00:00 - 04:30 4.50 PULL P DECOMP 04:30 - 06:30 2.00 PULL P DECOMP 06:30 - 07:30 1.00 PULL P DECOMP 07:30 - 09:30 2.00 PULL P DECOMP 09:30 - 11 :00 1.50 PULL P DECOMP 11 :00 - 12:30 1.50 PULL P DECOMP 12/27/2005 1/18/2006 Spud Date: 4/3/1990 End: 1/18/2006 Description of Operations -...---------.-. ..-..---.-.-..----- POH and LD BHA #9 - multi-string cutter assembly. C&C floor. Prep to fish wellhead packoff and 9-5/8" casing. Install 9-518" pipe rams and test door seal to 3500 psi for 5 minutes. Good test. PU wellhead packoff tool. Engage packoff tool in packoff assembly and verify J slot open. MU BHA #10 - 9-5/8" casing spear and packoff. Engage 9-518" casing with spear. Fish 9-5/8" casing. Pick up fish approx. 5 ft. to verify free movement of fish. Up wt. - 120K. to unland casing hanger and packoff. Free hanging wt. 100K. Circulate bottoms up and rig up floor and casing handling tools to POH and LD 9-5/8" casing. POH LD 9-5/8" casing. First 25 jt.s 9-5/8" casing laid down are missing parts of or all of centralizers. Cont. POH LD 9-5/8" casing. Recovered total of 1 mandril hanger, 4' Pup, 51 full jts & 23.03' cut off jt. No complete centralizers recovered. Clear & clean rig floor. RID casing tools. NOTE: Drained stack & noted bird's nest of centralizer bow springs lodged in stack in area of blind rams & pipe rams. Discuss options wI town. Opt to N/D stack. PJSM. N/D BOPE & raise enough to insert plywood to keep bow springs from falling down well bore. Reset stack & secure wI BOP bolts. Open blind ram doors & pipe ram doors & remove centralzer parts, (2) 5 gallon buckets full & (1) 25 gallon trash can full. N/D tubing spool. Set test plug. PJSM. N.U BOPE. PJSM. CIO 9 5/8" pipe rams to 2 7/8" x 5" VBRs. PJSM. Pressure test pipe rams & breaks @ 250 I 3000 psi. PJSM. Break down spear assembly. PJSM. Pick up 133/8" cleanout assembly BHA #10 - 9-5/8" casing scraper with stinger. RIH wI BHA #10 on 3-1/2" DP. Sting into to top of casing stub at 2170' md. No obstructions encountered. Circulate bottoms up at 4 bpm @ 370 psi. POH wlBHA #11. LD BHA #11. C&C rig floor. PU BHA #12. BHA #12 very tight traveling through wellhead. Turned BHA wlrig tongs to get it to go through wellhead. Cont. PU BHA #12. BHA #12 very tight traveling through wellhead. Turned BHA wlrig tongs to get it to go through wellhead. When last jt. wash pipe through wellead, BHA falling free. RIH wlBHA #12 to top of 9-5/8" csg. stub at 2170'. Tag top of stub w/19 stds in + 2'. Up wt = 50K, down wt = 50K. PJSM. Pick up kelly & circulate bottoms up @ 4 bpm 1250 psi. PJSM. Rotate down over top of 9 5/8" stub, 2-4K WOB max, 2000 ft Ibs max torque seen, rotating @ 30 RPM & pumping @ 3.5 bpm @ 200 psi. Ream down to 2205'. PJSM. Pump (20) bbls Hi Vis sweep around @ 5 bpm 1700 psi. PJSM. POOH wI burn shoe BHA. Printed: 1/23/2006 1 :06:04 PM Page 7 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date WGI-08 WGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 1/6/2006 1/7/2006 I . . From - To Hours! Task : Code I NPT 4.00 ~ULL·-;--r-·-- 4.50 PULL P 12:30 - 16:30 16:30 - 21 :00 21 :00 - 00:00 3.00 PULL P Start: Rig Release: Rig Number: Phase I DECOMP DECOMP DECOMP DECOMP 02:00 - 03:00 1.00 PULL P DECOMP 03:00 - 04:00 1.00 PULL P DECOMP 04:00 - 05:30 1.50 PULL P DECOMP 05:30 - 06:00 0.50 PULL P DECOMP 06:00 - 07:00 1.00 PULL P DECOMP 07:00 - 08:00 1.00 PULL P DECOMP 08:00 - 08:30 0.50 PULL P DECOMP 08:30 - 10:00 1.50 PULL P DECOMP 10:00 - 11 :30 1.50 PULL P DECOMP 11 :30 - 13:30 2.00 BOPSU P DECOMP 13:30 - 16:00 2.50 BOPSU P DECOMP 16:00 - 18:00 2.00 CASE P DECOMP 18:00 - 22:00 4.00 CASE P DECOMP 22:00 - 00:00 2.00 CASE P DECOMP 1/8/2006 00:00 - 04:00 4.00 CASE P DECOMP 04:00 - 05:00 1.00 CASE P DECOMP 00:00 - 02:00 2.00 PULL P 05:00 - 06:00 1.00 CASE DECOMP 06:00 - 07:00 1.00 BOPSU DECOMP 07:00 - 08:30 1.50 BOPSU DECOMP 08:30 - 10:00 1.50 BOPSU DECOMP 10:00 - 10:30 0.50 CASRE INTERV 10:30 -11:30 1.00 CASRE INTERV 11 :30 - 12:00 0.50 CASRE INTERV 12/27/2005 1/18/2006 Spud Date: 4/3/1990 End: 1/18/2006 Description of Operations PJSM. Rig up false floor to UD washpipe. UD washpipe, shoe, jars. Clear clean rig floor. PJSM. Pick up and make up back off tool BHA #12 per BFT fisherman. Torqued backoff tool connections to 50K ft./lbs. RIH w/BHA #12 - backoff assembly to top of 9-5/8" csg. stump at 2170'. Filled DP with water every 5 stands. PU kelly, sting into csg. stump and space out to locate upper slips at 2183'. Engage lower and upper backoff slips and backoff csg. stump approximately 8 turns. Torque req'd. to break csg. thread jt. - -34k ft./lbs. Drop dart to shear open BHA and drain DP. POH wlBHA #12 - backoff assembly. LD BHA #12. Clear and clean rig floor. PJSM. Pick up fishing BHA to spear & pupp 9 5/8" casing stub. PJSM. RIH wI fishing BHA, 19 stands + (2) singles. PJSM. Establish parameters. 50K up wt, 48K down wt. Engage spear wI stop at top of tubing stub @ 2170' DPM. Over pull 50K to 100 K to set spear. Slack off to 55K & rotate (5) turns to the left. Observe wt drop to 50K. Pick up free to 50K. PJSM. POOH w/3 1/2" DP & fishing BHA. PJSM. UD fishing BHA. Recovered 17.3' of 9 5/8" casing, (pin end recovered). PJSM. CIO pipe rams to 9 5/8". PJSM. Test ram door seals @ 250/4000, test plug leaking, pull, inspect & grease, retest, no leaks detected. Pull test plug PJSM. Rig up floor to run 9 5/8" casing. M/U Baker 9-5/8" screw-in sub wlcut lip guide, 10ft. pup jt. with baffle & plug on seat, HES ESSV cementer & 9-5/8" BTC x 9-5/8" TCII x-over jt. Torqued and Baker-Lok'd all BTC thread connections to 9000 ft-Ibs. BFT fisherman and HES service personnel on rig floor during assembly. RIH w/51 jts. 9-5/8" TCII casing. Torqued casing thread jts. to 17000 ft-Ibs. Filled casing with water every 5 jts. while running in hole. Cont. RIH w/9-5/8" TCII casing. Filled pipe with water every 5 jts. while running in hole. Tag top of casing coupling @ 2187'. Up wt, 96K, down wt 96K. Sting Baker screw-in sub into casing collar w/3000# down weight. Screw into collar with casing tongs. Achieved 11.75 turns with 1 OK ft-Ib torque on pipe. Pull tested connection to 250K. C & C rig floor. PJSM. N/D BOPE & raise up to set casing slips. PJSM. Pull 9 5/8" casing to 250K. Center casing in spool. Set casing slips. PJSM. Slack off 200K on casing slips, N/U BOPE & test seal breaks in BOPE by closing 9 5/8" Pipe rams, OK. Pre Job Safety meeting covering all phases of upcoming cement job including rig up and post job line flushing. Rig up lines to tiger tank. Make up cementing head and lines to same. PJSM. Line up & pump wI rig pump, open valve in ES Printed: 1/23/2006 1 :06:04 PM BP EXPLORATION Operations Summary Report Page 8 of 13 Legal Well Name: WGI-08 Common Well Name: WGI-08 Spud Date: 4/3/1990 Event Name: WORKOVER Start: 12/27/2005 End: 1/18/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2006 Rig Name: NABORS 4ES Rig Number: Ii. I I Date I From - To I Hours ¡ Task : Code' NPT Phase Description of Operations --.. .......--.-.... .---....---------- 1/8/2006 11:30 -12:00 0.50 CASRE P INTERV Cementer wI 1800 psi, pump 25 bbls heated 9.8 ppg brine, taking returns up 9 5/8" x 13 3/8" annulus to tiger tank, 4 bpm @ 150 psi. 12:00 - 13:00 1.00 REMCM P INTERV PJSM. Line up wI Dowell pump & pump (5) bbls fresh water ahead. Test tlines to 4500 psi, OK. Mix water temp = 70 degrees. Commence pumping Arctic Set 1, 15.7 ppg cement @ 4.8 bpm, 400 psi. Pump total of 160 bbls cement. 13:00 - 14:00 1.00 REMCM P INTERV Shut down Dowell pump, shut in 9 5/8" x 13 3/8" annulus valve. Flush Dowell cement line. Line up Nabors pump. Drop ES cementer closing plug & displace wI Nabors pump, pumping 9.8 ppg brine @ 5 - 6 bpm 450 -700 psi. Slow pump down wI 155 bbls displaced. wI 161 bbls displaced, see pressure increse to 1700 psi & see indication of valve on ES cementer close. Increase pressure to 1900 psi & hold for a few minutes. Bleed pressure off of 9 5/8" casing and check for flow back, no flow back. 14:00 - 15:30 1.50 REMCM INTERV PJSM. Rig down cementing tools, flush lines. 15:30 - 16:30 1.00 BOPSU INTERV PJSM. N/D BOPE & choke & kill lines. Raise BOPE stack for casing cut. 16:30 - 18:00 1.50 BOPSU INTERV PJSM. Rig up Wachs casing cutter & cut off 9 5/8" casing. Length of cut off jt = 26.87' 18:00 - 21 :00 3.00 BOPSU INTERV PJSM. UD cut joint, N/D BOPE to install spool. 21 :00 - 00:00 3.00 BOPSU INTERV N/U tubing head, BOPE, choke and kill lines. 1/9/2006 00:00 - 05:00 5.00 BOPSU INTERV N/U tubing head, BOPE, choke and kill lines. P/U and set test plug. P/U test jt. Changeout 9-5/8" pipe rams to 3-1/2" x 6" VBR's. PIT break and BOPE body to 250/4000 psi. Charted test. LID test jt. & pull test plug. 05:00 - 06:30 1.50 CLEAN P INTERV P/U BHA #14. 06:30 - 08:30 2.00 CLEAN P INTERV RIH wI clean out BHA. 08:30 - 11 :30 3.00 CLEAN P INTERV PJSM. Tag w/19 stds & (2) singles @ 2172'. UD (2) singles & kelly up & establish parameters. 47K up wt, 47K down wt. Bring on pump @ 4 bpm I 250 psi. Rotate @ 80 - 100 RPM, off bottom torque = 1500 ftllbs. Mill thru top plug w/4 - 6K WOB. Make connection, Tag bottom plug 12' in on kelly @ 2184'. Mill up bottom plug w/4 - 6K WOB, as with 1st plug. 11 :30 - 12:30 1.00 CLEAN P INTERV PJSM. Mix Hi Vis sweep & sweep hole, getting back plastic, aluminum & a little sand. 12:30 - 14:00 1.50 CLEAN P INTERV Stand back kelly & RIH w/3 1/2" DP. Tag wI 43 stands, (1) single & 15' @ 4429'. 14:00 - 16:00 2.00 CLEAN P INTERV PJSM. Establish parameters. 77K up wt, 77K down wt. Bring on pump @ 5 bpm I 750 psi. Attempt to circulate down thru sand, unable to ... may be a few centralizer bow springs still down there. Pump Hi Vis sweep & chase wI clean seawater wI bit resting on top of fill. 16:00 - 16:30 0.50 CLEAN P INTERV PJSM. Break off head pin, UD (1) jt, stand back (2) stands. 16:30 - 17:30 1.00 CLEAN P INTERV PJSM. Fill hole, close pipe rams & pressure test 9 5/8" casing from surface to top of fill @ 4429'. Test to 4100 psi 130 minutes, charted, good test, 0 bleed off. 17:30 - 19:30 2.00 CLEAN P INTERV POH wlBHA #14 & 3-1/2" DP. UD BHA #14. 19:30 - 20:30 1.00 CLEAN P INTERV M/U reverse circulating junk basket assembly. 20:30 - 00:00 3.50 CLEAN P INTERV RIH w/BHA #15 & 3-1/2" DP to clean out junk from hole. Tag junk I sand top at 4429'. 1/1 0/2006 00:00 - 01 :30 1.50 CLEAN P INTERV Break circulation at 450 psi @ 5.5 bpm. Up wt. 78K - down wt. Printed: 1/23/2006 1 :06:04 PM Page 9 of 13 BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: Task Code NPT· Phase .l....____. INTERV 80K. Rotated kelly down to 4435' @ 40-45 rpm. Pump 50 bbls. hi-vis sweep @ 4 bpm @ 450 psi. Once sweep away, chased sweep with clean seawater and increased pump rate to 5.5 bpm @ 450 psi. Circulate sweep to surface w Ijet basket @ 4435'. Recovered small amount of river sand across shaker. INTERV POH wlBHA #15. Recovered several pieces of aluminum baffle plate, float assembly and casing centralizer springs in jet basket. Boot baskets empty. INTERV RIH wI BHA #15 & 3-1/2" DP to clean out junk from hole. INTERV PJSM. Kelly up on 43 stands & (1) single. 83K up wt, 76K down, 77K rotating wt. Tag (dry) @ 4435'. Pick up 10' & bring on pump @ 5 1/2 bpm 11250 psi. Engage rotary table @ 80 RPM. Slack off & set as much as 10K WOB while rotating & pumping from 4435' - 4444', all wt came back. PJSM. Pump sweep wI @ 4444', CBU, 5112 bpm @ 1250 psi, sand back, circulate to clean returns. POOH wI reverse circulating junk basket & clean out same. Approximately (12) twisted up centralizer bands protruding out end of shoe. None in basket proper, (above fingers). PJSM. Inspect reverse circulating basket & RIH wI same assembly - BHA #16 on 31/2" DP. PJSM. Kelly up on 43 stands & (1) single. 83K up wt, 76K down, 77K rotating wt. Tag (dry) @ 4446',27' in on kelly. Dry drill on junk f/4446' - 4448' wI 3 -4K WOB, no significant torque increase. Pick up 10' & bring on pump @ 6 bpm 11250 psi. Engage rotary table @ 80 RPM. Slack off & set as much as 10K WOB while rotating & pumping from 4446' - 4453', all wt came back. PJSM. Pump sweep wI @ 4453', CBU, 6 bpm @ 1250 psi, sand back, circulate to clean returns. PJSM. POOH wI reverse circulating basket, recovered approximately (2 - 3) centralizer bow springs, (small pieces). PJSM. Consult wI town. Baker manufacturing components necessary to finish cleaning out around Halliburton Bridge Plug fish neck. In the mean time, rig is stringing new drilling line. POH wldrill collars and stand back same. Pull wear ring. Weekly BOPE test. AOGCC notified for witness test. AOGCC (Chuck Sheve) waived witness test. P/U and set test plug. RILDS. Test BOPE to 250/4000. Charted test. BOLDS. Test witnessed by Nabors tour pusher & BP Company Man. Pull and UD test plug. P/U and install wear ring. PJSM. P/U BHA #17, reverse circulating junk basket assembly wI extension. PJSM. RIH wI cleanout assembly on 3 1/2" DP/. PJSM. Pick up kelly & establish parameters. 85K up st, 83K down wt. Dry tag @ 4455'. Pick up 10'. Bring on pump @ 5.5 bpm I 2200 psi. Circulate down over fishneck on Halliburton Packer, set down 5K..., repeat (2) more times. Circulate sweep around @ 5 1/2 bpm 12200 psi, sand back.., circulate to clean returns. INTERV PJSM. POOH wI clean out assembly. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-08 WGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To Hours 1/10/2006 00:00 - 01 :30 1.50 CLEAN P 01 :30 - 04:00 2.50 CLEAN P 04:00 - 06:00 06:00 - 06:30 2.00 CLEAN P 0.50 CLEAN P 06:30 - 08:00 1.50 CLEAN P INTERV 08:00 - 10:00 2.00 CLEAN P INTERV 10:00 - 12:00 2.00 CLEAN P INTERV 12:00 - 12:30 0.50 CLEAN P INTERV 12:30 - 14:00 1.50 CLEAN P INTERV 14:00 - 16:00 2.00 CLEAN P INTERV 16:00 - 22:30 6.50 CLEAN P INTERV 22:30 - 23:30 1.00 CLEAN INTERV 23:30 - 00:00 0.50 BOPSU INTERV 1/11/2006 00:00 - 05:00 5.00 BOPSU P INTERV 05:00 - 06:30 1.50 CLEAN P INTERV 06:30 - 08:30 2.00 CLEAN P INTERV 08:30 - 10:30 2.00 CLEAN P INTERV 10:30 - 12:30 2.00 CLEAN P 12/27/2005 1/18/2006 Spud Date: 4/3/1990 End: 1/18/2006 Description of Operations Printed: 1/23/2006 1 :06:04 PM Page 10 of 13 BP EXPLORATION Operations Summary Report Date WGI-08 WGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES . I I From - To ¡ Hours Task Code Start: Rig Release: Rig Number: NPT I Phase i INTERV PJSM. UD cleanout asasembly.., (recovered 1 bowspring), nothing in finger basket. P/U Halliburton Packer retrieving tool & drill collars. INTERV RIH wI packer retrieving tool on 31/2" DP. INTERV PJSM. M/U head pin on stand #44. 81K up wt, 77K down wt. Close bag & reverse circulate down over fish neck @ 3 bpm I 350 psi, take weight 28' in @ 4558'. Set down 15K & J into fishneck lug. Overpull 10K to verify, slack off to neutral wt & reverse circulate Hi Vis sweep Around @ 5 bpm I 650 psi. INTERV PJSM. Little bit of sand back wI sweep. Shut down pump, bleed pressure & open bag. Slack off 15K on bridge plug, turn to the right & hold torque & pick up 25K over up wt, .. repeat process several times. Bridge plug released OK, slack off below 4458' to verify, OK. PJSM. POOH SLOWLY wI Halliburton retrievable bridge plug. UD RBP. Recovered 1 bowspring and lost 1 bowspring downhole. RBP mechanically intact. Clear and clean rig floor. Prep to run BHA #18. P/U BHA #18 and RIH. RIH wI BHA #18 on 3-1/2" DP. Pick up kelly and break circulation @ 5 bpm 11600 psi. Up wt. - 128k Down wt. - 120k. Tag top of seal assembly @ 7882'. Work pipe up and down while circulating. Set 5000 # on top of seal assembly. PU DP to neutral point just above seal assembly. Circulate 45 bbl high-vis sweep @ 5 bpm 11600 psi. CBU x 1.5. Increase pump rate to 6 bpm @ 2000 psi. PJSM. POOH wI scraper Icleanout assembly & 31/2" DP. PJSM. Stand back DCs, lay down BHA, nothing recovered in reverse circulating junk basket, small amount of sand in junk subs.. Clear I clean rig floor. PJSM. Rig up Schlumberger E - Line to run USIT log. N/D flowline & drip pan under rig fIIoor. N/U shooting flange. PJSM. Rig up sheaves, pick up logging tools, start in hole, test pack off to 500 psi, OK. RIH. Run USIT from 7850' to surface. Good data from -2600' down. Tool readings indicate dirty fluid in well from 2600' to surface therefore no good cement data. Decision made with engineer in town to run open ended to -3000' and CBU with clean seawater and then re-Iog that interval. PJSM. Rig down Schlumburger E-line. N/D shooting flange. N/U flowline and drip pan. Prepare to RIH to -3000' for circulation. TIH with DCs and 29 stands of DP to 3032' DPMD. Continue TIH with shoe, 3 drill collars, and drill pipe to 3032' DPMD. Pump and circulate 250 bbls of clean seawater from 3032' DPMD to surface @ 6 bpm I 530 psi to ensure clean wellbore fluids for US IT logging. POH shoe, DCs and 29 stands of DP. PJSM. N/D flowline and drip pan. N/U shooting flange. Finish rigging up SOS. Pick up tools. RUN USIT & CBL from surface to 3000' & back up. Log Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .._________. ______________ ...._.___n_... 1/11/2006 12:30 - 13:30 1.00 CLEAN P 13:30 - 15:00 15:00 - 17:00 1.50 CLEAN P 2.00 CLEAN P 17:00 - 17:30 0.50 CLEAN P 17:30 - 21 :30 4.00 CLEAN P INTERV 21 :30 - 23:30 2.00 CLEAN P INTERV 23:30 - 00:00 0.50 CLEAN P INTERV 1/12/2006 00:00 . 01 :00 1.00 CLEAN P INTERV 01 :00 - 03:30 2.50 CLEAN P INTERV 03:30 - 04:00 0.50 CLEAN P INTERV 04:00 - 06:00 2.00 CLEAN P INTERV 06:00 - 09:00 3.00 CLEAN P INTERV 09:00 - 10:30 1.50 CLEAN P INTERV 10:30 - 12:00 1.50 EVAL P INTERV 12:00 - 14:00 2.00 EVAL P INTERV 14:00 - 21 :00 7.00 EVAL P INTERV 21 :00 - 23:30 2.50 EV AL N FLUD INTERV 23:30 - 00:00 0.50 EV AL N FLUD INTERV 1/13/2006 00:00 . 01 :00 1.00 CLEAN N FLUD INTERV 01 :00 - 02:00 1.00 CLEAN N FLUD INTERV 02:00 - 03:30 1.50 CLEAN N FLUD INTERV 03:30 - 05:00 1.50 EVAL N FLUD INTERV 05:00 - 08:00 3.00 EV AL N FLUD INTERV 08:00 - 13:00 5.00 EVAL P INTERV 12/27/2005 1/18/2006 Spud Date: 4/3/1990 End: 1/18/2006 Description of Operations ..... _....__......_.n __... . ... --....--. .-.-..- Printed: 1/23/2006 1 :06:04 PM Page 11 of 13 BP EXPLORATION Operations Summary Report indicates no cement behind 9 5/8" casing from 2170' to surface. PJSM. Rig down Eline. PJSM. Pick up reverse circulating basket to cleanout 7" to 7908', below packer @ 7882'. TIH with BHA#19 and 80 stands of DP. Tagged at 7888'. Circulate @ 5 bpm 11150 psi and rotate string to get deeper. Worked string down to 7905' . Work pipe up and down from 7888' to 7905' attempting to clean up and fill up junk baskets. Could not advance string from 7888' down without pumping and rotation. Pull up to 7901' and circulate @ 5 bpm 11250 psi to capture as much junk as possible in basket. Decision made to circulate at this depth to prevent from pulling any sandlsluggits from on top of plug so that any solids that aren't captured in basket will fall on sand and not around the plug prong. CLEAN Sat down at 7906' three different times putting 5000# each time. Appears to be a solid tag each time. Pick up to 7901' and start high-vis pill and CBU @ 6 bpm 11500 psi. Decision made to make another cleanout run down to plug body. CLEAN POH with BHA#19 and 80 stands of DP. Inspect junk baskets. Pieces of control line and straps caught above fingers in catcher sub. The boot baskets contained what appears to be scale and sand with small pieces of metal shavings. CLEAN Re-make up BHA #19 to prepare for cleanout down to PRN plug. CLEAN TIH with BHA#19 and 80 stands of 3.5" DP. CLEAN PJSM. RIH w/3 1/2" DP, (80 stands). Kelly up. 127K up wt, 121 K down. Dry tag l' in on kelly @ 7902'. Pick up 5' & bring on pump @ 6 bpm 11500 psi. RIH & wash to 7905' wlo rotating. Hard tag @ 7905'. Pick up & engage rotary table @ 80 RPM 11000 ft Ibs off bottom torque. Rotate down pumping 6 bpm 11500 psi. Mill wl5K max WOB to 7909'..., milling hard @ 7909'. Mill w/10K WOB for a minute, no progress, no torque increase. Max torque throughout operation = 2000 ftllbs. PJSM. Pump (50) bbls Hi Vis sweep & circulate well bore wI shoe @ 7909'. Stand back kelly. PJSM. POOH w/3 1/2" DP. PJSM. Stand back collars, .....inspect reverse circulating basket, recovered several pieces of control line, ... approximately same amount as 1 st run. RIH wI cleanout BHA on 3 1/2" DP. 24 stands. Consult wI town. Opt to POOH & run brass shear stock in barrel below basket to determine how far over the prong we are. BHA #21 on rig floor. Break apart connections in preparation for new BHA components. Waiting for "tattle tail" (brass shear stock barrel) sub to be machined and delivered to rig. Make up BHA #22 with "tattle tail" subs attached to bottom of assembly. Total of 9' of brass pins each spaced out by 1'. PJSM. RIH wI 79 stands and a double of 31/2" DP and BHA #22. Kelly up. 125K up wt, 120K down wt. Dry tag with 29' on kelly @ 7906'. Pick up 4' and bring on pump @ 5 bpm 11200 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-08 WGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date I From - To Hours Task Code I NPT , Phase ! -..-..... -......-.-- 1/13/2006 08:00 - 13:00 5.00 EVAL P INTERV 13:00 - 15:30 2.50 EV AL P INTERV 15:30 - 16:00 0.50 CLEAN P CLEAN 16:00 - 20:30 4.50 CLEAN P CLEAN 20:30 - 21 :00 0.50 CLEAN P CLEAN 21 :00 - 22:00 1.00 CLEAN P CLEAN 22:00 - 00:00 2.00 CLEAN P 1/14/2006 3.00 CLEAN P 00:00 - 03:00 03:00 - 04:00 1.00 CLEAN P 04:00 - 07:30 07:30 - 08:30 3.50 CLEAN P 1.00 CLEAN P 08:30 - 10:30 2.00 CLEAN P CLEAN 10:30 - 14:00 3.50 CLEAN P CLEAN 14:00 - 15:30 1.50 CLEAN P CLEAN 15:30 - 16:30 1.00 CLEAN P CLEAN 16:30 - 18:00 1.50 CLEAN P CLEAN 18:00 - 20:00 2.00 CLEAN N WAIT CLEAN 20:00 - 20:30 0.50 CLEAN P CLEAN 20:30 - 23:30 3.00 CLEAN P CLEAN Start: Rig Release: Rig Number: Spud Date: 4/3/1990 End: 1/18/2006 12/27/2005 1/18/2006 Description of Operations Printed: 1/23/2006 1 :06:04 PM Page 12 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-08 WGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To , Hours I Task Start: 12/27/2005 Rig Release: 1/18/2006 Rig Number: ,Code ¡ NPT , Phase I Description of Operations . m ...m __.._L......_......... , ..._..__._m.. CLEAN Date ---.-------.. 1/14/2006 20:30 - 23:30 23:30 - 00:00 .... -.------... 3.00 CLEAN P 0.50 CLEAN P CLEAN 1/15/2006 00:00 - 00:30 0.50 CLEAN P CLEAN 00:30 - 00:45 0.25 CLEAN P CLEAN 00:45 - 01 :00 0.25 CLEAN P CLEAN 01 :00 - 04:30 3.50 CLEAN P CLEAN 04:30 - 12:00 7.50 CLEAN P CLEAN 12:00 - 13:00 1.00 CLEAN P CLEAN 13:00 - 15:00 2.00 BOPSU RUNCMP 15:00 - 16:00 1.00 BOPSU RUNCMP 16:00 - 21 :30 5.50 RUNCO RUNCMP 21 :30 - 22:00 0.50 RUNCO RUNCMP 22:00 - 23:00 1.00 RUNCO RUNCMP 23:00 - 00:00 1/16/2006 00:00 - 06:00 06:00 - 18:00 18:00 - 00:00 1/17/2006 00:00 - 04:00 04:00 - 05:00 RUNCMP 6.00 12.00 RUNCMP RUNCMP 6.00 RUNCMP RUNCMP RUNCMP 4.00 1.00 Spud Date: 4/3/1990 End: 1/18/2006 psi. Begin rotating workstring at 100A = 2000 ft-Ib of torque. RIH and wash to 34' of kelly in the hole. No increase in torque seen. Stop rotation and work pipe down to 35' of kelly in the hole with about 2k WOB to 7913'. PU 5' and tag again at 7913' with 5k WOB. Start rotating again at 2000 ft-Ib and work to 7914' with no increase in torque. Stop rotation and circulate @ 6 bpm 11600 psi at 7914'. Circulate for 30 mins. Started with 7k WOB and lost 3k WOB in 30 mins. Work pipe up and down without rotating. Cleaned up good with no wt. increase coming back down to 7914'. Top of plug body at 7916'. PU 6' pup to extend work string and try and clean out final 2' to top of plug. Circulating at 6 bpm 11600 psi and worked pipe to 32' kelly in which is 7916' (top of plug body). About 2k WOB seen when tagging. PU l' and pump high-vis pill and CBU @ 6 bpm 11500 psi. Pill came back clean. POH wI BHA #22, 79 stands and a double of DP laying down pipe. PJSM. Break down & lay down cleanout BHA. Recovered equalizing prong from PRN Plug in RN Nipple. PJSM. Clearl clean rig floor. Set test plug. CIO pipe rams to 7 5/8". PJSM. Test pipe rams to 250/4000 psi, OK. Pull test plug. PJSM. Rig up to run 7 5/8" completion string. PJSM with all personnel involved: Nabors, GatorHawk, Baker Start in hole with completion string. Components: WLEG, 2 pups, RN nipple, 2 pups, SABL packer, 2 pups, R nipple, 1 pup and 7" to 7-5/8" crossover. Bakerloc'd between the two pups below the packer, the connection from the pup to the packer, between the two pups above the packer and the crossover to 7-5/8". Trip in hole with 135 joints of 7-5/8" 29.7# L-80 tubing. GatorHawk pressure test each connection with Nitrogen to 3800 psi and ensure proper torque up to 14,450 ft-Ib with Torque-Turn Services. Bakerloc'd both pups above and below the DB nipple. Continue running 7-5/8" 29.7# L-80 tubing. PJSM. Continue running 7 5/8", L-80, Vam Top HC, IPC tubing & jewelry as per procedure, torque turning all 7 5/8" connections to 14,500 ftllbs, 7" connections to 10.100 ftllbs, using Jet Seal Guard Thread Compound & Gator Hawking all 7 5/8" connections to 3800 psi with nitrogen. PJSM. Continue running completion as noted above. 158 joints of tubing in the hole at 00:00. Continue running in hole with 7-5/8" completion. MU Joint 188 to tag SABL packer @ 7882'. Bring on circulation @ 3 bpm I 200 psi. Up wt. 205k down wt. 195 while circulating. Wait for pressure to stabilize and start RIH to tag. Tag @ 27' in with joint 188 and stacked 5K #. Space out 3' above tag per Baker hand and no pup joint needed for proper spaceout. Lay Printed: 1/23/2006 1 :06:04 PM Page 13 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-08 WGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: l i ! Task; Code! NPT Phase i RUNCMP down joint 188. RUNCMP Make up tubing hanger and landing joint. RUNCMP PJSM. Rig down Gator Hawk & Nabors casing tools. RUNCMP Reverse circulate Well with 200 bbls 140 deg Sea Water followed by 200 bbls 140 deg Sea Water containing 25 gal/100 bbls of Corrosion Inhibitor at 3.0 bpm/250 psi. RUNCMP Land Tubing Hanger. RILDS. Test Hanger. RUNCMP Rig up Little Red services. Pressure test lines to 4,000 psi. Begin to pump Diesel to Freeze Protect Well. However, Lil Red pump is down. Repairs completed to Pump. Continue to Freeze Protect Well. U-tube freeze protect from tubing to IA. PJSM. Suck back with Little Red services and have them RU to tubing. Prepare for dropping of ball and rod to pressurize and set packer. Drop 1-7/8" ball and rod to set packer. Start pressure test on tubing once ball and rod set. Tubing pressure increased to 1500 psi for three minutes to start setting process. Pressure increased to 4000 psi and held for 30 minutes. After 30 minutes, the tubing pressure had bled to 3900 psi. Bleed pressure back to 1600 psi. RUNCMP Nabors rig personnel PJSM. Start pressure test on IA. IA pressure increased to 4000 psi and held for 30 minutes. After 30 minutes, the IA pressure had bled to 3950 psi. Bleed IA pressure to zero. Bleed tubing pressure to zero after IA at zero. All pressures recorded and noted on chart. MU two way check valve and land with Cameron. Pressure test two-way check to 1000 psi. Good pressure test. Nipple down BOPE and NU adaptor flange. Continue ND BOPE and NU adapter flange and tree. Begin test on WH equipment. Components: tubing hanger and adapter, tested to 5000 psi for 30 minutes. Tree not pressure tested at this point. NU tree to wellhead. Pressure test tree to 5000 psi - good test. RU lubricator and pull two-way check. Observed 80 psi on Wellhead when TWC was pulled. No running tool for setting BPV on location. Wait for running tool to arrive. Set BPV with Lubricator. Secure Well. Prep to RDMO. Release Rig. Date I From - To ! Hours. --..-----.... . ..--.- --"--" . . ."._..___L_ .-.-..--.- 1/17/2006 04:00 - 05:00 05:00 - 06:00 06:00 - 07:30 07:30 - 10:30 1.00 RUNCO 1.00 RUNCO 1.50 RUNCO 3.00 RUNCO 10:30 -11:30 11 :30 - 16:30 1.00 RUNCO 5.00 RUNCO 16:30 - 17:30 1.00 RUNCMP 17:30 - 18:30 1.00 RUNCMP 18:30 - 19:30 1.00 RUNCMP 19:30 - 20:30 1.00 RUNCMP 20:30 - 22:00 22:00 - 22:30 0.50 RUNCO RUNCMP 22:30 - 00:00 1.50 RUNCO RUNCMP 1/18/2006 00:00-01:15 1.25 RUNCO RUNCMP 01:15 - 02:00 0.75 RUNCO RUNCMP 02:00 - 03:00 RUNCMP 03:00 - 05:00 RUNCMP 05:00 - 05:30 0.50 RUNCO RUNCMP 12/27/2005 1/18/2006 Spud Date: 4/3/1990 End: 1/18/2006 Description of Operations ....---______0 ...--..--- Printed: 1/23/2006 1 :06:04 PM TREE = McEVOY GEN 2 e S. NOTES: DO NOT PRESSUREOA ABOVE 3000 , WELL'HI!AD = McEVOY WGI-08 P ARNING: 2006 RWO TBG TALLY ACTlJATO¡,:r; AXÊLSõÑ DISCREPANCY - WLEG IS 3 FEET ABOVE ORIGINAL KB. ELEV = 60' PKR@ 7892'. PRN PLUG SET @ 7926' HAS A 3.0" BF. ELEV = ? ) ~......... HOLE MILLED THROUGH BTM. PLUG MAY NO LONGER KOP= 1113-3/8" CSG, 68#, 74' ¡- HAVE A FISHING NECK. Max Angle = 30@7000' K-55, ID= 12.415" ............ Datum MD = N/A 20' -17" X 7-5/8" XO, ID 6.323" I DatumTVD= 8800' SS -- 2173' -19-5/8" HES ESSV CEMENTER I I - 2178' -17-5/8" X 7" XO, ID = 6.184" I 19-5/8" CSG, 47#, L-80 TCII, ID = 8.681" I 2186' I · - 2189' -f 7" CAMCO DB-6 NiPPlE, ID = 6.00" I 2200' -17" X 7-5/8" XO, ID = 6.184" I 113-3/8" CSG, 68#, K-55 & L-80, ID = 12.415" I 3481' ~ ~ I 7-5/8" TBG, 29.7#, L-80 IPC,0459 bpf. ID = 6.875" I 7798' I 7798' 1-17-5/8" X 7" XO, ID - 6.563" I I I · 7809' H 7" HES R NIP, ID - 5.963" I Minimum ID = 3.0" @ 7926' Z 7831' -f 9-5/8" X 7" BKR S-3 PKR, ID = 6.151 I 6-5/8" HES PRN PLUG 2$. I · 7855' H 7" HES RN NIP, ID - 5.770" I 17" TBG, 29#, L-80 TCII, .0371 bpf, ID = 6.184" I 7877' I -17" FULL MULESHOE WLEG, ID = 6.184" I 7877' Z .ð 7892' -19-5/8" X 7" BKR SABL-3 PKR, ID = 6.0" I . \I 7926' H 6-5/8" HES RN NIP, ID = 5.5" I --r 7926' PRN PLUG w /3.0" HOLE MILLED 17" TBG-NSCC, 29#, L-80, .0371 bpf, ID = 6.184" I 7941' ¡-- THROUGH BOTTOM OF PLUG (2/12/06) ----r 7941' -17" TT W/WLEG, ID = 6.313" I 1 TOP OF 7" LNR I 8000' l- I H ELMD TT NOT LOGGED I I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8308' 1---.4 ~ ÆRFORA TION SUMMARY 11 REF LOG: FINAL CNP ON 04/03/90 f ANGLE AT TOP PERF: 15 @ 8357' J Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE í 3-3/8" 4 8357 - 8403 0 06/02/90 3-3/8" 4 8442 - 8488 0 06/02/90 3-3/8" 4 8492 -8691 0 06/02/90 Ó 3-3/8" 4 8697 - 8720 0 06/02/90 3-3/8" 4 8726 - 8788 0 06/02/90 3-3/8" 4 8794 - 8844 0 06/02/90 ] 3-3/8" 4 8846 - 8856 0 06/02/90 I PBTD I 8860' I I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 8905' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/16/90 ORIGINAL COM PLETION WELL: WGI-08 06/03/99 LAST WORKOV ER ÆRMIT No 1'1900490 01/18/06 N4ES RWO API No 50-029-22038-00 01/21/06 KSB/TLH DRLG DRAFT CORRECTIONS SEC 11, T11N, R14E, 17.44 FEL' & 160.03' FNL 02/12/06 SRB/PAG MILLED PLUG @ 7926 BP Exploration (Alaska) Sundry No. 305-274 (well WGI-08) 1'10 - 0 4~ Subject: Sundry No. 305-274 (well WGI-08) From: "Reem, David C" <ReemDC@BP.eom> Date: Tue, 13 Dee 2005 11 :07:52 -0900 To: Winton Aubert <winton_aubert@admin.state.ak.us> e e Winton, just FYI we are down-scaling the scope of this workover. We do not now plan on cutting and removing any of the 13-3/8" surface casing. Instead, we will be cementing in our new section of 9-5/8" casing to surface. Essentially the rest of the workover scope remains unchanged. We hope to rig up on this well in the last few days of this month. Let me know if additional information is required. Thanks Dave Reem WellslWorkover Engineer 564-5743 (w) 632-2128 (c) §CANNf[) DEC; ] {j 20D5 1 of 1 12/13/2005 2:23 PM n=~ !I~ Lb ) ) / / I ! ,¡ / j / FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 C {J..O~'OÚ( Re: Prudhoe Bay WGI-08 Sundry Number: 305-274 .'~f·; k~ b\~,^.Wi\.:;v ~J íC.'" E ICy 6) i' ') 0, 0 1,: ~\¡¡¡ &'1.ìQ 1. [¡,\or....,!,,,· d .P ¡)"~ JL I~ ..J Dear Mr. Reem: 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. Please provide at least twenty-four (24) hours 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, rJ/4~ John K. Norman Þ Chairman DATED thiSJ1f;;.y of September, 2005 Encl. ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA6s[m 20 AAC 25.280 \tJ4,4..,~' / ¡'I!zooç 1,1, err fl' "or"'"',. 0 ,.;1"""(:'" ,',','," "y c\ ~""..",," .'" ~ ,~ t·,,,,,,, If ' " , ,\ gl",,,, 0, '" it'''''' rW ", .~,':;';~." ¡;';t.~1t1o l1 SfP 1 ~~!; 2005 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other o Alter Casing /II Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O, Box 196612. Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Current Well Class: o Development 0 Exploratory o Stratigraphic B Service / 5. Permit To Drill Number 190-049 /~ 6. API Number: 50- 029-22038-00-00 /'" 59.9' 9. Well Name and Number: WGI-08 /" 8. Property Designation: ADL 028302 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool ':PR~S~NT','VVJ;:L:LC()~[)HI:IP~$l)MM,~~YII'I!I:I"il:'::I":1 'I': '"I::, 'I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 8860 8590 None MD .TVD . . Bur~t H. Total Depth MD (ft): 8907 Casing. ' Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 8635 Length , Size Junk (measured): None '¡Collapse 110' 20" 110' 110' 1490 470 3481' 13-3/8" 3481' 3481' 3450 1950 8308' 9-5/8" 8308' 8057' 6870 4760 905' 7" 8000' - 8905' 7761' - 8633' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 8357' - 8856' 8105' - 8586' 7-5/8",29.7# x 7",26# Packers and SSSV Type: 9-5/8" x 7" Baker 'SABL-3' packer; 7" Cameo 'DB-6' Nipple Tubing Grade: L-80 Packers and SSSV MD (ft): 7892'; 2213' Tubing MD (ft): 7941' 12. Attachments: B Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: o Exploratory 0 Development B Service / 16. Verbal Approval: Commission Representative: 17. I hereby certi that the foregoing is true and correct to the best of my knowledge. Printed Na e David Reem Title Drilling Engineer C-~ November 15, 2005 Date: 15. Well Status after proposed work: o Oil /0 Gas o WAG BGINJ o Plugged OWINJ o Abandoned o WDSPL Contact David Reem, 564-5743 Signature Phone 564-5743 Commission Use Only Date 9/1>/05 I Sundry Number: ~ 0 S ' l14 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ØBOP Test ær'MeChanicallntegrity Test 0 Location Clearance Other: Tt' '-- t- ¡So P E fc 4 C' 00 r ç,.;. ^I\XT ;' e Ó~....{' J . RBDMs BFl SEP 2 0 2DD5 Subsequent Form Required: \ 0 - 4 D 4- . Approved By: ~"'l! 4-r~~ COMMISSIONER Form 10-403 Rev~1~~04 ORIGINAL APPROVED BY THE COMMISSION Date 1- It}- f) ~ Submit In Duplicate ) ) Well Status: Shut-in gas injector. Well has confirmed inner annulus x outer annulus communication. The surface casing's top two joints are K-55 grade pipe which is not / rated to withstand injection pressure. The well is secured with a tubing tail plug. Project: Retrieve existing 7.625", 29.7#, L-80 IPC STL completion leaving the packer and tail-pipe. Cut and pull -3400' of 9-5/8". Cut and pull 3 joints of 13-3/8", tie-back /' with new 13-3/8", 68#, L-80, weld on new wellhead. Tie-back in with 3400' of new 9- 5/8", 47#/ft, L-80 TC-II casing and cement in place. Re-complete with 7.625", 29.7#/ft, L-80 IPC Yam Top HC tubing, permanent packer with tail-pipe mated to existing packer. , Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and t' MITIA post packer setting. PRE-RWO · Set TTP in "R" nipple to secure well (DONE). · Punch circ holes in 7-5/8" tubing 1 full joint above the packer. · Circulate the well over to seawater with diesel freeze protect. CMIT to 2000 psi to verify tubing tail plug integrity. MITOA to 2000 psi to verify 13-3/8" shoe integrity. · Cleanout and Rhino-line the cellar box for use as primary containment during / RWO. Install outlet valve on the conductor pipe. RWO 1. MIRU workover rig. Circ out diesel freeze-protect and verify well is dead 2. ND tree, NU )RÓ1JllY test BOPE per BP and AOGCC regulations (250 psi low"","" pressure tes~psi high pressure test (test the annular to 3500 psi). 3. RIH w/multi-string cutter (dressed w/8.5" knives) and cut the 1st full joint of 7- 5/8" tubing above the packer. 4. Pull 7-5/8" tubing down to the cut. 5. Run 9-5/8" scraper to the 7-5/8" stub. 6. Set 9-5/8" Model 3L RBP just above tubing stub. Spot -20' of river sand on RBP. 7. Run 9-5/8" USIT to locate top of cement in 9-5/8" x 13-3/8" annulus. /' 8. Set 2nd RBP -600' below the TOC indicated on the USIT log. Spot 20' of sand on RBP. 9. Mechanically cut the 9-5/8" casing in the 1st full joint above the TOC. 10. Mobilize and circulate out all Arctic Pack from the 9-5/8" x 13-3/8" annulus. 11. Pull 9-518" down to the cut. / 12. Run wash shoe and 13-3/8" scraper down to the 9-518" stub. Ensure wash shoe is able to get beyond the next 9-5/8" collar by -6'. Reverse circulate the wellbore clean. 13. Set 13-3/8" bridge-plug just above the 9-518" stub. PT plug to 1000 psi. Turn hole over to diesel. 14. Mechanically cut the 13-3/8" in the 1 st joint of L-80. 15. ND BOPs, ND tubing spool. Mechanically cut off the starting head using Wachs /' cutter. ') ) 16. Spear 13-3/8" and pull the K-55 joints and partial L-80 joint. 17. RIH with 16" wash-pipe and wash down over 13-3/8" stub past the next 13-3/8" collar by ~6' or more. Wash with diesel or mineral oil to ensure no freezable liquids in the 13-3/8" x 20" annulus. 18. Back-off 13-3/8" stub. /' 19. RIH w/new 13-3/8" 68# L-80 casing and over-shot guide-sub. Screw into existing L-80 casing. 20. Cut off excess 13-3/8" casing and weld on new 13-3/8" 5M x 13-5/8" 5M starting head. PT weld with nitrogen per ca~. Install and test 13-3/8" pack-off. /-._____ 21. NU tubing s~ool and BOP. .PT all t 40 psi. PT the 13-3/8" casing to 2000 psi. 22. RIH and retneve 13-3/8" bndge-plu . - 23. Back-off 9-5/8" casing stub. 24. RIH with new 9-5/8", 47#/ft, L-80 TC-II casing, shoe-track and over-shot guide- // sub. Screw into existing 9-5/8" casing. PT casing to ~2000 psi. Pressure up to open ES-cementer. Verify communication up 9-5/8" x 13-3/8" annulus. 25. Cement 9-5/8" in place with target top of cement = 500'md. Diesel ahead of cement to ensure freeze protection. Close ES-cementer. Pull ~ 150K tension on 9-5/8" . 26. Split stack, install slips/pack-off, slack-off on casing to fully engage slips. Test pack-off. Rough cut 9-5/8". Set back BOPs. Make final dressing cut on 9-5/8" NU tubing spool. NU BOPs. Test spool/BOPs to 4000 psi. /'- 27. Drill out shoe-track down to sand top on upper RBP. PT casing to 4000 psi. 28. Retrieve upper 9-5/8" RBP. 29. Retrieve lower 9-5/8" RBP. 30. Spear 7" stub and rotate k-anchor free from SABL-3 packer. 31. RIH with reverse circulating junk basket(s) and clean off any debris on top of TTP set in original tail-pipe. POH and LDDP except for 2000'. 32. RIH with sealing latch assembly, 7" pup joint with 8-1/8" over-shot pinned in place, 7" 26#/ft L-80 tail-pipe, 7" x 9-5/8" L-80 S-3 packer, 7" crossed over to 7- 5/8", 29.7#/ft, L-80, IPC VamTop HC completion. Will have a 7" DB-6landing nipple at ~2100' for flapper-type safety valve installation after the rig moves off. 33. Latch into existing SABL-3, shear overshot pins, reverse in packer fluid and / freeze protection. 34. Set S-3 packer. MIT-T to 4000 psi, MIT-IA to 4000 psi. / 35. RIH to 2000'md and reverse in diesel FP. POH and LDDP. 36. Set BPV. ND BOP, NU and PT tree to 5000 psi. 37. RDMO. POST-RWO · Pull ball&rod from RHC sleeve. Pull RHC sleeve. · Pull TTP from the 6-5/8" RN nipple. · Set A-I injection valve in DB-6 landing nipple. · Perfom top-job on 13-3/8" x 20" annulus using 15.7 ppg AS1 cement. · Tie-in injection lines, re-set well house and instrumentation. · POI. MIT-IA w/AOGCC witness. TREE =. Mc EV OY GEN 2 WELLHEAD = McEVOY ) "ÃërUA TOR =~-"-AxEïSÕ~j" KB~äEV';" ' ··60" BF, ELEV = ? KOP= 5400' 13-3/8" CSG, 68#, -i 74' Max Angle = 30 @ 7000' K-55, ID = 12.415" Datum MD = N/A ,,,,,,,,,,,,,,...,,,,,,,,,,, "..,,,,,,,, """. Datum ND = 8800' SS 113-3/8" CSG, 68#, K-55 & L-80, ID = 12.415" l-f 3481' Minimum ID = 5.5" @ 7926' 6-5/8'· HES RN NIPPLE I 7-5/8" TBG-STL, 29,7#, L-BO, ,0459 bpf, ID = 6,875" l-f I TOP OF 7" TBG-NSCC l-f 7890' 7890' 17" TBG-NSCC, 29#, L-BO, ,0371 bpf, ID = 6.184" l-f 7941' I TOP OF 7" LNR l-f WG 1-08/ SAFL.)NOTES: DONOTPRESSUREOAABOVE 3000 PSI. t- _ 2213' 1-f7" CAM BAL-O SVLN NIP, ID = 5,937" I ~ ~ ~I . ~)< ::.,:~, .,: : ~:,: .:::~. .:~.~: M J} 7890' l-i 7 -5/8" X 7" XO, ID = 6,563" I 7891' 1- 7-5/8" BKR KBH-22 ANCHOR SEAL ASSY, ID = 6,083" Z Z ---1 7892' l-f 9-5/8" x 7" BKR SABL-3 PKR, ID = 6,0" I r 1 7926' l-f 6-5/B" HES RN NIP, ID = 5,5" I 7941' 1-f7" lTW/WLEG, ID = 6,313" I l-i ELMD IT NOT LOGGED I 8000' ~ ~Ni( :¡ili~i: 1 9-5/8" CSG, 47#, L-BO, .0732 bpf, ID = 8,681" l-f 8308' ~ .. ÆRFORA TION SUMMARY REF LOG: FINAL CNP ON 04/03/90 ANGLE AT TOP ÆRF: 15 @ 8357' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 /8357-8403 0 06/02/90 3-3/8" 4 8442-8488 0 06/02/90 3-3/8" 4 8492-8691 0 06/02/90 3-3/8" 4 8697 -8720 0 06/02/90 3-3/8" 4 8726-8788 0 06/02/90 3-3/8" 4 8794-8844 0 06/02/90 3-3/8" 4 8846-8856 / 0 06/02/90 I PBTD l-f 17" LNR, 29#, L-80. ,0371 bpf, ID = 6,184" l-f 8860' 8905' I I I I ~ REV BY DA TE REV BY COMMENTS 01/30/05 KSB/PJC FISH (WRDP-2 SSSV & RING) 07/02/05 KDClTLH FISH PULLED PRUDHOE BA Y UNIT WELL: WGI-08 ÆRMIT No: 1900490 API No: 50-029-22038-00 SEC 11, T11N. R14E. 17.44 FEL' & 160.03' FNL DATE 04/16/90 06/03/99 11/03/01 03/25/03 04/11/03 04/30/04 RNlTP JlA/KK JRC/KK JLA/KK COMMENTS ORIGINAL COMPLETION LAST WORKOVER CORRECTIONS CSG & SA FEN NOTE REV , CASING CORRECTION CASING CORRECTION BP Exploration (Alaska) 'fREE =' ,. WELLHEAD = ACTUATOR = KB. 8.EV = SF, ËiBi'; RO¡::>; Max Angle = DatÚmMÓ';' DatÙm1YÖ; 6-3/8" 5M McEVOY AX8.S0N 60' ? 5400' ..,,~O ~ 7000: N/A åêÖö'ss 9-5/8", 47#/ft, L-80 TC-II ~ from -3400' to surface. ~ TOC -500'md ~ 1--1 3481' I~ WGI-08 Proposed) Diesel Freeze-Protect 113-3/8" CSG, 68#, L-80, ID = 12.415" Minimum IC = 5.5" @ 7926' 6-5/8" HES RN NIPPLE 17-5/8" IPC TBG-VamTop HC, 29,7#, L-80, ID = 6,875" 1--1 -7815' 1 17" TBG-TC-II, 26#, L-80, ID = 6,276" 1--1 7941' I TOP OF 7" LNR 1--1 8000' ~ II 1 9-5/8" CSG, 47#, L-80, ,0732 bpf, ID = 8,681" 1--1 8308' ~ PERFORA TION SUMI\t1A RY REF LOG: FINAL CNP ON 04/03/90 ANGLE AT TOP PERF: 15 @ 8357' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8357 -8403 0 06/02/90 3-3/8" 4 8442-8488 0 06/02/90 3-3/8" 4 8492-8691 0 06/02/90 3-3/8" 4 8697 -8720 0 06/02/90 3-3/8" 4 8726-8788 0 06/02/90 3-3/8" 4 8794-8844 0 06/02/90 3-3/8" 4 8846-8856 0 06/02/90 Z I ~ I ~ Z I \ I ~ I I I I I PBTD 1-1 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1--1 8860' 8905' ~ Top 2 joints of 13-3/8" are 68#, L-80 -2100' 1--17" CAM DB-6 NIP, ID = 6,00" I -7825' 1 I I I \ -7845' -7870' 7891' 7892' 7926' 7941' REV BY DATE REV BY COMMENTS 01/30/05 KSB/PJC FISH (WRDP-2 SSSV & RING) 07/02/05 KDCfTLH FISH PULLED DATE 04/16/90 06/03/99 11/03/01 03/25/03 04/11/03 04/30/04 RNlTP JLA/KK JRC/KK JLA/KK COMMENTS ORIGINAL COM PLETION LAST WORKOV ER CORRECTIONS CSG & SAFETY NOTE REV. CASING CORRECTION CASING CORRECTION 1--17" HES "R" NIP, ID = 5.963" 1 1--19-5/8" X 7" BKR S-3 PKR, ID = 6.0" 1--17" HES "R" NIP, ID = 5,963" 1 1- 7-5/8" BKR KBH-22 ANCHOR SEAL ASSY, ID = 6.083" 1--19-5/8" X 7" BKR SABL-3 PKR, ID = 6,0" 1 \- 6-5/8" HES RN NIP, ID = 5.5" 1 - 7" WLEG, ID = 6,313'" 1 PRUDHOE BA Y UNrr W8.L: WGI-08 PERMrr No: 1900490 API No: 50-029-22038-00 SEC 11, T11N, R14E, 17.44 FEL' & 160,03' FNL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: camille O. TaylOr Chair THRU: Tom Maunder P.i. Supervisor FROM: John Crisp Petroleum Inspector DATE: June 1, 2002 SUBJECT: Mechanical Integrity Tests BPX WGI 02,03,05 & 08 Prudhoe Bay Field Prudhoe Bay Unit NON- CONFIDENTIAL .............. P"a"cl~er DePth ....... i:;reiest 'i'niiial .... 15 Min." 30'Mi~. ' ........ TYpe inj;[' 'G ! T.V.O. !' ~75 1 TUl~in'g I "3550" ! 3550 I '~550' 1"3~S0'"l~nterVa~l 4 P.T.D. I "'1'790430 .! Type test'j '[5, I T%t.p.sil .!,.887' I'.casin'g I .,4..70 ,1,2490I '2~75I,,2470 -[' pIE Notes: · Welll ...WGI-03 LITyPel..nj..J. , G.. , I"T.':V-I~' ! 7255 'l'Tubin!;l',!. 3~'50 !' 355.',6 '1', .3.550 I' 3550' l lntervall. 4 _ _P.T.D.I 1790490 ITypetesti P- iTest pSiJ 1814 i Casinl;I I -_350 .I _.2190 .I .2175. I 2175., ! , P!E Notes: Monitored pressure for one hour to confirm stabilization. wellI "W'G'I-O5' IType"lnj. i G . I "I:.~/'.'D. I '7'~°°'" I'TUbi~g I '3550' '1' 35~0 I '! 3550' ll'nte~all P.T.D,i 190~50. _Type' test i.' P I T~t'psil ~9,~6 I~,,a,sing! 220 ! ~060-I : oo0'! 2000'i' PIF_ Notes: Monitored p.,ress,.ure for 45 minutes to confirm stabilization. '" Welli WGI-08 I.Type, lnj. I .G '"1 T..V:D. !, i;'~60 ! ~ubing J 3550 J 3550 ! '3550 I' 3550"linterVall~ 4 P.T.O.! .19~004~0 ITypetestl... P,,, ITestps.!l, .,..915 ! Casingj '4.'.00'. i, 2~_6,°_1-2550 2540 i'. pIE' Notes: Insignificant pressure loss of 20 psi. after 30 minutes. , Welli"' J Type Inj'.J ' J' 'l:.V'.O. I ' ' ' i Tubihg'l '! .......!' "1..... J lnte'r~all P.T..D..! ..i I TY.Pe.testl ..... l,Testps.i.j' __Icasing I'i -., .'-!' _ _' I 1 i-P/F ! Notes: Type INJ. Fluid Codes Type Test Internal F -- FRESH WATER tNJ. 'G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING M= Annulus'Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test during W orkover O= OUter (describe in notes) Test's Details I traveled to BP's Prudhoe Bay Field to witness MIT's on WGI Pad. WGI-03 had starting pressure of 2550 psi. The first 20 minutes of 03% test the pressure dropped from 2550 to 2320 psi. The last 10 minutes of 03's test tho pressure dropped from 2320 psi to 2190 psi. The Operator asked if I wanted to increase pressure back to 2500 psi on 03. I requested the Operator to monitor 03's test for another 30 minutes, w/o re-pressuring, to verifij stabilization. The test pressures are recorded on the test form above. I witnessed no change on 05 until I tapped on the gauge after 30 minutes. I verified stabilization by witnessing no change in 05% pressure from 30 to 45 minutes. M.I.T.'s performed. 4 Number of Failures: _.O Total Time during tests: .3. h.m. Attachments: - cc: MIT report form 5/12/00 L.G. MIT PBU WGI 06-01-02jcl.xls 614/02 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor~ DATE: August 25, 2001 Chair t. SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder JL"~P~',~ BPX P.I. Supervisor~1.~ ' YF ,-,,~1~..~-g'''''% ~"'~X NGI & WGI NGI-01& 02 WGI-01,05 & 08 FROM: Chuck Scheve PBU Petroleum Inspector Prudhoe Bay NON- CONFIDENTIAL Packer Depth Pre~est Initial 15 Min. 30 Min. . w~,I .~,-o~ 'lType,nj.I. 'e I ~.v.o. I,~ J Tubi.,I ~0 I ~ '1' ~"°' !.. ~o I,.~,1 '4 P.T.D.I 1750480 ITypetestl P IT,estpsil ~e27 I Casi~jI ~0 I 2200 I 2180 I, 2,!80, I P/F I Ii..w~,l .~,~ I~,,e'nJ-I'~ I ~-v:o-I ~..~'.~ I'u~.~l~o 'i ~"~° I'~ I ~ I'"~'1 "4.. P.T.D.I1750610 ITypetestl P ITestpsil ~a43 ICingI 0 I 2200 I 2180 I 2~00 I P/F I P I w,,I w~,~ I,,,e,nJ.I ~'I ~..v.,o'.. I ~'.~ I~u~"~l ~°0 i.~ I ~°°1 ~ l'"t~a'l ,4,, P.T.D.I 1790310 ITypetestl ,PITestmil 4843 I Caangl S20 I 2100 I 2080 I 2060 I P/F w,,I w~,~ I~e,nJ.I ~ I ~v.o. I ~ I'u~"~l ~°°1 ~ '1 '~°°1 ~ I'"~'! V ' P.T.D.I' 1900250 ITypetestl P ITestpsil 1950 I Casing. I 400 I 220O I 21601 2140 I~s: "' w,,,I w~,~ I.,,e,.J.I ~ ! f.V.o. I '~ Ifu~""l ~ ! ~°i ~°°! ~0 I,.~,1"0 ' P.T.D,I 1900490 ITypetestl p ITestpsil ~9~5 ICasi.gI 7OO. ,I 2200 I 2240'1', 224O I p/F I,,_p Netes: Annual MIT Type INJ. Fluid Codes F -- FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs NGI & WGI locations in the Prudhoe Bay field and witnessed the MIT on wells NGI-01, NGI-03, WGI-01, WGI-05 and WGI-08. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 5 wellsdemonstrating good mechanical integrity. M.I.T.'s performed: _5 Attachments: Number of Failures: 0 Total Time during tests: 4 hours CC.' MIT report form 5/12/00 L.G. MIT PBU NGI, WGI 8-25-01 CS.xls 8/30/01 19oo 90 MEMORANDUM TO:. Julia Heusser, ~-~' DATE: Commissioner Tom Maunder, P. I..Supervisor~\ THRU: State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp~ SUBJECT: Petroleum Inspector January 15, 2000 Safety Valve Tests Prudhoe Bay Field WGI Pad January 15, 2001: I traveled to BP's Prudhoe Bay Field to witness Safety Valve System testing on WGI Pad. BP representative Bill Preston was in charge of SVS tests on WGI Pad. Testing was conducted in a safe & efficient manner. Two failures were witnessed. WGI 06 surface & sub-surface valves failed to hold DP. This well was shut in until rePaired & re-tested. The AOGCC test report is attached for reference. I inspected wellhouses on WGI Pad. during SVS tests. All are clean & in good shape. SUMMARY: I witnessed SVS tests on PBU WGI Pad. 8 wells, 24components tested. 2 failures witnessed. 8.3% failure rate. 8 wellhouses inspected. Attachments: SVS PBU WGI Pad 1-15-01jc NON-CONFIDENTIAL SVS PBU WGI Pad 1-15-01jc.doc Alaska Oil and Gas ConServation CommisSion Safety Valve System Test Report Operator: BPX Submitted By: John Crisp Date: 1/15/01 Operator Rep: Bill Preston Field/Unit~ad: Prudhoe Bay Field WGI Pad AOGCC Rep: John Crisp ,, Separator psi: LPS HPS 3400 Well · Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE WGI-01 1790310 3400 2900 2440" P P P GINJ WGI-02 1~96430 3400 2900-2650 P P P GINJ WGI-03 1790490 3400''2900 2350 P P P ' GINJ, WGI-04 1790560 3400 2900 2350 P P P' GINJ WGI-05 1900250 '3400 2900 2500 P P P GINJ WaI-06 1900300 3400 2900 2460 .' P . 4 9 . GINS V~/GI-07 1900400 " 3400 2900 ' 2480 ' P ' P P GINJ wo~-08 ::i-900490 3400 29,00 26~0 'P P P, ., GINS . ,, , Wells: 8 Components: 24 Failures: 2 Failure Rate: 8.3% Elgo my Remarks: WGI-07 Shut in untill repaired & re-tested. 1/18/01 Page 1 of 1 SVS PBU WGI Pad 1-15-01jc.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE ,,OCTOBER 27, 2000 P M C:LORI~IFILM. DOC L A T T H E E E W E R IA L U N D ER IS M ARK ER MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson~r~ DATE: Chairman (3/~' THRU: Blair Wondzell, ~~ FILE NO: P. I. Supervisor ~(~.f99 FROM: John H Spaulding, ~) ~0~ SUBJECT: Petroleum I nspectoLr~~4 May 29, 1999 aerle3gf.doc BOPE Test Nabors 7ES ARCO WGI-08 Prudhoe Oil Pool PTD: 90-49 May 29, 1999' I traveled to ARCO's West Gas Injection pad well number 8 to witness the initial BOPE Test. The AOGCC BOPE Test Report is attached for reference. The rig was getting ready to pull the 7" production tubing and replace it with 7 5/8" plastic coated tubing. This new type of tubing with less friction loss will substantially increase the amount of gas that can be injected in the well. As noted there were no failures and the rig was in ~xcellent shape with all spare parts properly stowed on the pad. SUMMARY: I witnessed the BOPE Test on; Nabors 7ES, 0 failures, 4 hours Attachment: aerle3gf.xls Not confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Nabors Rig No. Operator: ARCO Well Name: WGI-08 Casing Size: Set @ Test: Initial X Weekly Other 7ES PTD # Rep.: Rig Rep.: Location: Sec. DATE: 5/29/99 90-49 Rig Ph.# 659-4831 Tom Anglen C. Henley 11 T. 11N R. 14E Meridian Umiat MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: ok Well Sign ok Upper Kelly/IBOP Housekeeping: ok (Gen) Drl. Rig ok Lower Kelly/IBOP PTD On Location ok Hazard Sec. ok ° Ball Type Standing Order Posted ok · Inside BOP BOP STACK: Quan. Annular Preventer Pipe Rams 1 Lower Pipe Rams Blind Rams 1 Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves Check Valve Test Press. P/F 25O/25OO P 250/5,000 P 250/5, 000 250/5,000 P 250/5,000 250/5,000 250/5,000 250/5,000 1 MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok Test Quan. Pressure P/F I 250/5, 000 p 250/5, 000 p 250/5, 000 p 250/5,000 P CHOKE MANIFOLD: No. Valves 14 No. Flanges 33 Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 250/5, 000 P 250/5,000 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2250 avg. 2,950 I P 1,800 p minutes 28 sec. minutes 35 sec. x Remote: x Psig. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves testecl 20 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to tl~e AOGCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659.3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev. 12/94) aede3gf. XLS ; ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: E~ Operation Shutdown r--1 Stimulate I-] Plugging i--] Perforate [] Pull Tubing E~] Alter Casing [--1 Repair Well I--] Other 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 963' SNL, 1060' WEL, SEC. 11, T11N, R14E, UM At top of productive interval 207' SNL, 139' WEL, SEC. 11, T11N, R14E, UM At effective depth 165' SNL, 32' WEL, SEC. 11, T11N, R14E, UM At total depth 160' SNL, 22' WEL, SEC. 11, T11N, R14E, UM Type of well: [--I Development [--I Exploratory F-I Stratigraphic I~ Service 6. Datum Elevation (DF or KB) RKB - 60' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number WGI-08 9. Permit Number / Approval No. 90-49 399-082 10. APINumber 50-029-22038 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 8907 fee{ Plugs (measured) 8635 feet 8860 feet Junk (measured) 8589 feet Length Size Cemented MD TVD Structural Conductor 110' 20" 2150# Poleset 110' 110' Surface 3481' 13-3/8" 2200 sx AS III, 650 sx 'G', 107 sx AS I 3481' 3481' Intermediate Production 8308' 9-5/8" 650 sx Class 'G', 325 sx CS I 8308' 8057' Liner 905' 7" 266 sx Class 'G' 8000' - 8905' 7761' - 8633' Perforation depth: measured 8357' - 8856' (seven intervals) true vertical 8104' - 8585' Tubing (size, grade, and measured depth) 7" x 7-5/8", 26# / 29.7#, L-80 to 7941' Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker 'SABL-3' packer at 7892'; 7" Camco 'BaI-O' SVLN Nipple at 2213' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure JUN -9 1999 N~ 011 & Gas Cons. ~mmlssion Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments I--I Copies of Logs and Surveys run [~ Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //,~ ~..~ ~. _ __ -.. Terrie Hubble ~_ Title Technical Assistant III Prepared By Name/Number: I16. Status of well classifications as: I--] Oil I-~ Gas i--1 Suspended Service Gas Injection Date Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility WGI Well WGI-08 Rig Nabors 7ES Page 1 Date 08 June 99 Date/Time 28 May 99 00:01-02:00 02:00-02:30 02:30-04:00 04:00-06:00 06:00-18:30 18:30-20:30 20:30-22:00 22:00-23:00 23:00-04:00 29 May 99 04:00-05:00 05:00-06:00 06:00-06:30 06:30-10:30 10:30-15:00 15:00-16:30 16:30-18:00 18:00-19:00 19:00-20:00 20:00-21:30 21:30-22:30 22:30-00:00 30 May 99 00:00-01:45 01:45-02:00 02:00-03:30 03:30-04:45 04:45-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-11:00 11:00-11:30 11:30-17:30 17:30-17:45 17:45-18:30 18:30-19:00 19:00-19:30 19:30-21:30 21:30-04:00 31 May 99 04:00-04:30 04:30-06:00 06:00-06:15 06:15-10:00 10:00-11:30 11:30-12:00 12:00-14:00 14:00-18:30 18:30-21:00 21:00-22:00 22:00-01:00 01 Jun 99 01:00-02:30 02:30-06:00 06:00-14:30 14:30-20:00 Duration 1-3/4 hr 1/2 hr 1-1/2 hr 2 hr 12-1/2 hr 2 hr 1-1/2 hr lhr 5hr lhr lhr 1/2 hr 4hr 4-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr lhr 1-1/2 hr 1 hr 1-1/2 hr 1-3/4 hr 1/4 hr 1-1/2 hr 1-1/4 hr 1/4 hr 1 hr 1/2 hr lhr 1/2 hr 3 hr 1/2 hr 6 hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 2hr 6-1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 3-3/4 hr 1-1/2 hr 1/2 hr 2 hr 4-1/2 hr 2-1/2 hr 1 hr 3 hr 1-1/2 hr 3-1/2 hr 8-1/2 hr 5-1/2 hr Activity Rigged down Drillfloor / Derrick Rig moved 5.00 % Serviced Drillstring handling equipment Rig moved 15.00 % Rig moved 100.00 % (cont...) Fill pits with Brine Removed Hanger plug Held safety meeting Reverse circulated at 7984.9 ft Installed Hanger plug Rigged down Xmas tree Rigged down Xmas tree (cont...) Rigged up BOP stack Tested BOP stack Removed Hanger plug Retrieved Locator seal assembly Circulated at 7977.9 ft Laid down 160.0 ft of Tubing Installed Retrievable packer Rigged down BOP stack Removed Tubing head spool Installed Tubing head spool Tested Tubing head spool Rigged up BOP stack Tested BOP stack Removed BOP test plug assembly Retrieved Retrievable packer Retrieved Retrievable packer Circulated at 7790.0 ft Rigged up Completion string handling equipment Laid down 2060.0 ft of Tubing Rigged down Completion string handling equipment Laid down 5741.0 ft of Tubing Rigged down Wear bushing Rigged up Top ram Tested Top ram Installed Wear bushing Made up BHA no. 1 Singled in drill pipe to 7935.0 ft Serviced Block line Circulated at 7935.0 ft Circulated at 7935.0 ft (cont...) Milled Packer & tailpipe assembly at 7955.0 ft Circulated at 7959.0 ft Worked toolstring at 7995.0 ft Circulated at 7960.0 ft Pulled out of hole to 344.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 8027.0 ft Circulated at 7990.0 ft Circulated at 7990.0 ft Circulated at 7990.0 ft (cont...) Laid down 7646.0 ft of 4in OD drill pipe Facility WGI Progress Report Well WGI-08 Page 2 Rig Nabors 7ES Date 08 June 99 Date/Time 02 Jun 99 03 Jun 99 20:00-21:30 21:30-22:30 22:30-23:00 23:00-23:15 23:15-23:30 23:30-01:30 01:30-02:00 02:00-03:30 03:30-05:00 05:00-06:00 06:00-16:30 16:30-17:30 17:30-01:00 01:00-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-07:15 07:15-08:30 08:30-10:00 10:00-13:15 13:15-14:00 14:00-15:00 Duration 1-1/2 hr 1 hr 1/2 hr 1/4 hr 1/4 hr 2 hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 10-1/2 hr lhr 7-1/2 hr 2 hr 1-1/2 hr 1 hr 1/2 hr 1/4 hr 1/4 hr 3/4 hr 1-1/4 hr 1-1/2 hr 3-1/4 hr 3/4 hr lhr Activity Pulled BHA Rigged up Top ram Rigged down Wear bushing Tested Top ram Rigged down BOP test plug assembly Rigged up Completion string handling equipment Held safety meeting Ran Tubing to 50.0 ft (7-5/8in OD) Repaired Completion string handling equipment Ran Tubing to 7in (300.0 ft OD) Ran Tubing to 5727.0 ft (7-5/8in OD) (cont...) Installed SCSSSV nipple assembly Ran Tubing to 7941.0 ft (7-5/8in OD) Circulated at 7941.0 ft Functioned Hydraulic packer Tested Tubing - Via annulus and string Retrieved Tubing landing string Retrieved Tubing landing string (cont...) Rigged up Hanger plug Rigged up Top ram Rigged down BOP stack Installed Adapter spool Installed Xmas tree Tested Xmas tree Rigged down Surface lines Re: NGI-05 Status Subject: Re: NGI-05 Status Date: Mon, 17 May 1999 15:12:01 -0900 From: "PRB Problem Wells" To: Blair_Wondzell~admin. state.ak.us Here are Jerry's comments. Looks like plastic coating adds about 50 MMD injection, 5/8" adds 50 MMD. Joe Forwarded by PRB Problem Wells/AAI/ARCO on 05/17/99 03:16 Jerry L Brady 05/17/99 03:15 PM To: PRB Problem Wells/AAI/ARCO@ARCO cc: Von Cawvey/AAI/ARCO@ARCO Subject: Re: NGI-05 Status (Document link not converted) Joe, The only reason for the plastic coating is to reduce the friction losses which will result in a higher injection rate. Plastic coating should add about 50 MMSCFPD and the larger pipe will add about another 50 MMSCFPD. Therefore, the injection rate on NGI-05 should increase by about 100 MMSCFPD since we have both larger pipe and the current pipe is not plastic coated. WGI-08 already has plastic coated pipe, but increasing the pipe from 7" to 7-5/8" should increase the injection by about 50 MMSCFPD. Jerry 05/17/99 12:11 PM PRB Problem Wells PRB Problem Wells PRB Problem Wells 05/17/99 12:11 PM 05/17/99 12:11 PM To: Blair Wondzell <Blair Wondzell@admin. state, ak.us> -- cc: Jerry L Brady/AAI/ARCO@ARCO Subject: Re: NGI-05 Status (Document link not converted) Hi Blair. I've copied Jerry Brady on this note - he is the Engineer who did the calculations on injectivity enhancement expected form the larger plastic coated tubing. Jerry, would you please address Blair's questions below. We are planning on running nipples with surface control lines into both wells. Thanks! Joe Blair Wondzell <Blair_Wondzell@admin.state.ak.us> on 05/17/99 10:39:02 AM To: PRB Problem Wells/AAI/ARCO cc: Subject: Re: NGI-05 Status Hi Joe, Thanks for the info on WGI-8 and NGI-5. You've peaked my curosity as to why the need for the plastic coated tubing. Also, will yOu be running downhole safety valves or the nipples 1 of 2 5/17/99 4:06 P~e: NGI-05 Status back in the wells? What rates do you expect into these wells after equiping them with the larger plastic coated tubing? Thanks for your help. Blair, 5/17/99. PRB Problem Wells wrote': > > Hello Blair. This note is to inform you of the mechanical condition of well > NGI-05. NGI-05 is currently injecting 140 F~fCFD gas at 3500 psi. > > NGI-05 is scheduled for a RWO (starting around 6/15/99) to mitigate Tubing x > 9-5/8" communication problems, install larger tubing and increase well injection > rates. Notes on the well condition: > > - A Tubing x 9-5/8" leak occurs when the SSSV is pulled for replacement. > Diagnostics indicate the balance line has parted, allowing gas to enter the > Tubing x 9-5/8" annulus. Also, the sealing area for the SSSV packing elements is > apparently damaged. This has resulted in the SSSV being replaced three times so > far this year. Currently, the 9-5/8" pressure is stable at 1625 psi. > > - MIT's on the 9-5/8" conducted 3/3/97 and 3/16/97 indicate it is competent to > liquid. > > - The 13-3/8" appears competent and does not track the 9-5/8" pressure. > > The rig is planning to pull the tubing and run new 7-5/8" plastic coated tubing. > The Drilling Department is preparing the sundry application. > > Please call if you have any questions. > > Joe Anders > Problem Well Specialist > 659-5102 2 of 2 5/17/99 4:06 PM Re: NGI-05 Status Subject: Re: NGI-05 Status Date: Mon, 17 May 1999 12:11:01 -0900 From: "PRB Problem Wells" T o: B lair Wondzell CC: "Jerry L Brady" <JLBRADY~mail.aai.arco.com> Hi Blair. I've copied Jerry Brady on this note - he is the Engineer who did the calculations on injectivity enhancement expected form the larger plastic coated tubing. Jerry, would you please address Blair's questions below. We are planning on running nipples with surface control lines into both wells. Thanks! Joe Blair Wondzell <Blair Wondzell@admin.state.ak.us> on 05/17/99 10:39:02 AM To: PRB Problem Wells/AAI/ARCO cc: Subject: Re: NGI-05 Status Hi Joe, Thanks for the info on WGI-8 and NGI-5. You've peaked my curosity as to why the need for the plastic coated tubing. Also, will you be running downhole safety valves or the nipples back in the wells? What rates do you expect into these wells after equiping them with the larger plastic coated tubing? Thanks for your help. Blair, 5/17/99. PRB Problem Wells wrote: > Hello Blair. This note is to inform you of the mechanical condition of well > NGI-05. NGI-05 is currently injecting 140 M~CFD gas at 3500 psi. > > NGI-05 is scheduled for a RWO (starting around 6/15/99) to mitigate Tubing x > 9-5/8" communication problems, install larger tubing and increase well injection > rates. Notes on the well condition: > > - A Tubing x 9-5/8" leak occurs when the SSSV is pulled for replacement. > Diagnostics indicate the balance line has parted, allowing gas to enter the > Tubing x 9-5/8" annulus. Also, the sealing area for the SSSV packing elements is > apparently damaged. This has resulted in the SSSV being replaced three times so > far this year. Currently, the 9-5/8" pressure is stable at 1625 psi. > - MIT's on the 9-5/8" conducted 3/3/97 and 3/16/97 indicate it is competent to > liquid. > > - The 13-3/8" appears competent and does not track the 9-5/8" pressure. > The rig is planning to pull the tubing and run new 7-5/8" plastic coated tubing. > The Drilling Department is preparing the sundry application. > Please call if you have any questions. > Joe Anders 1 of 2 5/17/99 4:04 PM WGI-08 Subject: WGI-08 Date: Sun, 16 May 1999 13:29:29 -0900 From: "PRB Problem Wells" T o: B lair_Wondze ll~admin, state, ak.us Hello Blair. This note is to follow-up on our 5/13/99 phone conversation regarding well WGI-08. WGI-08 is scheduled for a RWO (starting around 5/20/99) to mitigate Tubing x 9-5/8" communication problems, install larger tubing and increase well injection rates. Notes on the well condition: - The 13-3/8" is competent to liquid - it was successfully pressure tested to 2000 psi on 12/1/98. MIT's on the 9-5/8" conducted 5/15/99 and 6/13/97 indicate it is also competent to liquid. - A Tubing x 9-5/8" leak occurs when the SSSV is pulled for replacement. Diagnostics indicate the balance line has parted, allowing gas to enter the Tubing x 9-5/8" annulus. Also, the sealing area for the SSSV packing elements is apparently damaged. This has resulted in the SSSV being replaced three times so far this year. Currently, the 9-5/8" pressure is stable at 700 psi, a 3000 psi difference between the Tubing and 9-5/8" pressures. - The 13-3/8" pressure slowly tracks the 9-5/8" and the leak is thought to be downhole. We have done extensive troubleshooting and the wellhead appears to be competent. When bled down, the 13-3/8" will equalize with the 9-5/8" in 2-4 days. The rig is planning to pull the tubing, replace the 9-5/8" hanger seals, and run new larger plastic coated tubing. Please call if you have any questions. Joe Anders Problem Well Specialist 659-5102 1 of 1 5/18/99 8:02 AM Repair Ibg x IA Communication in WGI-8'~'x~ Subject: Repair Tbg x IA Communication in WGI-8 Date: Wed, 12 May 1999 1'1:56:52 -0800 From: B lair Wondzell Organization: SOA-AOGCC To: "Hubble, Terrie L (NANA)" <HubbleTL@BP.com> Hi Terry, This morning I received a 10-403 on PBU well WGI-8 to repair the tubing because of Tbg x IA communication. The "Estimated date for commencing operation" is listed as "May 15, 1999. I opened my MIT records and noticed that there is no record of communication or other problem with WGI-8. The last entry is a passing MIT on 6/13/97, witnessed by the operator. Two possibilities come to mind: 1. This is a very recent happening; the well is such an important injection well that the 403 to repair it beat the MIT reporting the failure, 2. The failure occurred some time in the past and because of: A. negligence, we were not notified of the failure, or B. a deliberate attempt to deceive us, we were not notified. Terry, I know that the lack of notification was not your doing, I'm only using you for the messenger. Pass on that we want answers to the above concerns before we evaluate the 403. Sincerely, Blair Wondzell, 5/12/99. 90 1 of 1 5/18/99 7:55 AM STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend d Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate [] Other 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 963' SNL, 1060' WEL, SEC. 11, T11 N, R14E, UM At top of productive interval 207' SNL, 139' WEL, SEC. 11, T11N, R14E, UM At effective depth 165' SNL, 32' WEL, SEC. 11, T11N, R14E, UM At total depth 160' SNL, 22' WEL, SEC. 11, T11 N, R14E, UM 5. Type of well: I--I Development [] Exploratory [-] Stratigraphic [~ Service 6. Datum Elevation (DF or KB) RKB - 60' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number WGI-08 9. Permit Number 90-49 10. APl Number 50-029-22038 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 8907 feet true vertical 8635 feet Effective depth: measured 8860 feet true vertical 8589 feet Casing Length Size Structural Conductor 110' 20" Surface 3481' 13-3/8" Intermediate Production 8308' 9-5/8" Liner 905' 7" Plugs (measured) Junk (measured) Cemented 2150# Poleset 2200 sx AS III, 650 sx 'G', 107 sx AS I 650 sx Class 'G', 325 sx CS I 266 sx Class 'G' MD TVD 110' 110' 3481' 3481' 8308' 8057' 8000'-8905' 7761'-8633' Perforation depth: measured true vertical 8357' - 8856' (seven intervals) 8104' - 8585' ORIGINAL Tubing (size, grade, and measured depth) 7" x 5-1/2" x 4-1/2", 26#/17#/12.6#, L-80 to 8026' Packers and SSSV (type and measured depth) RECEIVED t, IAY 2 99,9 Alaska Oil & Gas Cons. C0mm/ssi0~ Anchorage 9-5/8" Baker FB-1 packer at 7961 ', Camco BaI-O SSSV at 2221' 13. Attachments Description summary of proposal i--I Detailed operations program ~-I BOP sketch 14. Estimated date for commencing operation May 15, 1999 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Bill Isaacson, 564-5521 Date approved 15. Status of well classifications as: [--] Oil I-] Gas I--I Suspended Service Gas Injection Prepared By Name/Numbec Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~_.....~.._ .~. ~ Dan Stone Title Senior Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative ma~witness ].Approval No.,.~ Plug integrity BOP Test ~ Location clearance__ ' ......... Mechanical Integrity Test f Subsequent form required 10- ORIGINAL SIGNED BY .~Cp~'' Approved by order of the Commission Robert N. Chdstenson ,,o-~ev.~_ C/bJj Commissioner Form 10-403 Rev. 06/15/88 D ate._~/~'"--/~'.- ? ~ Submit In Triplicate . .ka ared rvices rilling To: From: Subject: Reference: BP Exploration / ARCO Alaska Inc. Blair Wondzell - AOGCC Date: May 11, 1999 William Isaacson WGI-08 Application for Sundry Permit - Rig Workover Operations APl #50-029-22038 The WGI-08 rig workover is currently scheduled for Nabors 7ES following the workover operations on well 6-18. Pre-rig work for the workover is planned to begin May 15th and workover operations are estimated to begin around May 22nd. Objective WGI-08 has tubing x inner annulus communication, which appears to be the SSSV nipple. The balance line is leaking, and multiple attempts at sealing with various packing configurations have been unsuccessful. The Wells Group has done all they can do to mitigate and/or repair the annular communication problem on this well to bring the well into compliance with Operating Guidelines. Over the last six months the bleed frequency has increased .to the point the well operates at the limit of our allowed guidelines. If this well is not worked over and the tubing x inner annulus communication repaired, we will be forced to shut the well in. Scope Pre-Rig Work: 1. Test the 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 2. RU slickline. Pull wire-line retrievable SSSV from BaI-O SSSV nipple at 2221' MD. 3. RU pump trucks. Bullhead 2% KCI water down tubing to perforations to load tubing. Liquid pack the 9-5/8" by lubricating in diesel and bleeding of gas as required. 4. RU slickline. RIH and set plug in 'XN' nipple (3.725" No-Go) in tailpipe at 8013'. Simultaneously pressure both the tubing and annulus to 4000 psi for 30 minute test. Bleed off pressure and pull plug from 'XN' nipple. 5. RU pump trucks. Bullhead sized salt pill down to perforations to serve as lost circulation pill for upcoming workover operations. Follow the same procedure used to spot the salt pills on the WGI-1, 3, and 4 workovers. - 50 bbls of 10 ppg NaCl saturated hi-vis spacer - Sized salt pill in saturated NaCt brine -12.0 ppg (volume as required) - 40 bbls of 10 ppg NaCI saturated hi-vis spacer - Displace sized salt pill with 9.5 ppg NaCl brine Slow pump rate as hi-vis spacer and salt pill hit the perforations and pump only as required to adequately place sized salt pill in perforations. Don not fracture formation. Shut down and allow salt pill to leak-off to formation and settle out, isolating perforations. 6. RU slickline. Drift tubing for upcoming E-line work and tag top of sized salt pill. WGI-08 RWO Sundry 7. RU E-line. RIH and perforate 4-1/2" tubing tail at -7985' MD (1' at 4spf). These perforations will be needed to remove any trapped gas from behind tubing tail, which could otherwise be exposed while milling the packer. RIH and perforate 5-1/2" tubing pup immediately above 9-5/8" packer at -7957' MD (1' at 4 spf). Tubing will not be cut. 8. RU pump trucks. Circulate annulus to 9.5 ppg NaCI brine by circulating down tubing and up annulus through perf holes in tubing. Continue to circulate until clean 9.5 ppg brine returns to surface. 9. Set a BPV in the tubing hanger and test to 500 psi. Secure the well. 10. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Rig 1. 2. 3. 4. Estimated Pre-rig Start Date: Estimated RWO Start Date: Operations: MIRU Nabors 7ES. Pull BPV. Circulate well with 9.5 ppg brine and verify well is dead and stable. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. Screw into tubing hanger. PU on completion assembly and pull seals from seal bore below production packer. Pull hanger to floor and circulate bottoms up to verify the well is dead. 5. POOH laying down the 7"x 5-1/2" completion through seal assembly. (If tubing can not be pulled, tubing will be cut above permanent packer.) 6. PU packer milling assembly and RIH. Mill packer and push to top of liner. 7. PU fishing assembly and RIH to packer. Engage packer and POOH slowly with packer and tailpipe assembly. 8. PU 6" bit on cleanout assembly with 9-5/8" casing scrapper. RIH with bit to top of sized salt pill and casing scraper to liner top. POOH 9. If necessary, PU 9-5/8" RTTS and RIH to liner top. Set RTTS and test 9-5/8" casing to 4000 psi for 30 minutes. POOH LD DP. 10. Run new 7-5/8" L-80 STL IPC completion with new 9-5/8" x 7" production packer. The tubing tail of the new completion will tie into the 7" liner tie-back sleeve. 11. Displace annulus to 9.5 ppg brine with corrosion inhibitor and freeze protect annulus to -2200' MD. Set packer and test the tubing to 4000 psi for 30 minutes. Test annulus to 4000 psi for 30 minutes. 12. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 13. Secure the well and rig down and move off. 14. Post rig work will clean out the sized salt pill from across the perforations. 05/15/99 05/22/99 William Isaacson Operations Drilling Engineer 564-5521 WGI-08 RWO Sundry Tree: 7-1/16" - 5M ClW L-80 Wellhead: McEvoy Gen IV 13-5/8" x 5M psi WGI-08 Proposed Completion RKB = 60' K. 7" 5M psi McEvoy Tubing Hanger with crossover pup to 7-5/8" STL tubing. J. 7-5/8" 29# L-80, STL Tubing.to surface with two control lines strapped to tubing. I. 7" Camco BAL-O SSSV Ported Landing Nipple with 5.937" seal bore ID set at ~2000'. Equipped with crossover handling pups to crossover to 7-5/8" STL tubing. 13-3/8", 68 #, L-80, BTC I 3,481' H. 7-5/8" 29# L-80, STL Tubing. 7" LinerTop at: I 8,000' Baker Tie Back Sleeve Baker Liner Hanger ~ 9-5/8", 47 #, L-80, BTC-Mod I 8,aox' I 7", 29 #, L-80, BTC I 8,905' G. 9-5/8" x 7" Baker 'S-3' Production Packer. Equipped with 10' handling pups above and below packer with crossover to 7-5/8" STL on top pup. F. 10' x 7" L-80 pup joint. E. 6-5/8" Halliburton 'R' Landing Nipple with 5.625" selective seal bore (7" NSCT threads). D. 20' x 7" L-80 pup joint. C. 6-5/8" Halliburton 'RN' Landing Nipple with 5.625" seal bore / 5.50" No-Go (7" NSCT threads). B. 10' x 7" L-80 pup joint. A. 5' x 7" L-80 cut-off pup with OD and ID of cut-off end beveled. Tubing tail spaced out into tie back sleeve (7.50" ID). PBTD I 8,860' Total Depth [ 8,907' Date 5/11/99 Rev By WSI Comments Proposed Completion Prudhoe Bay Unit WELL: WGI-08 APl NO: 50-029-22038 Shared Services Drilling Alaska hared ervlces rilling WELL NAME WGI-08 DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category oer cover sheet) DRILLING PERMIT D Permit Documentation Prepared: ODE: Date: D Permit Application Reviewed: SDE/ES: Date: D Permit Application Submitted: TA: Date: PRE-RIG WORK Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date: I~'] SUNDRY NOTICE ~/~ql Sundry Document.a, tion Prepared: ODE:'P'~' k. ~ ........ Date: ~"11'~[~[ I~ Sundry Application Reviewed: ~ SundryA~. pplicat,ion~,u, bmitted: ' ~ TA: ~./~ ~~ Date: '~' t2.~ ~ NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that aooly) Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate APPROVAL TO PROCEED Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: ~"'-', STATE OF ALASKA ,/'~ ,--,_ ,SKA OIL AND GAS CONSERVATION COMMISSION L,,,-r ~. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well GAS INJECTOR OIL ~ GAS r-~ SUSPENDED r-'"] ABANDONED r'~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-49 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22038 4 Location of well at surface 9 Unit or Lease Name 963' FNL, 1060' FEL, SEC 11, T11N, R14E UM '~~ .... PRUDHOE BAY UNIT ~.T~O~,; ! ~ ~]F~[~ ~ 10 Well Numar At Top Producing ,nte~a, j ~ 0~T~, j 207' FNL, 139' FEL, SEC 11 T11N, R14E UM ~ ~ 11 Field a~ Pool At Total Depth ~IFt~D ~ , 160'FNL, 22'FEL, SEC 11, T11 N, R14E UM · - ~71 PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 L~se Designation and Serial ~. PRUDHOE BAY OIL POOL RKB 60'~ ADL 28302 ALK 2313 12 Date Spudd~ 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ] 15 Water Dep~, if offshore ~ 16 No. of Completions 04/03/90. 04/13190. 06/03/90*~ N/A feet MSL~ 1 17 To~l Dep~ (MD+~D) 18 Plug Back Depth (MD+TVD) 19 Dir~tional Su~ey ~20 Depth where SSSV set ~ 21 Thickness of permafrost 8907' MD/8635' TVD 8860' MD/8589' TVD YES ~ ~ ~~ 2222' f~t MD~ 1900' (approx) 22 Ty~ El~tric or Other Logs Run GR/CCUCET/CBT, GOT 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP ~ ~LE SIZE CEME~ING RECORD AMOUNT PULLED 20" 91.5~ H-40 SURF 110' 30" 2150~ POLESET 13-3/8" 68.0~ L-80/K-55 SURF 3481' 17-1/2" 2200 SX AS III & 650 SX C~SS G TOP JOB W/107 SX AS I 9-5/8" 47.0~ L-80 SURF 8308' 12-1/4" 650 SX C~SS G & 325 SX CS I 7" 29.0~ L-80 8000' 8905' 8-1/2" 266 SX C~SS G 24 Perorations open to Production (MD+~D of Top a~ BoEom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7" / 4-1/2" 8026' 7961' PERFORATED W/4 SPF: 8349'-8395'MD/8097'-8141'TVD 8435'-8481'MD/8180'-8224'TVD 26 ACID, FRACTURE, CEME~ SQUEEZE, ETC 8485'-8684'MD/8228'-8420'TVD DEPTH I~ERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8690'-8713'MD/8425'-8448'TVD N/A 8720'-8782'MD/8454'-8515'TVD 8789'-8839'MD/8521 '-8570'TVD 8841 '-8851 'MD/8571 '-8581 'TVD 27 N/A PRODUCTDN TEST Date First Production ~Method of O~ration (Flowing, gas li~ etc.) I Date of Test Hours Test~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAV~Y-API (corr) iPress. 24-~UR RATE ~ 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent di~ and presence of oil, gas or water. Submit core chips. · NOTE: DRILLED RR 4/16/90. TUBING RUN 5/25/~. PERFORATED WELL 6/20/90. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, ME,AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 8433' 8178' BASE SADLEROCHIT 8888' 8616' NONE 31. LIST OF ATTACHMENTS WELL HISTORIES {DRILL & COMPLETE), GYROSCOPIC SURVEYS {2 COPIES), & ADDENDUMS (SIGNED 4/27/90 & 6/20/90) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ! Signed ~{~,/~ ~ ~ Title DRILLING ANALYST Date ~/~ ~-. ¢)~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 WELL HISTORY ADDENDUM WELL WORK LOG Well # WGI-8 Work performed: INITIAL PERFORATIONS Cost: ~.{Z,_4..0.Z.J~ Date: 6/2/90-6/3/90 AFE: AS3021 Time Summary O73O 1400 1 545 RIH w/ 1 730 RIH w/ 1 905 RIH w/ 2035 RIH w/ 221 0 RIH w/ 2345 RIH w/ 01 1 0 RIH w/ 0240 RIH w/ O41 5 RIH w/ 0555 RIH w/ 073O RIH w/ 0905 RIH w/ 1 O45 RIH w/ 1 220 RIH w/ 1355 RU SWS to perf using hyper jet II, 4 spf, 60°/120° phasing RIH w/gun #1, shoot f/ 8819-8839. POH, all shots fired. gun #2, shoot f/ 8841-8851, 8799-8819. POH;. asf. gun #3, shoot f/ 8789-8799, 876'2-8782. POH, asf. gun #4, shoot f/ 8752-8762, 8732-8752. POH, all shots fired. gun #5, shoot f/ 8727-8732, 8707-8713, 8720-8727. POH, asf. gun #6, shoot f/ 8690-8707, 8674-8684. POH, all but one shot fired. gun gun gun gun gun gun gun gun gun gun #7, shoot f/ 8664-8674, 8644-8664. POH, all shots fired. #8, shoot f/ 8624-8644. POH, all shots fired. DRILLING SUPERINTENDENT RIH w/ Pump 75 bbls 60/40 meth/wtr. Summary: 8841-8851 8789-8839 8720-8782 8690-8713 8485-8684 8435-8481 8349-8395 #9, shoot f/ 8614-8624, 8594-8614. #10, shoot f/ 8584-8594, 8564-8584. #11, shoot f/ 8554-8564, 8534-8554. #12, shoot f/ 8524-8534, 8504-8524. #13, shoot f/ 8485-8504, 8471-8481. #14, shoot f/ 8461-8471, 8441-8461. #15, shoot f/ 8435-8441, 8375-8395. #16, shoot f/ 8365-8375, 8349-8365. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. Freeze protect WHP=1020. Perforated all w/ 4 spf Well secured. ADDENDUM DALLY DRILLING REPORT Well # WGI-8 Date: 4/22/90 Work performed: Cost: AFE: AS3021 Summary RU, Ran CET, CBT, GR, CCL w/0 & 1000 psi f/8852'-6900' Log interpretation: Bonding was good throughout 7"csg & liner lap. 9-5/8" csg showed very poor cmt bond throughout GCT correlated w/MWD DRILLING SUPERINTENDENT ARCO ~,, and Gas Company Well History - Initial Report - Daily Inab~ctiOlla: DistHct Field ^uth. or W.O. hO.AS3021 API: 50-029-22038 first Wednesday after a well is spudded or workover operations are started. Prepare told sablttit~.~'_'~;~' on the Daily worR ptiQ~[~: . automatized on the form giving inclusive dates only. I County. pariah or b~%H SLOPS ARC . . :.~_:, .... P~JJDHOE ]~lt.y ?~;'~ ILeese or Unit 3J3L: 28302 I Title CO1%~ LETE State AK Iwe, ~GI-8 Operator ARCO Spudded or W.O.i~j~pT ]Date 05/23/90 ]Hour Date and depth aa of 8:00 a.m. 05/24/90 ( Complete record 16) I ARCO W.L 21.0000 1800 Has Iprior status if a w.o. MU BAKER 9-5/8" FB-1 PKR 7"@ 8905' MW: 9.2 NaCl ACCEPT RIG @ 1800 HRS, 5/23/90. ND TREE. NU BOPE. TEST BOPE. DISPLACE 600' DIESEL CAP. RU ATLAS WL. RIH W/8.5" GR/JB/CC~ WELLBORE~LEAN. MU BAKER 9-5/8" X 5-1/2" FB-1 PERMANENT PACKER AND TAILPIPE ASSEMBLY. DAILY:S26,206 CUM:$1,626,715 ETD:S1,626,715 EFC:$2,699,000 TD: 0 PB: 8860 SUPV:RWO 05/25/90 ( TD: 0 PB: 8860 SUPV:RWO 17) The ?ova I~correot ~ ~l p~[epa a{Ion and dletr~utlon, -- see Proceddms Manual, Section 10, Drilling, Pages 86 and 87. DISP 9.2 W/8.5 INHIB FSW 7"@ 8905' MW: 9.2 NaCl RIH AND SET 9-5/8" X 5-1/2" BAKER FB-1 PERMANENT PACKER AT 7961' ELM. TEST CSG TO 4000 PSI. OK. RIH W/7" COMPLETION ASSEMBLY. DISPLACE OUT 9.2 PPG NACL W/8.5 PPG INHIBITED SEAWATER. NOTE: CAMCO 'BAL-0' SSSV @ 2222', BAKER 'FB-I' @ 7961', & TT @ 8026'. DAILY:S265,973 CUM:$1,892,688 ETD:S1,892,688 EFC:$2,699,000 Drilling Supt. AR3B-459-1-D INumber all daily well history forms consecutively las they are prepared for each well. I Page no. ARCO ,.,il and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the~"?il[l~m...l~. ~e~O.~ ~" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Repo~t" should be SUbmitted ~~t'allond are Suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, rel~3rt ~~~1~ reprea~rltatlve test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available.. :~-'?'~'~.~'i. District Field ARCO ALASKA INC.. ICounty or Parish NORTH SLOPE Lease or Unit ADL: 28302 Title COMP LETE IAccounting cost center code State AK Well no. WGI-8 PRUDHOE BAY Auth. or W.O. no. A83021 API: 50-029-22038 Operator ARCO IA.R.Co. W.L 21. 0000 Spudded or W.O. ~(~EPT [Date 05/23/90 05/26/90 ( TD: 0 PB: 8860 SUPV:RWO Completerecordforeachdayr~§dNABORS Date and depth as of 8:00 a.m. I otal number of wells (active or inactive) on this est center prior to plugging and ~ bandonment of this well J our 1800 HRS IPrior status if a w.o. 18) RELEASE RIG 7"@ 8905' MW~ 8.5 Seawater DISPLACE WELL W/8.5 PPG SEAWATE~ INHIBITED WITH C-193. FREEZE PROTECT TOP 2200' OF WELL W/6.8 PPG INHIBITED DIESEL. LAND 7" TUBING HANGER. PRESSURE TEST TUBING AND ANNULUS SEPARATELY TO 4000 PSI. TEST WITNESSED BY AOGCC. LD LANDING JOINT. SET BPV, ND BOPS, NU TREE. TEST TREE TO 5000 PSI. PRESS TBG TO 4400 PSI TO SHEAR SUB IN TAILPIPE. SET BPV. RD, RELEASE RIG @ 1900 HRS, 5/25/90. DAILY:S118,381 CUM:$2,011,069 ETD:S2,400,000 EFC:$2,310,069 Old TD I New TD I PB Depth Released rig J Date IKInd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Off c a reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size ¥.P. C.P. Water % GOR Gravity Allowable Effective date corrected Signature~. _ ~ D · Title k. nHIItnn R, mt For form prep~lrati°n and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history form! consecutively as they are prepared for each well. iPage no. DIvIIdo~ of AtlantlcRIchfl~ldCompm~y ARCO c,.. and Gas Company Well History - Initial Report - Daily Instnlctiona: Prepare and submit the "Initial Rel~rl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Sl~tdding should be summarized on the form giving inclusive dates only. District ARCO ALASKA Field PRUDHOE BAY* Auth, or W.O. nOAS3021 ICounty, parish or borough NORTH SLOPE ILease or Unit ADL: 28297 Title DRILL IState AK lWal, ~GI- 8 API: 50-029-21996 Operator ARCO Spudded or W.O.~J~j~J~) Date and depth as of 8:00 a.m. 04/03/90 ( TD: 294'( SUPV:DBJ 04/04/90 ( TD: 1833'( SUPV:DBJ 04/05/90 ( TD: 3500'( SUPV:DBJ 04/06/90 ( TD: 3500'( SUPV:DBJ 04/07/90 TD: 4433'( SUPV:DBJ 04/08/90 ( TD: 5842'( SUPV:DBJ 04/09/90 ( TD: 6762'( SUPV:DBJ JDate 04/03/90 J,our o4oo HRS Complete ..... d fojf)~)~t~;~y ~ported 1) 294) 2) .539) IAF~CO W I. 21.0000 Prior status if a W.O. 3) L667) 4) O) 5) 933) 6) .409) 7) 920) DRLG MW: 0.0 VIS: 0 ACCEPT RIG @ 2100 HRS, 4/2/90. NU ANN & DIV. MU BIT. SPUD WELL @ 0400 HRS, 04/03/90. DRILLED TO 294'. DAILY:S47,250 CUM:$47,250 ETD:S200,000 EFC:$2,546,250 DRLG MW: 9.4 VIS:300 DRLG TO 425', RECIPROCATE PIPE, CUTTINGS BOX PLUGGED, DRLG TO 539, CBV, SET KELLY BACK, POH, L/D 3 JTS HW, CHANGE ,BITS AND BHA, P/U JARS, RIH, DRLG TO 1650', LOST 1500 PSI PUMP PRESSURE, CHECK SURFACE EQUIPMENT, POH, LOOKING FOR WASHOUT, BHA, FOUND EXTENDED NOZZLE TUBES JET GONE, CHANGE BIT, RIH, FILL PIPE, WASH AND REAM FROM 1632-1650', TAG BOTTOM AND WORK TO KICK JUNK ASIDE, DRLG TO 1833'. DAILY:S65,275 CUM:$112,525 ETD:S200,000 EFC:$2,611,525 RU TO RUN 13-3/8" CSG. 13-3/8"@ 3481' MW: 9.6 VIS:195 DRLG 17-1/2" HOLE TO 2020', CBU, DRLG TO 3500', CBU, SHORT TRIP, CBU, POOH FOR 13-3/8" CASING. DAILY:S94,776 CUM:$207,301 ETD:S300,000 EFC:$2,606,301 WELD ON STARTING HEAD. 13-3/8"@ 3481' MW: 9.5 VIS: 61 RUN 13-3/8" CSG, CIRC AND COND MUD, CMT CSG W/ 2200 SX AS III & 650 SX CLASS G, FULL RETURNS WHILE RECIP, BUMP PLUG, PERFORM TOP JOB W/ 107 SX AS I, SLIGHT PROBLEM CENTERING CSG AND SETTING SLIPS, CUT CSG, WELD ON STARTING HEAD. DAILY:S326,655 CUM:$533,956 ETD:S600,000 EFC:$2,632,956 DRLG AHEAD W/ 12.25" BIT AT.13-3/8"@ 3481' MW: 9.2 VIS: 37 NU DRLG HEAD, LD BI-lA, NU BOPE AND TEST, MU NEW BHA, RIH, TEST CSG TO 3500 PSI, OK, DRILL FC, FS AND 15' NEW FORMATION, PERFORM LOT- 14.7 PPG, DRILL 12.25" HOLE TO 4433'. DAILY:S54,790 CUM:$588,746 ETD:S850,000 EFC:$2,437,746 DRILLING AHEAD W/ 12-1/4" BIT.13-3/8"@ 3481' MW: 9.5 VIS: 45 DRILL 12-1/4" HOLE TO 5000' KOP, TRIP FOR NEW BHA, RIH BEGIN KICK-OFF, DRILL TO 5842' ROTATING AND SLIDING. DAILY:S67,268 CUM:$656,014 ETD:S1,000,000 EFC:$2,355,014 DRILLING AHEAD W/ 12-1/4" BIT.13-3/8"@ 3481' MW: 9.5 VIS: 46 DRLG 12-1/4" HOLE TO 6378', CBU, TRIP FOR PDC BIT, PU NEW BHA, SURF CSG SLIGHTLY PINCHED, DID NOT RUN FULL GAUGE PDC BIT, RIII "/~.. ~CF ~''. ~UT DRLG LINE, BRIDGE AT 6341', REAM TO 6378', DRILL 12-1/4" HOLE TO 6762' DAILY:S74,574 CUM:$730,588 ETD:S1,050,000 EFC:$2,379,588 Drilling Supt. For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D JNumber all dally well history forms consecutively as they are prepared for each well. jPage no. ARCO OI, ..nd Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until linal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin~ until completion. District ARCO ALASKA INC. Field F~q. UDHOE BAY Date and depth as of 8:~ a.m, U4/10/90 ~ TD: 7611'( SUPV:DBJ 04/11/90 ( TD: 8328'( SUPV:DBJ 04/12/90 ( TD: 8328'( SUPV:RJB 04/13/90 ( TD: 8907'( SUPV:RJB 04/14/90 ( TD: 8907'( SUPV:RJB Complete record 8) 849) 9) 717) lO) o) L1) 579) .2) 0) ICounty or Parish NORTH SLOPE Lease or Unit WGI-8 State AK JWell no. for eaC~ile~drilling or workover in progress TIH W/ NEW MOTOR AND BIT.13-3/8"@ 3481' MW: 9.7 VIS: 48 DRILL 12-1/4" HOLE FROM 6762' TO 7611', LOST PUMP PRESSURE, CBU, SURVEY, POOH, XO BI-IA, RIH W/ NEW BIT AND DYNADRILL. DAILY:S54,656 CUM:$785,244 ETD:S1,100,000 EFC:$2,384,~44 POOH TO RUN 9-5/8" CASING. 9-5/8"6 8308' MW:10.1 VIS: 39 RIH, REAM F~ 7545 TO 7611', DRILL 12-1/4" HOLE TO 8328', CBU, SHORT TRIP, REAN F/ 8252' TO 8328', RAISE MW TO 10.1PPG, CBU, SHORT TRIP, SURVEY, POOH TO RUN 9-5/8" CASING. DAILY:S73,500 CUM:$858,744 ETD:S1,200,000 EFC:$2,357,744 L/D BHA #6 F/DERRICK 9-5/8"@ 8308' MW: 0.0 VIS: Q FINISH POH, C/O TOP RAMS FROM 5" TO 9-5/8" AND TEST, RAN AND I2LNDED 199 JTS OF 9-5/8" CSG W/MCEVOY MANDREL HGR W/PUP, CIRC AND CMT W/650 SX CLASS G, HOSED OUT BOP STACK, INSTALLED 9-5/8" PACK-OFF, N/D MOUSEHOLE,FLOWLINE, CHOKELINE, TURNBUCKLES,DRLG NIPPLE, DRLG SPOOL, INSTALL MCEVOY TBG SPOOL, INSTALL VR PLUG AND COMPANION FLANGE, ENERGIZE FLANGE AND TEST, N/U STACK, C/O TOP RAMS F/9-5/8" TO 5", TEST BOP, SET WF_J%R BUSHINGS, L/D TEST JT, L/D BHA F/DERRICK. (UNABLE TO RECIPROCATE 9-5/8" CSG DUE TO BENT 13-3/8" CSG AT THE WELLHEAD). DAILY:S429,349 CUM:$1,288,093 ETD:S1,200,000 EFC:$2,787,093 RUN REPEAT ON MWD LOG 9-5/8"@ 8308' MW: 9.2 VIS: 42 P/U, MU BHA #7, SERV AND CALIBRATE MWD, RIH TAG @ 8237', CIRC., TEST 9-5/8" CSG, DRLD FC + 61' OF FIRM TO HARD CMT, CIRC AND COND TO 9.2 PPG, TEST 9-5/8" CSG (REPAIR LEAK IN MUD LINE #1 PUMP), DRLD 20' CMT, 10' OLD HOLE, 10' NEW HOLE, CBU, PERFORM F.I.T. TO 12.5 EMW W/9.2 PPG MUD, DRLD F/8338'-8907', TOP OF KAVIK @ 8897', CBU, L/D 7 JTS, SHORT TRIP TO 9-5/8" CSG SHOE, TIH, RUN REPEAT FOR BAROID MWD RLL F/8660' TO 8793' DAILY:S53,693 CUM:$1,341,786 ETD:S1,200,000 EFC:$2,840,786 TOH 7"@ 8905' MW: 9.2 VIS: 42 REA.N AND WASH RUNNING REPEAT FOR BAROID MWD RLL, CIR AND COND, DROP SURVEY, SLUG PIPE, DROP RABBIT, POH SLM, NO CORR., RETR SURV, L/D BHA, R/U CSG TOOLS, RUN SHOE, FLOAT, F.C., CHECK FLOAT EQUIPMENT, BAKERLOCK SAME, RUN LINER (21 JTS) F/8000'-8905', CIRC LINER, P/U, S/O AND HANG , TIH, CIRC WHILE BATCH MIXING CMT, RECIPROCATED PIPE WHILE CIRC, PUMP 266 SX CLASS G CMT, TEST LINES TO 3500 PSI, FLOATS HOLDING SET HGR, RECIPROCATE WHILE CMTG, POH W/10 STDS, SLUG PIPE CONT, POH. DAILY:S134,001 CUM:$1,475,787 ETD:S2,000,000 EFC:$2,174,787 The above is correct For form p'teparati~'n and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ITit'e Drilling Supt. AR3B-459-2-B INumber all daily well history forms conseculively [Page no. as they are prepared for each well. ARCO Oi, ~l Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until tinal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District A[:~.CO AI.~t~SKA TNC o tCounty or Parish N. ORTH SLOPE IState AK Field [31~.UDHOE SAx /L ...... Unit WGi_8 Iwe,I no. Date and depth Complete record as of 8:00 a.m. 04/15/90 TD: 8860' SUPV:RJB 04/16/90 TD: 8860' SUPV:RJB 13) 0) 14) 0) f ..... b{~o~,le ~rilling ..... k .... in prog .... FLUSH & CLEAN OUT SURF. LINES 7"@ 8905' MW: 9.2 VIS: 54 M/U TIH W/ BHA #8, RIH TO 4273', CUT AND SLIP 54' DRILLING LINE, RIH TO 7560', REAM & WASH F/7560 TO 8000', TAG CMT @ 7895', FIRM TO HARD, CBU, TOH, L/D BHA #8, P/U, TIH W/BHA #9, TAG & DRLD OUT CMT F/TOL @ 8000' TO 8005', WASHED 3 JTS DOWN, RIH, DRLD OUT CMT (HARD F/8745' TO 8816' (LNDG COLLAR)), CIRC. AND TEST LINER TO 4000 PSI, DRLD L/C + 44' CMT TO FC @ 8860', CIRC, RETEST CSG/LINER TO 4000 PSI, CIRC, FLUSH AND CLEAN OUT SURFACE LINES. DAILY:S49,818 CUM:$1,525,605 ETD:S2,000,000 EFC:$2,224,605 TAKE OFF BOP 7"@ 8905' MW: 9.2 VIS: 0 DISPLACE 9.2 PPG MUD WITH 9.2 PPG NACL, RETEST LINER TO 4000 PSI, CLEAN OUT SHAKER, CIRC OVER SCREENS, PUMP SLUG, POH, L/D DP AND BHA #9, DISPLACE TOP 617' OF 9-5/8" CSG W/DIESEL, L/D KELLY, TOP HOLE OFF W/DIESEL, PULL WEAR BUSHING, INSTALL DUMMY TBG HGR W/2 WAY CHECK, L/D R/T, N/D FLOWLINE, MOUSEHOLE TURN BUCKLES, CHOKELINE, TAKE BOP STACK OFF AND REMOVE F/SUB. DAILY:S60,904 CUM:$1,586,509 ETD:S2,000,000 EFC:$2,285,509 The above is correct Signata~re %. '~'~ For form p. eparat,on and ibution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecufively as they are prepared for each well. Page no. ARCO ...il and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the ,Filtal R~" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted ~WI~ 99stations ere suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report co~t~ff..?t~'repre~eli~!¥e test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. IAcc°unting cost center code I IL ...... Unit ADL: 28297 I Title DRILL ARCO ALASKA INC. District Field PRUDHOE BAY Auth. or W.O. ho.AS3021 Operator ARCO A.R.Co. W.I. Date Complete record for each day_reported DOYON 9 Spudded or W.O. 04/17/90 (15) TD: 8860' ( SUPV: RJB Date and depth as of 8:00 a.m. 0) API: 50-029-21996 21.0000 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our 0400 HRS IPri°r status if s W'O' I 04/03/90 7"@ 8905' MW: 9.2 VIS: 0 N/U MCEVOY GEN IV DRV HOLE TREE, TEST TO 5000 PSI FOR 15 MIN., OK, CLEANING PITS, SOLID CONTROL EQUIPMENT AND LINES WITH H20 INJECTING SAME, FREEZE PROTECTING WGI-7, WGI-8 WITH 90 AND 100 BBLS OF 50/50 CRUDE. RELEASED RIG AT 1400 HOURS 4-16-90. DAILY:S14,000 CUM:$1,600,509 ETD:S2,000,000 EFC:$2,299,509 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval !Oil or gas Test time Production OII on teat Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % --. ~(~R Gravity - Allowable Effective date corrected %. v r ~ The abo e is ¢~o rect ~'X _ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number ell daily well history forms consecutively as they are prepared for each well. iPage no. DIvINoe of Atlantlcflk:hfleldCompa~Y RRCO RLRSKR INC; HGI-8 Date_ PRU~HOE ~RY DRLE HENURIX RECEIVED MAY 11 1990 Alaska 011 & Gas Cons. Commissior ;a, nchora~e ARCO ALASKA INC. WGI-8 PRUDHOE BAY DALE HENDRIX 4/3/90 DATADRIL ANADRILL MWD 30.74 N47.7 E DOYON 9 AFE AS-3021 PAGE No. File Na~e: WGI 8 . MEASURED INCL D R I F T DEPTH ANGLE DIRECTION (FT) (DEG) (DEG) 0.00 0.00 N 0.00 E .9.00 .20 S 34.70 E 955.00 .50 S 10.00 W 1441.00 .20 S 39.90 E 1941.00 .40 S 13.20 W 2435.00 .~0 N 64.60 E ,'~.j~.vv .10 S 4.60 W · .'.4J4.00 40 S 18.80 E 3747.00 ,50 S 6.90 W 4057.00 .60 S 16.90 W 4364.00 .40 S 43.70 W 4737.00 .60 S 27.70 W 4939.00 .50 S 29.90 W 5149.00 3.50 N 59.40 E 5371.00 8.90 N 48.40 E 5557.00 13,10 N49.20 E 5746.00 17.90 N 51.00 E 5966.00 23.90 N 45.90 E 6312.00:27.50~ ~N 47.50'E ~L~5.00 28.60 'N48.90E .8.00 30.00 N 48.80 E COURSE LENGTH (FT) 0.00 479.00 476.00 486.00 500.00 494.00 500.00 469.00 343.00 310.00 307.00 373.00 202.00 210.00 222.00 186.00 189.00 220.00 346.00 313.00 313.00 ~Z RECORD OF SURVEY Calculated by DATADRIL's CADDS System Radius of Curvature Method AIl Angles are Decima! Vertical Section Plane: N 49.70 E TOTAL T O T A L VERTICAL RECTANGULAR COORDINATES DEPTH (FT) VERTICAL C L 0 S U R E SECTION DISTANCE DIRECTION (FT) (FT) (DEG) 0.00 0.00 N 0.00 E 0.00 O. O0'N 0.00 E 479.00 .69 S .48 E -.08 .84 S 34.70 E 954.99 3.46 S 1.OB E -1.41 3.62 S 17.39 E 1440.98 6.23 S 1.82 E -2.64 1940.97 8.69 S 2.41 E -3.79 24.74.95 10.87 $ 5.10 E -3.14 2934.94 12.30 S 7.18 E -2.48 3403.94 14.32 S 7.43 E -3.59 374&.93 16.97 S 7.71 E -5.10 4056.91 19.88 S 7.10 E -7.45 4363.90 ~" ,1.17 S 5.76 E -9.95 4736.89 24.81S 3.86 E -13.10 4938.88 26.51S 2.93 E 5148.73 30.30 S 6.77 E 5369.35 !6.20 S 26.10 E 5551.89 7,17 N 52.80 E 5733.96 39.56 N 91,54 E 5939.39 91.57 N 150.22 E 6251.11 194.46 N 259.40 E 6527.34 292.56 N 369.12 E 6800.29 393.35 N 484.46 E -14.91 -14.44 9.43 44.91 95.40 173.80 323.61 470.74 623.90 8.50 S 16.31 E 9.02 S 15.48 E 12.00 S 25.15 E 14.24 S 30.27 E 16.1.] S 27.43 E 18.64 S 24.42 E 21.11 S 19.64 E 22.91 S 14.55 E 25.11 S 8.85 E 26.67 S 6.30 E 31.05 S 12.59 E 30.72 S 5B.1B E 53.28 N 82.26 E 99.72 N 66.63 E 175.93 N 58.&3 E 324.20 N 53.14 E 471.00 N 51.60 E 624.04 N 50.93 E DOGLEG SEVERITY (DEG/IO0') 0.00 ,04 ,08 .08 .06 .18 .13 .07 .06 .04 .10 .06 .05 1,88 2.48 2.55 2.85 1.06 .41 .45 MEASURED DEPTH (FT) 7252.00 7524.00 7879.00 8190.00 8554.00 8827.00 Bg07.00 ARCO ALASKA INC. WBI-B INCL D R I F T COURSE TOTAL ANGLE DIRECTION LENGTH VERTICAL (DEB) (DEG) (FT) DEPTH DATADRIL PRUDHDE BAY DALE HENDRIX T D T A L VERTICAL C L O S U R E RECTANGULAR COORDINATES SECTION DISTANCE DIRECTION (FT) (Fl) (FT) (DEB) 25.10 N 48.90 E 314.00 7078.60 488.89 N 593.78 E 76g.07 769.15 N 50.53 E 25.00 N 54.00 E 272.00 7325.02 560.64 N 683.82 E B84.14 B84.27 N 50.65 E 21.00 N 47.10 E 355.00 7651.73 648.70 N 790.84 E 1022.73 1022.86 N 50.64 E 15.20 N 61.90 E 311.00 7947.22 704.65 N 869.25 E 1118.70 1118.97 N 50,97 E 15.50 N 67.00 E 364.00 8298.23 746.18 N 956.16 E 1211.85 1212.85 N 52.03 E 16.10 N 66.50 E 273.00 8560.91 775.52 N 1024.45 E 1282.91 1284.88 N 52.87 E 16.10 N 66.50 E 80.00 8637.78 784.36 N 1044.80 E 1304.15 BOTTOM HOLE CLOSURE: 1306.46 Feet at N 55.10 Degrees E 1306.46 N 53.10 E PAGE No, 2 DOGLEG SEVERITY (DEB/lO0') 1.56 .79 1.36 2.57 ,.]8 ,23 0.00 ***** CURREN'T BO'I'TOM HOLE LOCA'I'ION ***** Calculated by DATADRIL's CADDS System * Vertical Section Plane: N 49.70 E Radius of Curvature Method ARCO ALASKA INC. WGI-8 PRUDHOE BAY DALE HENDRIX CURRENT SURVEY -- Measure Depth: Inc:l i nati on: Direction: 89(")7.00 Feet 16. 10 Degs N 66.5~') E D.L.S.: 0.0() Degs/100 Feet TVD (Vert Depth): 8637.78 Feet * Vertical Section: 13(]4. 15 Feet Total N/S !]oord: Total E/W Coord: 784.56 Feet 1044.8() Feet BOTTOM HOLE CLOSL;RE: 1306.46 Feet L~' N 53. 10 Degrees E RRCO RLRSKR INC. WGI-8 PRUDHOE BR¥ DRLE HENDRIX VERTICRL PLOT 16 RPR 1998 · 8:81 I ............. JLJ[...J SCRLE: 15OO FEET?INCH TVD 1588- 3888- 4588- 6888 - 7588- 9888- 85~i .1441 .2935 3404 3?4? 405? 4364 4?3? 5149 ! 8 1588 VERTICRL SECTION SECTZON PLRNE: N 49.?B 1 ........ ] ._1 I~: 13~6 FEET · N 53.t~ £ TVD: 8E38 FEET ~13: 8987 FEET .L. 7588 ARCO ALASKA INC. WGI-B PRUDHOE ]]AY DALE H£NDRI× HORIZONTRL PLOT 16 RPR ISSO ~ 8:16 SCRLE: 150 FEET/INCH BHL: 1306 FEET 8 N 53.18 E TVD: 8638 FEET M~: 8S87 FEET -758 -388 -.158 ORIGINAL ?o ~ ~/? P~.~ NO, COi'IPN4Y ARi:Z) AI,ASI(A INC. ~ ~ WGI-8 LOCATIOI,i 1 PBtll)~£ ~Y ~TION 2 ~AG~'TIC I)~LII~TIOFI Whq, L ldUIqBl~ 8 WEll, HEAD Lt:)CATI~: ~T($'-$) O,00 AZIIJJTH FROfl ROTARY T~LS TO TARG~ IS TIS IH POINT(TIP): ~ ~ 0.00 ~ ~ I)EP'fTI O.00 Ii,ICLII, i~TI014 0.00 AZIIJ. ffH LATITtq~(H/-$) 0.00 D~ARITJR~(E/-W) O.00 D~(E/-W) RECEIVED APR 2 6 1990 AJaska 011 & Gas Cons, Commission Ancherage P~£ ~, 2 WGI'8 ~D Ilff~ VI~ICAL l'AR(]~l' STATIOH AZIIEITH DI~ffH DI~aTI4 S)~I'IDI II~. ft ft ft ft deg deq O.CK) 0.0 0.00 0.00 0.00 49.70 479.00 479.0 479,00 0,50 0.20 145.30 9b'5.00 476.0 954.99 -1.75 0,50 190,00 1441.30 486.0 1440,98 -2.98 0.20 140.10 1941,(,0 5(X),O 1940,97 -5,01 0,40 193.20 LATII'dO£ DE~Af~E OlSPI~CE)~NT at AZI~qUTH N/-S ~/-W ft ft ft deg 0,0O 0.00 0.00 0.0O -0,10 0.74 0,75 97,50 -2.86 0.14 2,87 177.28 -5.64 0,88 5.71 171.16 -8.0~ 0,30 8.10 177,91 2435.30 494,0 2434,95 2935,00 500,0 2934,94 3403.00 468.0 3402,94 3747,00 344.0 3746.93 4057.00 310,0 4056.91 -1.55 0.60 64.60 -4,06 0,10 184,60 -5.16 0.40 161,20 -7.10 0,50 18&90 ' -9,45 0.60 196.90 DLS lOOft 0.00 0.04 0,08 0,08 0.06 4364.00 307.0 4363.Cj~) 4737.00 373.0 4736,89 4939,00 202.0 4938.88 5149.00 210.0 5148.73 5371.00 ~,0 5369.34 -11,95 0.40 223.70 -15.10 0.60 207.70 -16,91 0.50 209.90 -11.53 3.50 59.40 12.34 8,90 48.40 -5.92 2,99 6.63 153,20 0,18 -7.35 0.91 7.41 172,92 0.13 -9,35 1.16 9.43 172.92 0.07 -12.02 0.88 12.05 175.79 0.06 -14.c/3 0.27 14.93 178.96 0.04 5557.00 186.0 b'551,89 5746,00 189,0 5733.96 5966.0O 220,0 5939.39 6312,00 346.0 6251,11 6625.00 313.0 6527.34 47.81 13.10 49.~ 98,30 17.90 51.0O 176.71 23.90 45.90 326.52 27,50 47,50 473,65 28.60 48,90 -17.22 -1.07 17.25 183,55 0,10 -19,85 -2,96 20.07 188.48 0,06 -21,55 -3,89 21.90 190.24 -17,76 -0,06 17.76 180,18 -3.66 19.28 19.62 100,75 2,48 7252.00 627.0 7086.66 7524.00 272.0 7333,08 7879,00 355.0 7659.79 8190.00 311,0 7955.28 B554.00 364.0 83O6.29 756.76 25.10 48.90 871.84 25.0O 54.0O 1010.43 21,00 47.10 1106.40 15.20 61.90 1199.55 15.50 19,71 45.98 50,02 86.79 2.26 52.10 84.71 99,45 ~.41 2.55 104,11 143.40 177,21 54.02 2,85 207.0O 252.58 326.56 50.66 1,06 3~.10 362,30 473,65 49.90 0.41 8827,0O 273,0 8907,C,0 80'0 SURVEY AT 8907 I9 A 491.23 5~.~ ~.~ 49,53 0.56 562,98 6,65.71 871,85 49,78 0.79 651,05 772,73 1010,43 49,BB 1.36 706,98 851.14 11~,~ 50.29 2.37 748.52 938.04 1200.08 51,41 0.38 1006.34 1271.92 52,30 0.23 1026,68 1293.44 52,54 0,0O 8568,97 1270.61 16,10 66,50 777.86 8645.84 1291.85 16.10 66.50 786.71 PR0JlLT~ ~ AT 8.SHOLE ~ ~RCO ~d, ASI(A INC. WELL ~ KI-8 I,OCATIOI, I I PRUIX. IOI~ ~Y LOCATI~ 2 D~: ~VW;I~"TIC I)~LI~TIOH 30.74 P~£ ~, 2 ~I-8 MD ft TVD INC_CH~ ~t~IN~_CH~ I_RA~ AZM_C~ CUMAZM_CH6 TURN_RA~ CLO~UR~ TOOL_PA~ DLS DLSRT ft deg de9 deg/l~r de9 de9 deg/lOOft ft deg de~/lOOft de~/lOOft**2 0,0 0,00 0,00 0,00 0,00 0,00 0.00 0,00 0,00 0,00 0,00 0,00 479,0 479,00 0,20 0,20 0,04 95,60 95,60 19,96 -0,55 0,00 0,04 0,01 955...',954,99 0,30 0.50 0,06 44,?0 140,30 9,39 -2,27 65,56 0,08 0,01 1441,0 1440,78 -0,30 0,20 -0,0.6 -49.90 90,40 -10,27 -4,87 157.28 0,08 0,00 1941,0 1740,97 0,20 0,40 0,04 53,10 143,50 10,62 0,00 0,00 0,06 0,00 2435,0 2434,95 0.20 0,60 0.04 -128,60 14,90 -26.03 -6,45 148,54 0.18 0.02 29~,0 2934,94 -0,50 0,10 -0,10 120,00 134,90 24.00 -6,20 171,87 0.13 0,01 3403,0 3402.94 0,30 0,40 0,0,5 -23,40 111,50 -5,00 -7.89 29,09 0.07 0,01 3747...'. 3746,?3 0,10 0,50 0,03 25,70 137.20 7.47 -9.74 76.07 0.06 0.00 4057,0 4056,91 0,10 0,60 0,03 10,00 147.20 3.23 -6,34. 82.46 0,04 0.01 4364,0 4363,90 -0,20 0,40 -0,07 26,S0 174,00 8,73 -12,44 I43,45 0,10 0,02 4737,0 4736,89 0,20 0,60 0,05 -16,00 158,00 -4,29 -13,23 41,32 0,06 0,01 4939,0 4?38,88 -0,10 0,50 -0,05 2,20 160,20 1,09 -13,92 0,00 0,05 0,01 5149,0 5148.73 3,00 3,50 1,43 -150.50 9,70 -71,67 -13,51 154.01 1.88 0,87 5371,0 5369,34 5.40 8,90 2,43 -11,00 -1,30 -4.95 -11.56 45.66 2.48 0.27 5557.0 5551,87 4,20 13,10 2,26 0°80 -0,50 0,43 -14,70 2,44 2,26 0,12 5746,0 5733,96 4,80 17,90 2,54 1.SO 1.30 0.95 -15,06 6.57 2.55 0,15 5966,0 5939,39 6,00 23,90 2,73 -5,10 -3,80 -2,32 -13,35 19,27 2,85 0,13 6312,0 6251,11 3,60 27,50 1,04 1,60 -2,20 0,46 -5,49 11,62 1,'~ 0,52 6625,0 ~,527.34 1.10 28.60 0.35 1,40 -0,80 0,45 -15,26 17.92 0.41 0.21 7252,(, 708/,,66 -3,50 25,10 -0,56 0,00 -0,80 0,00 2,31 0,00 0,56 0,02 7524°0 7~33,08 -0,10 25,00 -0,04 5,10 4,30 1,87 -1,20 ?4,96 0.79 0.09 7879.0 7659.7? -4.00 21.00 -1,13 -6.90 -2.60 -1.74 -3.26 149,16 1.36 0,16 8190,0 79~,28 -5,80 15,20 -1,~ 14,80 12,20 4,76 -11,32 148,47 2,37 0.32 8554.0 8306,29 0.30 15,50 0,08 5,10 17.30 1,40 -1,64 31,49 0,38 0.55 8827,0 8.568,9'7 0,60 16,10 0,22 -0,.50 16,80 -0,18 -57,64 12,72 0,23 8907,0 84al5.~ 0.00 16.10 0°00 0.00 16.~ 0.00 -~.~ ~.00 0.00 0,28 OI~iGINA. L SUB-SURFACE DIRECTIONAL SURVEY ~----]UIDANCE [~ONTINUOUS F'~]OOL Company. ARCO ALASKA~ INC. Well Name WGI-8 (963' FNL~1060' FEL~SEC llzTllN~R14E~UM) Field/Location PRUDHOE BAY~ NORTH SLOPE~ ALASKA t Job Reference No,. 73816 Log~3ed By: HUSBAND Date 22-APR-90 Computed By: KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. WGI - 8 PRUDHOE BAT NORTH SLOPE, ALASKA SURVEY DATE: 2Z-APR-lO90 ENGINEER: J. HUSBAND METt.'I-ODS OF COMPUTATION :~. TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH ~ ~' INTERPOLATION: LINEAR :~:51~ERTICAL SECTION: HaRIZo DISTo PRaJECTED ONTO I TARGET AZIMUTH OF NORTH 49 DEG 44 MIN EAST COMPUTATION DATE: 20-MAY-90 PAGE ARCO ALASKAt INC. WG! - 8 PRUOHOE BAY NORTH SLOPE9 ALASKA DATE OF SURVEY: 22-APR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: J. HUSBAND INTERPOLATED VALUES FOR EVEN 100 mEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/ZO0 FEET FEET FEET DEG MIN 0.00 0.00 -60.00 0 0 N 0 0 E 100.00 99.95 39.95 0 7 S 22 13 E 200.00 199.95 139.95 0 I N 16 46 E 300.00 299.95 239.95 0 17 S 12 19 E 400.00 399.95 339.95 0 8 S 15 16 W 500.00 499.95 439.95 0 6 S 12 49 E 600.00 599.95 539.95 0 15 S 8 12 E 700.00 699.95 639.95 0 23 S 11 20 E 800.00 799.94 739.94 0 26 S 8 2 E 900.00 899.94 839.94 0 25 S 10 47 E 0.00 0.00 0.00 N 0.00 E -0.05 0.00 0.11 S 0.03 E 0.03 0.25 0.19 S 0.20 E -0.17 0.29 0.44 S 0.15 E -O.ZZ 0.72 0.70 S 0.30 E -0.38 0.49 1.04 S 0.38 E -0.56 1.15 1.43 S 0.47 E -0.79 0.73 1.92 S 0.59 E -1.04 0.48 2.44 S 0.70 E -1.36 0.77 3.06 S 0.81 E 0.00 N 0 0 E 0.12 S 16 27 E 0.28 S 46 39 E 0.47 S 19 12 E 0.76 S 23 5 E 1.11 S 20 12 E 1.50 S 18 ZZ E :,.ox s E 2.54 S 16 5 E 3.17 S 14 55 E 1000.00 999.94 939.94 1100.00 1099.94 1039.94 1200.00 1199.94 1139.94 1300.00 1299.94 1239.94 1400.00 1399.94 1339.94 1500.00 1499.94 1439.94 1600.00 1599.94 1539.94 1700.00 1699.94 1639.94 1900.00 1799.94 1739.94 1900.00 1899.94 1839.94 0 25 S 8 35 E 024 S 3 36 ~c 0 18 S 21 59 E 0 14 S 29 59 5 0 7 S 8O 30 E 0 6 N 45 4 E 0 4 N 15 15 5 0 10 S 64 32 W 0 12 S 76 56 W 0 13 N 89 34 W -1.70 1.06 3.67 S 0.88 -2.01 0.59 4.23 S 0.95 -2.22 0.64 4.70 S 1.08 -Z.Z8 0.27 4.95 S 1.20 -2.30 0.91 5.10 S 1.31 -2.Z0 0.19 5.03 S 1.38 -2.15 0.48 5.00 S 1.41 -2.42 0.47 5.12 S 1.17 -2.81 0.03 5.15 S 0.69 -3.15 0.78 5.10 S 0.19 3.77 S 13 28 E 4.34 S 12 42 E 4.83 S 12 55 E 5.09 S 13 36 E 5.26 S 14 22 E 5.22 S 15 23 E 5.20 S 15 47 E 5.25 S 12 50 E 5.20 S 7 35 E 5.10 S 2 9 E 2000.00 1999.93 1939.93 2100.00 2099.93 2039.93 2200.00 2199.93 2139.93 2300.00 2299.93 2239.93 2400.00 2399.93 2339.93 2500.00 2499.93 2439.93 2600.00 2599.93 2539.93 2700.00 2699.93 2639.93 2800.00 2799.93 2739.93 2900.00 2899.92 2839.92 0 16 S 78 20 W 0 5 N 45 35 W 0 4 N 13 29 W 0 13 N 35 17 W 0 17 N 2 47 E 0 22 N 32 8 E 0 22 N 5O 10 E 0 14 N 87 41 E 0 35 S 68 41 E 0 27 S 47 17 E -3.40 0.94 5.06 S 0.17 W -3.50 0.85 5.08 S 0.29 W -3.57 1.11 5.11 S 0.35 W -3.68 0.51 5.04 S 0.56 W -3.59 0.00 4.65 S 0.77 W -3.10 0.16 4.06 S 0.62 W -Z.40 0.51 3.56 S 0.13 W -1.96 0.01 3.39 S 0.31 E -1.63 O.ZO 3.62 S 0.92 E -1.32 0.83 4.09 S 1.73 E 5.06 S I 54 W 5.09 S 3 15 W 5.13 S 3 56 W 5.07 S 6 20 W 4.71 S 9 24 W 4.11 S 8 38 W 3.56 S 2 7 W 3.40 S 5 9 E 3.73 S 14 19 E 4.44 S 22 57 E 3000.00 2999.92 2939.92 3100.00 3099.92 3039.92 3200.00 3199.92 3139.92 3300°00 3299.92 3239.92 3400.00 3399.92 3339.92 3500.00 3499.92 3439.92 3600.00 3599.91 3539.91 3700.00 3699.91 3639.91 3800.00 3799.91 3739.91 3900.00 3899.90 3839.90 012 S $0 6 E 0 11 S 29 34 E 0 8 S 26 49 E 0 11 S 25 6 E 0 18 S 19 52 E 023 S ZO 25 E 0 27 S 8 50 E 0 28 S 12 50 E 0 34 S 11 30 E 033 S 8 37 E -1.24 0.33 4.50 S 2.19 E -1.27 0.01 4.75 S 2.36 E -1.32 0.00 4.97 S 2.48 E -1.40 0.00 5.24 S 2.60 E -1.53 0.44 5.59 S 2.74 E -1.69 0.24 6.10 S 2.96 E -1.96 0.71 6.76 S 3.15 E -2.32 0.17 7.50 S 3.31 E -2.77 0.43 8.37 S 3.46 E -3.25 0.00 9.32 S 3.64 E 5.01 S 25 55 E 5.30 S 26 22 E 5.56 S 26 32 E 5.85 S 26 24 E 6.22 S 26 5 E 6.79 S 25 53 E 7.46 S 25 I E 8.20 S 23 50 E 9.06 S 22 28 E 10.01 S 21 20 E COMPUTATION DATE: 20-MAY-90 PAGE ARCO ALASKA, INC. WGI - 8 PRUOHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 22-APR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: J. HUSBAND INTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/tO0 FEET FEET FEET OEG MIN 4000.00 3999.90 3939.90 4100.00 4099.89 4039.89 4200.00 4199.89 4139.89 4300.00 4299.89 4239.89 4400.00 4399.88 4339.88 4500.00 4499.88 4439.88 4600.00 4599.88 4539.88 4700.00 4699.88 4639.88 4800.00 4799.88 4739.88 4900.00 4899.87 4839.87 032 S 6 27 E 030 S 1 16 E 028 S 2 57 W 0 27 S 10 31 W 0 21 S 11 18 W 0 15 S 15 11 W 0 27 S 28 17 W 0 29 S 26 28 W 0 32 S 26 39 W 0 32 S 26 21 W -3.77 0.21 10.30 S 3.78 E -4.30 0.00 ll.lT S 3.83 E -4.87 0.00 12.04 S 3.81 E -5.48 0.00 12.85 S 3.71 E -6.07 0.09 13.59 S 3.55 E -6.45 0.00 14.06 S 3.46 E -6.95 0.38 14.56 S 3.22 E -7.67 0.00 15.29 S 2.89 E -8.47 0.18 16.08 S 2.52 E -9.30 0.35 16.91 S 2.14 E 10.97 S 20 10 E 11.81 S 18 55 E 12.63 S 17 34 E 13.38 S 16 6 E 14.05 S 14 40 E 14.48 S 13 50 E s6s E 16.27 S 8 53 E 17.05 S 7 13 E 5000.00 4999.87 4939.87 0 lB 5100.00 5099.87 5039.87 1 25 5200.00 5199.69 5139.69 4 31 5300.00 5299.24 5239.24 6 34 5400.00 5398.27 5338.27 9 20 5500.00 5496o61 5436.61 11 31 5600.00 5594.16 5534.16 13 50 5700.00 5690.63 5630.63 16 44 5800.00 5785.64 5725.64 19 44 5900.00 58'78.89 5818.89 22 22 S 19 17 W N 39 10 E N 57 36 E N 53 5 E N 46 17 E N 44 21 E N 47 48 E N 52 17 E N 51 4 E N 47 43 E -9.96 0.16 17.61 S 1.87 E -9.64 4.92 17.44 S 2.13 E -4.00 1.87 13.84 S 6.48 E 5.36 3.72 8.64 S 14.34 E 19.20 2.34 0.43 N 24.80 E 37.24 2.33 13.35 N 37.49 E 59.16 2.60 28.68 N 53.24 E 85.41 2.89 45.40 N 73.48 E 116.55 3.98 64.53 N 152.61 1.90 17.71 S 6 3 E 17.57 S 6 59 E 15.29 S 25 6 E 16.75 S 58 55 E 24.80 N 89 0 E 39.80 N 70 24 E 60.47 N 61 41 E 86.38 N 58 t7 E 98.08 E 117.41 N 56 40 E 88.08 N 125.39 E 153.23 N 54 55 E 6000.00 5970.80 5910.80 23 54 6100.00 6061.80 6001.80 25 10 6200.00 6151.79 6091.79 26 27 6300.00 6240.90 6180.90 27 29 6400.00 6329.46 6269.46 27 50 6500.00 6417.73 6357.73 28 12 6600.00 6505.63 6445.63 28 41 6700.00 6593.17 6533.17 29 9 6800.00 6680.36 6620.36 29 31 6900.00 6767.22 6707.22 29 53 N 46 47 E N 46 50 E N 46 44 E N 47 4 E N 48 19 E N 48 41 E N 48 31 E N 48 31 E N 48 33 E N 48 42 E 191.96 1.23 233.36 1.52 276.91 1.24 322.23 0.86 368.65 0.77 415.63 0.34 463.30 0.43 511.63 0.58 560.60 0.45 610.14 0.33 114.88 N 154.26 E 192.34 N 53 19 E 143.28 N 184.46 E 233.57 N 52 10 E 173.12 N 216.25 E 277.01 N 51 19 E 204.17 N 249.35 E 322.27 N 50 41 E 235.46 N 283.69 E 368.67 N 50 18 E 266.51 N 318.95 E 415.64 N 50 7 E 298.06 N 354.69 E 463.30 N 49 58 E 330.07 N 390.92 E 511.63 N 49 49 E ~ 362.51 N 427.61 E 560.60 N 49 43 E '~ 395.27 N 464.79 E 610.14 N 49 37 E 7000.00 6853.85 6793.85 29 54 - 7100.00 6941.77 6881.77 26 35 7200.00 7031.79 6971.79 25 32 7300.00 7122.02 7062.02 25 33 7400.00 7212.24 7152.24 25 33 7500.00 7302.50 7242.50 25 26 7600.00 7392.89 7332.89 25 14 7700.00 7483.33 7423.33 25 15 7800.00 7574.21 7514.21 23 42 7900.00 7666.65 7606.65 21 8 N 49 13 E N 48 45 E N 47 39 E N 48 43 E N 49 49 E N 50 56 E N 52 12 E N 48 19 E 660.08 1.28 707.67 3.79 751.20 0.51 794.30 0.46 837.42 0.46 880.47 0.57 923.23 0.45 965.86 3.52 2.74 2.58 N 44 27 E 1007.46 N 47 2 E 1045.48 428.08 N 502.45 E 660.09 N 49 34 E 459.10 N 538.55 E 707.68 N 49 33 E 488.34 N 570.83 E 751.21 N 49 27 E 517.08 N 602.96 E 794.31 N 49 23 E 545.24 N 635.63 E 837.44 N 49 23 E 572.69 N 668.80 E 880.49 N 49 26 E 599.27 N 702.31 E 923.23 N 49 32 E 626.16 N 735.40 E 965.87 N 49 35 E 655.28 N 765.25 E 1007.47 N 49 26 E 681.95 N 792.49 E 1045.51 N 49 17 E COMPUTATION OATE: 20-MAY-90 PAGE 3 ARCO ALASKA, INC. WGI - 8 PRUOHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 22-APR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: J. HUSBAND INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY'NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG HIN 8000.00 7760.59 7700.59 19 8 8100.00 7855.81 7795.81 16 23 8200.00 '7952.19 7892.19 14 45 8300.00 8048.99 7988.99 14 2~ 8400.00 8145.81 8085.82 14 39 8500.00 8242.42 8182.42 15 15 8600.00 8338.84 8278.84 15 29 8700.00 8435.18 8375.18 15 35 8,800.00 8531.52 8471.52 15 46 8900.00 8627.76 8567.76 15 46 N 50 24 E 1079.73 N 56 18 E 1110.16 N 63 30 E 1136.39 N 70 54 E 1160.27 N 72 15 E 1183.36 N 71 I 5 1207.35 N 69 0 E 1232.21 N 67 37 E 1257.63 N 66 48 E 1283.32 N 66 48 E 1309.28 2.56 3.15 2.12 1.30 0.79 0.67 0.51 0.16 0.00 0.00 704.62 N 818.17 E 1079.76 N 49 16 E 722.82 N 842.64 E 1110.18 N 49 23 E 736.29 N 865.60 E 1136.39 N 49 37 E 745.88 N 888.77 E 1160.28 N 50 0 E 753.58 N 912.52 E 1183.46 N 50 27 E 761.70 N 937.07 E 1207.59 N 50 54 E 770.76 N 961.98 E 1232.67 N 51 18 E 780.71 N 986.86 E 1258.34 N 51 39 E 791.07 N 1011.75 E 1284.30 N 51 59 E 801.77 N 1036.72 E 1310.58 N 52 17 E 8907.00 8634.50 8574.50 15 46 N 66 48 E 1311.10 0.00 802.52 N 1038.47 E 1312.42 N 52 18 E COHPUTATION OATE: 20-HAY-90 PAGE ARCO ALASKA~ TNC. WG! - 8 PRUDHOE BAY NORTH SLOPE9 ALASKA DATE OF SURVEY: Z2-APR-1990 KELLY BUSHING ELEVATION: 60°00 FT ENGINEER: J. HUSBAND INTERPOLATEO VALUES FOR EVEN 1000 FEET"OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTTCAL VERTICAL DEVTATTON AZTMUTH DEPTH DEPTH DEPTH DEG MIN DEG MTN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -60.00 0 0 1000.00 999.94 939.94 0 25 2000.00 1999.93 1939.93 0 16 3000.00 2999.9Z 2939.92 0 12 ¢000.00 3999.90 3939.90 0 32 5000.00 4999.87 4939.87 0 18 6000.00 5970.80 5910o80 23 54 7000.00 6853.85 6793.85 29 54 8000.00 7760.59 7700.59 19 8 8907.00 8634.50 857¢.$0 15 46 N 0 0 5 0o00 0.00 S 8 35 E -1.70 1.06 S 78 20 W -3°40 0.94 S 50 6 E -1.24 0.33 S 6 27 E -3.77 0.21 S 19 17 W -9.96 0.16 N 46 47 E 191.96 1.23 N 49 13 E 660.08 1.28 N 50 24 E 1079.73 2.56 N 66 48 E 1311.10 0.00 0.00 N O.OO E 0.00 N 0 0 E 3.67 S 0.88 E 3.77 S 13 28 E 5.06 S 0.17 W 5.06 S 1 54 W 4.50 S 2.19 E 5.01 S 25 55 E 10.30 S 3.78 E 10.97 S 20 10 E 17.61 S 1.B7 E 17.71 S 6 3 E 114.88 N 154.26 E 192.34m, N 53 19 E 47.8.08 N 502.45 E ' 660.09 N 49 34 E ) 704.62 N 818.17 E 1079.76 N 49 16 E 802.52 N 1038.47 E 1317_.42 N 52. 18 E COMPUTATION DATE: 20-MAY-90 PAGE "5 ~ ARCO ALASKAt INC. WG[ - 8 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 2Z-APR-lO90 KELLY BUSHING ELEVATION: 60.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DIG M[N 0.00 0.00 -60.00 0 0 N 0 0 E 60.05 60.00 0.00 0 [0 S 14. 4 E 160.05 160.00 100.00 0 8 S 81 19 E 260.05 260.00 200.00 0 13 S 13 3 W 360.05 360.00 300.00 0 8 S 50 32 E 460.05 460.00 400.00 0 15 S 31 4 E 560.05 560.00 500.00 0 16 S 29 16 E 660.05 660.00 600.00 0 13 S 14 13 E 760.05 760.00 700.00 0 15 S 8 34 E 860.06 860.00 800.00 0 20 S 2 49 E 960.06 960.00 900.00 1060.06 1060.00 1000o00 1160.06 1160.00 1100.00 1260.06 1260.00 1200.00 1360.06 1360.00 1300.00 1460.06 14.60.00 14.00.00 1560.06 1560.00 1500.00 1660.06 1660.00 1600.00 1760.06 1760.00 1700.00 1860.06 1860.00 1800.00 0 19 S 4 52 W 0 16 S 4 52 E 0 12 S 10 23 E 0 3 S 28 20 E 0 7 S 36 33 W 0 5 N 86 2 E 0 4 S 14 59 E 0 14. S 50 46 W 0 22 S 89 57 W 0 22 N 77 9 W 1960.06 1960.00 1900.00 2060.07 Z060.00 2000.00 Z160.07 2160.00 2100.00 2260.07 2260.00 2200.00 2360.07 2360.00 2300.00 2460.07 2460.00 2400.00 7560.07 2560.00 2500.00 2660.07 2660.00 2600.00 2760.07 2760.00 2700.00 2860.08 2860.00 2800.00 0 13 N 67 53 W 0 0 N B1 31W 0 1 S 89 13 E 0 6 N 75 13 W 0 14 N :~3 58 W 0 22 N 13 0 E 0 26 N 48 28 E 0 16 N 71 50 E 0 22 S 62 39 E 0 32 S 56 14, E 2960.08 2960.00 2900°00 3060°08 3060.00 3000.00 3160.08 3160.00 3100.00 3260.08 3260.00 3200°00 3360.08 3360.00 3300.00 34.60.08 3460.00 3400.00 3560.09 3560.00 3500.00 3660.09 3660.00 3600.00 3760.09 3760.00 3700.00 3860.10 3860.00 3800.00 ENGINEER: J. HUSBAND 0 19 S 50 23 E 0 9 S 31 55 E 0 8 S 29 30 E 0 10 S 27 54 E 012 S 23 6 E 0 ZO S 25 19 E 0 22 S 16 54 E 0 24 S 1Z 54 E 030 S 9 13 E 0 33 S 10 16 E VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG 0.00 0.00 0.00 N 0.00 -0.01 0.36 0.02 S 0.00 -0.01 0.21 O.ZO S 0.15 -0.05 0.29 0.27 S 0.15 -0.21 0.22 0.64 S 0.28 -0.37 0.48 0.94 S 0.32 -0.52 0.52 1.29 S 0.41 -0.67 0.43 1.71 S 0.56 -0.89 0.69 2.19 S 0.69 -1.18 0.73 2.78 S 0.80 -1.51 1.01 3.38 S 0.89 -1.85 0.37 3.99 S 0.96 -2.12 0.4.5 6.51 S 1.04 -2.24 0.76 4.84 S 1.16 -2.28 1.36 5.01 S 1.25 -2.24. 0.89 5.04 S 1.33 -2.18 0.06 5.00 S 1.38 -2.28 0.22 5.03 S 1.27 -2.63 0.01 5.12 S 0.89 -2.99 O.Z1 5.12 S 0.42 -3.26 1.39 5.08 S 0.04 5 -3.50 0.00 5.09 S 0.28 W -3.58 0.03 5.12 S 0.35 W -3.68 0.38 5.11 S 0.49 W -3.69 0.63 4.82 S 0.75 W -3.33 0.36 4.30 S 0.7,?- W -Z.70 0.58 3.76 S 0.36 W -2.10 0.00 3.42 S 0.16 E -1.77 0.13 3.47 S 0.62 E -1.40 0.01 3.88 S 1.45 E -1.27 0.07 4.39 S 2.05 -1.24 0.00 4.63 S 2.30 -1.30 0.00 4.89 S 2.44. -1.37 '0.00 5.13 S 2.55 -1.46 0.00 5.42 S 2.68 -1.61 0.00 5.88 S 2.87 -1.84 0.00 6.50 S 3.09 -2.19 0.00 7.22 S 3.25 -2.55 0.10 7.98 S 3.41 -3.06 0.00 8.95 S 3.58 0.00 N 0 0 E 0.02 S 14 5 E 0.25 S 36 57 E 0.31 S 30 4 E 0.70 S 23 11 E 1.00 S 18 62 E 1.36 S 17 48 E 1.80 S 18 16 E 2.30 S 17 27 E 2.89 S 16 6 E 3.50 S 14 4.4 E 4..10 S 13 29 E 4..63 S 13 1 E 4.98 S 13 30 E 5.16 S 14 2 E 5.21 S 16 49 E 5.18 S 15 25 E 5.19 S 14 12 E 5.20 S 9 53 E 5.16 S 4 41 E 5.08 S 0 24 E 5.10 S 3 10 W 5.14. S 3 57 W 5.14. S 5 26 W 4.88 S 8 53 W 4.36 S 9 Z7 W 3.T8 S 5 23 W 3.4.2 S 2 20 E 3.53 S 10 10 E 4.14 S 20 27 E 4.84 S 25 0 E 5.16 S 26 25 E 5.46 S 26 30 E 5.73 S 26 24. E 6.05 S 26 ZO E 6.55 S 26 0 E 7.19 S 25 26 E 7.91 S 24 14 E 8.68 S 23 9 E 9.64 S 21 47 E COMPUTATION DATE: 20-MAY-90 PAGE ARCO ALASKAt INC. gG!- 8 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 22-APR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: J. HUSBANO INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 3960.10 3960.00 3900.00 4060.11 4060.00 4000.00 4160.11 ~160.00 4100.00 4260.11 4260.00 4200.00 4360.11 4360.00 4300.00 4460.12 4460.00 4400°00 4560.12 4560.00 4500.00 4660.12 4660.00 4600.00 4760.12 4760.00 4700.00 4860.13 4860.00 4800.00 034 S 8 29 E 029 S 2 31 E 0 30 S 1 54 W 027 S 7 31W 0 27 S 12 54 14 014 S 9 3 W 0 19 S 28 43 14 0 28 S 22 44 14 0 30 S 22 43 14 030 S 22 18 14 -3.56 0.11 9.91 S 3.73 E -4.08 0.13 10.82 S 3.82 E -4.64 0.00 11.70 S 3.83 E -5.24 0.00 12.54 S 3.76 E -5.86 0.13 13.32 S 3.61 E -6.32 0.00 13.90 S 3.49 E -6.69 0.49 14.32 S 3.36 E -7.38 0.24 14.99 $ 3.03 E -8.16 0.00 15.76 S 2.66 E -8.97 0.00 16.58 S 2.29 E 10.59 S 20 38 E 11.47 S 19 27 E 12.31 S 18 6 E 13.09 S 16 40 E 13.80 S 15 9 E 14.33 S 14 7 E 14.71 S 13 13 E 15.29 S 11 26 E ) · 15.98 S 9 35 E 16.74 S 7 51 E 4960.13 4960.00 4900.00 0 22 5060.13 5060.00 5000.00 0 8 5160.20 5160.00 5100.00 3 37 5260.54 5260.00 5200.00 5 33 5361.27 5360.00 5300.00 8 14 5462.69 5460.00 5400.00 10 44 5564.87 5560.00 5500.00 13 3 5668.08 5660.00 5600.00 15 47 5772°82 5760.00 5700.00 18 42 5879.63 5860.00 5800°00 21 55 S 20 23 W S 73 49 E N 51 17 E N 56 20 E N 48 30 E N 43 55 E N 46 2 E N 51 24 E N 52 1 E N 48 14 E -9.75 0.22 17.39 S 1.95 E -10.09 1.SB 17.78 S 1.84 E -6.83 2.77 15.49 S 4.17 E 1.24 1.85 11.03 S 10.98 E 13.29 2.92 3.57 S 20.44 E 30.08 2.21 8.19 N 32.48 E 50.97 2.75 23.09 N 47.24 E 76.46 3.27 39.87 N 66.43 E 107.54 3.26 58.90 N 144.99 2.36 17.49 S 6 23 E 17.88 S 5 55 E 16.04 S 15 4 E 15.56 S 44 51 E 20.75 S 80 5 E 33.50 N 75 51 E 52.58 N 63 57 E 7T.47 N 59 2 E 91.04 E 108.43 N 57 6 E 83.00 N 119.71 E 145.67 N 55 16 E 5988.18 5960.00 5900.00 23 46 6098.01 6060.00 6000.00 25 8 6209.17 6160.00 6100.00 26 34 6321.54 6260.00 6200°00 27 35 6434.56 6360.00 6300.00 27 58 6548.03 6460.00 6400.00 28 29 6662.05 6560.00 6500.00 28 58 6776.62 6660.00 6600.00 29 24 6891.68 6760.00 6700.00 29 52 7007.10 6860.00 6800.00 29 51 N 46 49 E N 46 50 E N 46 43 E N 47 16 E N 48 40 E N 48 33 E N 48 34 E N 48 31E N 48 41 E N 49 17 E 187.18 1.32 232.53 1.51 280.99 1.26 332.19 0.68 384.83 0.49 43E1.43 0.76 493.20 549.09 0.53 605.99 0.33 663.63 1.51 111.60 N 150.77 E 187.58 N 53 29 E 142.71 N 183.85 E 232.74 N 52 11 E 175.93 N 219.23 E 281.09 N 51 15 E 210.94 N 256°67 E 332.23 N 50 35 E 246.18 N 295.80 E 384.84 N 50 14 E 281.59 N 336.06 E 438.44 N 50 2 E 317.86 N 377.1t E 493.20 N 49 52 E 354.B9 N 418.99 E 54,9.09 N 49 44 E ) 392.54 N 461.67 E 605.99 N 49 38 E 430.40 N 505.13 E 663.63 N 49 34 E 7120.34 6960.00 6900.00 26 2 7231.26 7060.00 7000.00 25 32 7342.10 7160.00 7100.00 25 33 7452.93 7260.00 7200.00 25 31 7563.63 7360.00 7300.00 25 17 7674.20 7460.00 7400.00 25 18 7784.46 7560.00 7500.00 24 5 7892.86 7660.00 7600.00 21 19 7999.38 7760.00 7700.00 19 7 8104.37 7860.00 7800.00 16 16 N 48 5 E 716.69 N 47 59 E 764.67 N 49 10 E 812.46 N 50 24 E 860.23 N 51 49 E 907.72 N 50 21 E 954.86 N 44 21 E 1001.21 N 46 49 E 1042.87 N 50 22 E 1079.52 N 56 35 E 1111.39 2.32 0.46 0.46 0.50 0.66 2.91 2.65 2.62 2.35 3.17 465.08 N 545.30 E 716.69 N 49 32 E 497.38 N 580.82 E 764.68 N 49 25 E 529.01 N 616.65 E 812.47 N 49 22 E 559.86 N 653.13 E 860.25 N 49 24 E 589.71 N 690.08 E 907.73 N 49 29 E 618.92 N 727.12 E 954.86 N 49 36 E 650.81 N 760.85 E 1001.22 N 49 27 E 680.15 N 790.59 E 1042.90 N 49 18 E 704.49 N 818.01 E 1079.56 N 49 16 E 723.51 N 843.66 E 1111.41 N 49 23 E COMPUTATION DATE: 20-MAY-90 PAGE -'7 ARCO ALASKAt INC. DATE OF SURVEY: 22-APR-1990 NG! - 8 KELLY BUSHING ELEVATION: 60.00 FT PRUOHOE BAY NORTH SLOPE, ALASKA ENGINEER: J. HUSBANO INTERPOLATED VALUES FOR EVEN 100 FE~T OF SU~-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL OEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH OEG HIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 8208.07 7960.00 7900.00 14 43 8311.37 ~060.00 8000.00 14 23 B¢14.66 8160.00 8100.00 14 45 851B.Z3 B260.00 8ZO0.O0 15 19 8621.96 8360.00 8300.00 15 31 8725.77 8460.00 8400.00 15 36 8829.59 8560.00 8500.00 15 46 8907.00 8634.50 8574.50 15 46 N 64 10 E 1138.36 N 71 29 E 116Z.90 N 72 8 E 1186.82 N 70 40 E 1Zll.82 N 68 36 E 1237.76 N 67 29 E 1264.22 N 66 48 E 1291.00 N 66 48 E 1311.10 2.1g 1.00 0.79 0.57 0.51 0.24 0.00 0.00 737.15 N 867.45 E 1138.36 N 49 39 E 746.80 N 891.44 E 1162.92 N 50 3 5 754.73 N 916.07 E 1186.93 N 50 31 E 763.27 N 941.61 E 1212.11 N 50 58 E 772.89 N 967.45 E 1238.27 N 51 23 E 783.35 N 993.26 E 1265.00 N 51 44 E 794.Z4 N 1019.1~ 5 1292.07 N 52 4 E 802.5Z N 1038.47 E 1312.42 N 52 18 E COMPUTATION DATE: 20-MAY-g0 PAGE 8 - ARCO ALASKA9 INC. WGI - 8 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER 13 3/8" CASING TOP 7" CASING 9 5/8" CASING SAG SHUBLIK TOP S~D ZONE ~ ZONE 3 ZONE 2 ZDNE lB LAST GCT READING PBTD BASE SAD BOTTOM 7" CASING TD DATE OF SURVEY: 22-APR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: J. HUSBAND INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 963" FNL & 1060' FELt SEC11T11N R14EtUM MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 8793.75 8525.51 8465.51 790.40 N 1010.19 E 8860.00 8589.27 8529.27 797.49 N 1026.73 E 8888.00 8616.21 8556.21 800.49 N 1033.72 E 8905.00 8632.58 8572.58 802.3! N 1037.97 E 8907.00 8634.50 8574.50 80Z.52 N 1038.47 E 3481.00 3480.92 34Z0.92 5.99 S 2.92 E 8000.00 7760.59 7700.59 704.6Z N 818.17 E 8308.00 8056.73 7996.73 746.52 N 890.65 E 8356.00 8103.Z3 8043.23 750.Z3 N 90Z.O0 E 8397.00 814Z.92 808z.gz 753.35 N 911.80 E 8433.00 8177.73 8117.73 756.17 N 920.53 E 8433.00 8177.73 8117.73 756.17 N 920.53 E 8520.00 8261.71 8201.71 763.42 N 942.05 E 8570.00 8309.92 8Z49.gz 767.93 N 954.51 E 8782.00 8514.15 8454.15 789.Z2 N 1007.25 E COMPUTATIO'N DATE: gO-MAY-90 PAGE ARCO ALASKA, INC. WGI - 8 PRUDHOE BAY NORTH SLOPE~p ALASKA MARKER 13 3/8# CASING TOP 7" CASING 9 5/8" CASING SAG SHUBLIK TOP S~D ZONE 4 Z ONE 3 ZONE g ZONE 1 B LAST GCT READING PBTD BASE SAD BOTTOM 7" CASING TD DATE OF SURVEY: ZZ-APR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: J. HUSBAND SURFACE LOCATION = 963' FNL E 1060' FEL, SEC11 T11N RICEmUM MEASUREO OEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3481.00 3480.92 3420.9Z 8000.00 7760.59 7700.59 8308.00 8056.73 7996.73 8356.00 8103.23 8043.Z3 8397.00 814Z.92 8082.9Z 8433.00 8177.73 8117.73 8433.00 8177.73 8117.73 8520.00 8Z61.71 8201.71 8570.00 8309.92 8249.9Z 8782.00 8514.15 8454.15 5.99 S 2.92 E 704.6Z N 818.17 E 746.52 N 890.65 E 750.23 N 902.00 E 753.35 N 911.80 E 756.17 N 920.53 E 756.17 N 920.53 E 763.42 N 942.05 E 767.93 N 954.51 E 789.Z2 N 1007.25 E 8793.75 8525.51 8465.51 8860.00 8589.27 8529.27 B888.00 8616.21 8556.21 8905.00 8632.58 8572.58 8907.00 8634.50 8574.50 790.40 N 797.49 N 800.49 N 80Z.31 N 8OZ. 52 N 1010.19 E 1026.73 E 1033.72 E 103'7.97 E 1038.47 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH B907.00 8634.50 8574.50 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 131Z.4Z N 52 18 E SCHLUMBEROER O i RECT I ONAL SURVEY COMPANY ARCO ALASKA. 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NEUTRON G/R 7-9 6-9-90 DIFF~; TEMPERATURE 7-S4 6-9-90 COMP, NEUTRON G/R t2-t8 6--4-90 CET t 2-t 8 6-4-90 CBT t6-'~....- 5-29-9~ CBT t 6-.--~ 5-29-90 G/R t6-22 5-29-90 CET WGI-5 6-S-90 PERF RECORD WGI-6 5-30-9.0 PERF RECORD WGI-7 6-~ -90 PERF RECORD WGI-8 6-2-90 PERF RECORD RUN 1, RUN t , RUN t , RUN t, RUN t , RUN t , RUN t , RUN I, RUN i , RUN t , RUN t, RUN i, RUN i , RUN I , RUN I , RUN i , RUN i , RUN i, RUN i RUN i , RUN i, RUN t , RUN i , i 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 2' 5' 5' 5' 5' 5' A'FLAf AI'LAf A 'I'L A,? ATI_A~: A'FLA$ ATLAS A I'LA~,' A'TLAf ATLAA~ ATLAS A'¥L. AA~ A]'LAf A'I'LAA~ Al'LAS 5'CH 5'CH $CH 5'CH $CH $CH .~'CH $CH SCH PLEASE SIGN AND RETURN THE AT];C~C, W4ED COF'Y RECEIVED BY ....... ~ OT~r _~-~F~ HAVE A NICE DAY' · _Al s & Gas Cons. SALLY HC)FFECKER. ATO-~ 529 AS RECEIPT OF DATA. APPROVED~ TRAN$~ 9~218 DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA .TEXACO A N C H 0 R A G E, A L A .';,' K A DATE' 5/S0/90 REFERENCE:~ ARCO CASED HOLE FINALS i -T 5-23-90 COLLAR t -9 5-2S-90 PFC 5-4 5-27-90 COLLAR 6-t2 5-26-90 PDK-tO0 G/L C~L 9-~ 5-2~ -90 PERF RECORD 9-~ 5-2~ -90 PERF RECORD i:1-5 5-27-90 F'DK-iO0 G/R CCL it-iS 5-27-90 F'DK-tO0 G/R CCL i t-16 5-28-90 CONF'., NEUTRON G/R ~4-7 5-26-90 COMF'~ NEUTRON G/R t 5-4 5-24-90 SONAN i5-4 5-24-90 DIFFERENTIAL TEMF'. WGI-5 ~ <-26-90 COLLAR W6 I-7 5-22-90 COLLAR WG]:-8 5-24-90 P' '" RUN I;,' I.j N RUN R I.j N R U N I:,.: U N RUN RUN RUN RUN I;:fJN RUN RUN RUN PLEASE RECEIVED BY HAVE A NICE DAY! JUN - SALLY HOFFECKER 'Anchorage SIGN AND RETURN 'THE ATTACHED. COF'Y AS RECEIPT OF DATA AF' PROVED TRAN$~ 90t98 DISTRIBUTION :~ CENTRAL FILES ~ PHILLIPS '"' CHEVRON F'B WELL I::'II_E:S D & M R.& D ~ EXTENSION EXPLORATION ~ BPX ~ EXXON ¢ STATE OF ALASKA MARATHON TEXACO ~ MOBIL ATLAS;' A'I'L. Ai: A'I'L.A~;' A TI_ A ~," ~" C I--I ~' L: H A T L. A .'!/ A'I I_ A ;~7 A '}"L A ,5.' A'i I.. A ~" A 'l t._ A ,? ATLAS AFL. A;.;' A TI_A ;i' A'TLA~; ARCO AI...A,VKA, INC, F',O, BOX ~8(~S6~ ANCHORAC;E, AL.A,~'K A 995t DATE' 5-4-90 , ...... i" ·" · RE:.FEI'4:ENC[:.: ARCC) I)IF;,'ECTIONAL DATA tt.-2':2 3-30-90 . MWD D:[RECTI[)NAL :91JF(VEY DATADR]:I... W(.';. ]: -..8 4-.::~--90 HWD DIF,'ECI'IONAI... ,S'URVEY I)A'I"AI)R]:L. F'LEA,":~E ,<ZIGN AND RETURN 'I'I"IE AT'¥ACHED COF'Y AS RIECEIF'T OF I)A'I"A. F~I:'.-CE.I VE:D BY ................................... REEEIVED ~'ALLY HOF'F'ECKER ATO'"t 5"~9-- MAY 1 1 1990 011 & Gas (]one. Commisslo~ /mchomge D I $1'R I BUT ]: ON CENFRAE FILES C H E V R 0 N D & M · ..'"' EXI'E:N$ION [:.XF' LORATION .,-~' EXXON HARATHON MOB I L F'HIL. LIF'$ ~: F:' B W E 1. L F I L E $ (') ,.. C 0 F' I E:.~' ) R & D ~" BPX · ..'~ ST~'I'E OF ALASKA T E: X A C; 0 AI:;;C)[] AL. ASKA, liNC ~ I='.0, BOX ~,30S60 · *o o! · ** ,i ANCHOF, AC, E, AL..A~I<A 99~ DATE' 5-2-90 F~E. FEF~E:.NCE' ARCO C~.~$EI) HC)LE FINAI...$ t-7 4-.i 8-9{) F I.~L. DLJC] IC]N RLJN t, t ~ 4 t 8'-9~ F'ERF F',E:.C.)I~,D RUN i , · " ' '1 ~' '~ .... ~ '" .... ~ ~:' 4-"2~':-'"'9¢:) CUI...L. Ah./F' E:.I'~I'- RI IN i ./ ....., ... · - ~ () 4 .- ~ 9- 9 () V F F;,' l' I I.. C)(; R LIN ~ , .... ~ ~ 4- 24 -- 9 (:) F:' R C] D LJC T I 0 N P K R R LJ N~ , '7-i ~ 4.-2~.-.~ PFC RUN ~ , ?.-.':~'~, 4-.-"~-o~ COMPL. Ei:I']:CIN RECORD RLJN i ~S--.26 i.-2~--9e3 CC)I_LAI;: TO ;:;'ETF:'ATCH RUN ~--~ ~ ~ --i .--9~3 F:'ERF:' F;,'UN 4 , i'?-:3 4..-2~.~--~ (:CI_ F;:.UN ~ , 7-. ~ ,.'3 ~ -~ 4-..9E) COL. I_AF;: i"O ,S'E::-F F'I...LJG RLJH i , PWDWi -2 4-'22-.~.-} [.,El RUN ~ , F'WDW~ -2 a ~"",:,.."" 9 <~ CE:I' RLJN I/,IG :1:-8 4-'2~-9~ GI-,-CCI_ RUN WG ]:-'8 4-.',=2-'9~ CBT RUN i, WG[-8 ,a.-:~"~-.'o~,=..- ..., CE'I' RUN t, PLEASE: SIGN ANI) REI'URN THE ATTACHE:D C;C)F:'¥ AS F~:EC)E':IF'I' C)F" DATA. .5:" 5" 5:" 5" '.ii:" 5" 5" 5" 5" 5" 5" 5" 5" >7 C; H ,"] C H AT I... A A '1' I.. A ,~<; A'i' I.. A,? ~:'~ "i' L A ;S' ,~'? C I..I I. ~ I... ,? I..ll...,? A T' I.. A ~,' HI... S S C I-I SCI..I SCH ,S'CH RECEIVED BY I-.lAVE A NICE ,DAY, R , - SALLY FICIFI='ECKE:R MAY'I 1 1990' APF'ROVE:D ATO- t 529 Naslm 011 & Gas Cons. Commission Anchorage DISTRIBUTION .,. CENTRAL FILES ..'" PHILLIPS ~ CHEVRON F'B WELL F'ILES D & M R & D · -~'EXTENSION EXF'LORAI'ION ...'"' BF'X ...'"EXXON ...'~- STATE OF ALASKA MARATHON TEXACO · . MOBIL * I'HE AF'I4: FrOR iS-ii IS 5~'"e29-206'$3, ARCO ALASKA, INC. F'.O. BOX iOOS6('] ANCHORAGE, ALASKA DATE' REFERENCE' ARCO OPEN HOLE FINALS HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 AS RECEIPT OF DATA~ MAY - l' 1990 Oil & Gms Cons. C i'&2' 2'&5' 2'&5' 2'&5" 2'tvd 2 ' md 2'&5' 2'-. &5'%vd at' Las afla~ a ttaa' atlas a t,. Las spe DISTRIBUTION CENTRAL FILES ~ ~ PHILLIPS CHEVRON PB WELL FILES D&M ~ ~ R&D EXTENSION EXPLORATION ~ ~ BPX EXXON ~ STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL ARCO AI..ASKA, INC i:'~ O, BOX AN._,HORAGE., ALASKA 995t DATE · .5'-~ -98 REF:'EREiNCE:': ARCO MAGNETIC TAPE(S) WITH LISTING(S) ~ ~-22 4-2S'-90 BHCA/DIFL../CN-ZDL ;x~ ~Y"~_~ J09:~4262 · RE:CIEIYED BY .................. HAVE A N I..,E DAY! SALLY i"IOF:F:'E C:K EFt: ATO .... ~529 ED I~A¥ - ? 1990 AFiPROVED Alaska Oil & Ga~ Cons. Commisslo~'R AN Anchorage DISTRIBUTION CENTRAL FILES (CH) CHEVRON D & M TAMMA$ BROWN (OFi) EXXON MARATHON MOBIL.. PHILLIPS F'B WFLI.. F:IL. Ei:$ F.'. & D · .""' BPX :~TATE OF' ALASKA TFXACO ATLAS SF'E AF~C.'.O ALAS:KA, INC., P~O~ BOX i(?,,036(3 ~ ANCHORAGE, ALA~'KA 995i,3 DATE · 4-24-90 RF..:F'E~RENCE~ ~,R'CL DIRECTIONAL I,A~ L, JGI-8 4-.5-90 MW!) D I RECT.1]ONAL ,'.':.:URVEY MWD DIRECTIONAL :~URVFZY F'I..E~,E ,?IGN AND RE]'IIRN THE ATTACHEI) ¢':FIF'Y A2 RECEIF'T OF DATA~ '¥ E L. E C A N A SALL. Y I"!0 F"F EC'I< E:R // APR 2 G 1990 APF:'ROVr~:D ~...~.~ Oil A G~ Cons. Comml~lon N S :~ <~e'~ ~ :~ '~mge DISTRIBUTION CENTRAL FILES ,I"IE:. ~ RON EXTENSION EXPLORAT ~ tin EXXON MARATHON MOBIL PHILLIPS ~ F'B WEL_L FILES (2 COF'IE.S') R & D :D BF:'X · "' STATE OF AL.A..9, KA · Ir . TEXACO April 18, 1990 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: WGI-5,6,7, & 8 As-builts Dear Mr. Chatterton: Enclosed are copies of the subject As-builts for your information. If you have any questions, please call me at 263-4618. Sincerely, Engineering Aide DW cc: File W1-1 Cons. Commission Anch0rag~ ARCO Alaska inc. is a subsidiary of Atlantic Richfield Company AR3B-6001 -A ii ! · 4 · 6 ® 7e 8e PRUDHOE BAY R ECEI VED NOT TO SCALE APR 2 3 tgon .... LEGEND L. OCA TED MTHIN PRO TRA.~_,~ & Gas Cons, Co~J,S~i~jori SEC T/ON I!, T. II N., R, 14 E,, UMIA T MERIDIAN, ALASKA Anchoraga e CONDUCTORS 4S-BUlL T THIS SURVEY · EXISTING CONDUCTOR A.S.P. COORDINATES NOR THING EA S TING 5,971,185.66 685,180.73 5,971,535..79 685,097. 72 5,971 685,12,5.51 5 , 971 t 302. ,FI 685, 153. PLANT COORDS. tv E~19. 97 tV 609.83 369.90 569.81 NO TES h) BASIS OF '[.OCA T'K)N PER NGI MONU~TS NI-C & NPD. 2.) ALASKA STATE PLANE COORDINATE$ ARE ZONE 4~ k- 0.9999390. 3.). BASIS OF ELEVATiON 1S ARCO DA TUM LM.L.L.IFJ. q) REF. FIELD BOOK. 90-06 p. 34-4R './151~0] ISSUED FOR t~FORM4 T/OH .~-vzsza~ GEODETIC POSITION LA T. LONG. 70' 19'34.551 148'29 '53.494 70° I 9 ' 38. 014' 148'29 ' 55. 70'19'56.858' 148 ' Z~ ' 54 . 937 , L OCA TION IN SECTION 1080o I 0_~_ ' I~L 728' F~. 1109' FEL I~' F'EL 1060' F.R. BELL & ASSOCIATES ARCO Alaska, Inc. ~ CONDUCTOR A S-BUlL ,wGI PAD~ WELLS 5~6~ 7 ~'z//,/~o l~'"" ~/~ I~°. ~A NSPO CEA"6000-O05 . O ID:ARCO ALASKA/DOYeN 9 TEL N0:907-659-5614 STATE OF ALASKA gPR 1 o OA, COn E V T o ~as~'OJl& GasCons. Com~ission ~,0.~,~, Inspection , Anchorage ~ l ~ · _~ -~_~.~ o. . / Conttacto~ ,~ Oeneral Housakeepin: .... ~ RIB.. ~ __ .- ~ m .... I m Il _ Tank ._ ~ ,,. - , ~nule ~l, ~ i I _ I I - . , . t- t._..~ ~; ........ ~-: ..... iiii i . i i ii LI ~ltnd H,C,R. Valve Kill Line Valves Check Valve ~880 PO1 .... Ill I I ' ~ . -· ..... _.lJ~asin8 Set ~ 3q~_ ....... ft. ,. ' :,antativ. ~. - ..... Full-~arlt ~restur[ __~¢~ ,,__ Pump incr. aloe. pres. 200 psat .... Full Chir$e Fraoture Attaifledl~nin~oee. Contrelsl Naste~. ~_C~_ :..._ ........ Eemo~e v~5 Blinds ew/~eh "' -?~ i _ _ _ {~ i , ...... 7: ' _g~ily a~d ,Fi~or . Inside BOP~T.s~ ~resmure_ _ Choks Nani~old__ V.~ Test F~emouro ~5~0o .. Adjustable chokes:__: __[ .... . .............. _ ~d ~hoke ltepmit or Replacement o% Eailed equipment to bm made within days and Co~ssion o{~tc, note{lad. ' .~ -- __ ~___ :~: : , oftI. - AO&CCC co - Operator ce - Supervisor March ~0, 1990 Telecopy~ (907)276-7542 Mr. John Gtllespie Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit WGI-8 ARCO Alaska, Inc. Permit No. 90-49 Sur. Loc. 963'FNL, 1060'FEL, Sec. 11, TllN, R14E, I~M. Btmho!e Loc. 18'FNL, 56'FWL, Sec. 12, TI]N, R14E, t~M. Dear Mr. Gillespie: Enclosed is the approved application for pe~it to drill the above referenced well. The permit to drill, does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Co~tssfon may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a dlverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. VerM truly ~..~.ours, ,/ i .. ' / ," ' '~, V. Ch'a~'teftoA Chai~an of Alaska Oil and Gas Conservation BY ORDER OF THE COMMISSION dlf Enclosure cc.. Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o enc!. . ...... . STATE OF ALASKA ALASK.. .L AND GAS CONSERVATION ~, ~MISSION PERMIT TO DRILL 20 AAC 25.005 ~',45 ..~',uJ'e~:7'/,~,t) ~,,,Ez./ la. Type of work Drill ~/' Redrill :l lb. Type of well. Exploratory Re-Entry - Deepen 2. Name of Operator ARCO Alaska, Inc. StratigraphicTest ~ Development Oil Service i~ Developement Gas : Single Zone ~ Multiple Zone ............ -- v '~___-2:_ 3. Address 2.0. 3ox 100360, Anchorage, AK 99510-0360 4. Location of well at surface 963'FNL, 1060'FEL, Sec.ll, TllN, R14E, UM At top of productive interval 150'FNL, IO0'FEL, Sec.ll, TllN, R14E, UM At total depth 18'FNL, 56'FWL, Sec.12, TllN, R14E, UM 12. Distance to nearest 13. Distance to nearest well property line WGT- 7 from 0-5500'MD 5 2 2 4 ' feet 10 6 ' feet 16. To be completed for deviated wells Kickoff depth 50oo feet 25~; Maximum hole angle 0 18. Casing program size Casing 20" Weight 91.5# 68~ L- Hole 30" 17-1/2" 13-3/8" ....~...~ - 1 / 4" 9-5/8" 8-1/2" 7" 5. Datum Elevation (DF or KB) Pad 19' RKB 58 feet 6. Property Designation ADL 28302 ALK 2313 BHL 7. Unit or property Name Prudhoe Bay Unit 8. Well number WGI-8 9. Approximate spud date 04/10/90 14. Number of acres in property 2560 10. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 11. ~pe Bond(see20AAC25.025) S'Latewiae Number Nog U-630610 Amount $200,000 15. Proposed depth(MDandTVD) 8955'MD 8647'TVD feet psig 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2 8 i 0 psig At total depth fTVD) 3 6 5 6 ' Quantity of cement (include stage data) 47~ 29# Specifications Grade I Coupling [ Length H-40 [Weld i 80' 180/K-~5 BTC 3462' L-80 ~TC/MOD 18327' L-80 tBTC ! 891' TVD 119' 3500' 8113' 450 SX G 20"00~ Pb'le'~-~-[ t , 8647' 300 sx Latex G Setting Depth Top Bottom MO,I 1 MO I 38' I 38' I 3500'1 19. To be completed for Redrill, Re-entry, and Deepen O)erations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True Vertical depth 'Anchoral~ true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch ~"" Diverter Sketch ~ Drilling program ¢ Drilling fluid program 12i" Time vs depth plot [] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements Conditions of approval Samples req,uired Fi. Yes ~'No Mud log reqtJir, e"~-~'~ Yes. ,~No Hydrogen sulfide.measures [] Yes /'~No Directional survey required ,~Yes [] No Required workingj;m~ssure forJ~OP~ i-]2M; J~ 3M; ,~r' 5M; [] 10M; ~ 15M . by order of pproved by( I.~'. L~ ,~,~~//~,~ Commissioner the commission Form 10-401 Re~2-1:85 -/ / 21. I hereby certify that the foregoing is true and correct to the best of my knowledge~ Signed //~ ~) Z~~<., Title Regi°na: Drilling Engineer Date~¢~, ¢'¢ Permit Numb~ APl number Approval date See cover letter ¢~-~ [ 50-O~,-~zo~ 103/30/90 [ for other requirements i 0 RKB EI_IEVATION fiR' , '-~ i AR( O IC. wgi- g SHL: U 1 IN 14E 11 963' ~' 1060' FEL THL: U 11N 14E 11 150' ~L 1~' FEL BHL: U 11N 14E 12 18' ~ 56' ~L N49~' ~ 2~ 30~) 13-3~' C~g ~ )=35~ ~=35~ DI :~ 4~ ~5~ ~5~ D~ gOP ~5~ 10.0 1~.0 6~ AV~GE ~GLE = ~ 58' 7~ ,- [_ Gl0 ~7210 ~ ~7368 D~7~ K-5 ~7539 ~ ~31 8~ ~ ~t~ ~~8 ~83~ D} ~=11~ ~~G~[ ~8108 T~8~;8 D~1210 -X ~-5~' C~8 ~8113 ~83~ D~1212 ~SAG~v~ T~8123 ~8375 [~1217 TARG~ ~8208 ~70 r~l~7 G~ ~23 ~9~ I '~laS0 9~ ~ ~ ~7 ~8955 Di ~1~2 I0~0 . .................................................. 0 1~ 2~ 3~ 4~ 5~ 6000 ~RTIC~ SE~ION PRUDHOE BAY DS WGI-8 PRELIMINARY DRILLING PROCEDURE 1. MIRU drilling rig. NU diverter and function test same. 2. Drill 17-1/2" vertical hole to 3500' TVD/MD. . Set 13-3/8" casing and cement same. Nipple up BOPE and test to 5000 psi. Test casing to 2500 psi for 30 minutes. 4. Pick up 12-1/4" BHA and RIH. Drill 10 ft of new hole and perform leakoff test. o Ddl112-1/4" hole to 5000' TVD/MD and kick off. Build angle at 2.5 degrees per 100' to 24 degrees 58' at 5967' TVD/5998' MD. . Ddll 12-1/4" hole to 9-5/8" casing point at 8113' TVD/8364' MD maintaining the 24 o 58' hole angle in a N 49 44' E direction. 7. Set 9-5/8" casing and cement same. 8. Pick up 8-1/2" BHA and RIH. Test casing to 4000 psi. 9. Drill 10 ft of new hole and perform EMW test. 10. Drill 8-1/2" hole to 8647' TVD / 8955' MD in a N 49 44' E direction using MWD logs. 11. Set 7" liner and cement same. i2. Clean out the 7" liner and 9-5/8" casing and test liner / casing to 4000 psi for 30 minutes. Circulate well to brine and freeze protect with diesel. 13. Release drilling rig. Run cement bond logs 7 days after rig release. 14. MI and RU completion rig. Run 7" tubing and packer assembly. Notify State to witness Mechanical Integrity tests as per requirements for a Class 2 Gas Injection well. Since this is a Class 2 Gas Injection well, it must comply with 20 AAC 25.030 g (1 & 3) and 25.412 (a- e). NU 7" tree and test to 5000 psi. Test tubing and casing to 4000 psi. Release completion rig. 15. Rig up wireline unit and perforate. NOTE; PRUDHOE BAY DS WGI-,., PRELIMINARY DRILLING PROCEDURE CONT. a. Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. WGI-7 is about 106' from the proposed well down to approximately 5500' MD where it departs. c. The ddlling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). e. Based on previous logs, no potential productive zones are anticipated above 3500' TVD. f. No potential hazardous levels of H2S are anticipated in this well. SOLIDS CONRROL EQUIPMENT Shale shaker Mud cleaner Centrifuge Trip tank Degasser Pit level indicators (visual and audio) Fluid flow sensor Fluid Agitators ARCO ALASKA, INC. wgi-8 N49 44' E -3000 4000 E - W COORDINATES -2000 -1~ 0 1000 2000 3000 1000 300 2000 r,.)o I Z -1000 -2000 -3000 -3000 } i i i I I I I I I .... ' .............................. WGI-03 8194 7881 /z:9 w~-5 Ii L 1-09 12 ............................................................... 4000 4000 3000 2OOO 1000 -2000 -2000 - 1000 0 1000 2000 3000 -3000 4000 ARCO ALASKA, INC. wgi-8 N4944' E E - W COORDINATES -3000 -2000 - 1000 0 1000 2000 3000 4000 3000 2000 1000 0 0 ~ o Z -1000 -2000 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 -3000 -3000 4000 -1000 -2000 -2000 -1000 0 1000 2000 3000 -3000 4000 AIK~U ALA~ lX~, wgi-8 E - W COORDINATES -400 -300 -200 -100 0 100 200 300 6370 500 500 400 400 300 300 Z 200 ~- 200 WGI-7 /~7 ~o ~oo Z 0 0 WGI-8 -100 -100 WGI-5 -200 -200 -300 ............................................................. 300 -400 -300 -200 -100 0 100 200 300 E - W COORDINATES 0 0 Z ~oo ~ I~'~/--0~ W 8 IV~/--O~ 7 W O~ IV~/- ? ~ 8 ~ ~ ~~. ~0 O~ ~ ~ ~ 8 IV~I-O~ I? O~ £/ ~/ DOYON 9 MUD SYSTEM BBLS 32 BBLS TRIP TANKS I [ D~--GASSER] (30 BBLS) (83BBLS) (97 ~LS) PI~.~. PIT (36 ~LS) (36 ~LS) DE~~ ~X PIT SUCTION PIT (448 ~LS) (122 ~LS) OTHER EQUIP~ - DRIT.T.ING FLUID SYSTEM (3) DERRICK FLO-LINE C~.~.~NER (1) PVT SENSOR PER PIT w/ visual and audio warning devices (1) AGITATOR PER PIT (1) DRILLING FLOW SHOW SENSOR w/ readout convenient to the driller's console SURFACE HOLE DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE I RISER 2000 PSI DIVERTER IFLOWLINE 10" BALL VALVE 10" BALL VALVE CONDUCTOR NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 10" VENT LINES ' WELL O , m I I , RIG MODULES NOTE: 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES RESERVE PIT JG 7/27/87 13-5/8" 5000 psi BOP STACK DIAGRAM . . , I PIPE RA 2. BUND RAMr~~ :3. SPOOL PIPE RA BRADEN HEAD ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 13-5/8" STACK TEST FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES . FUNCTION TEST CHOKES. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BOTTOM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PIPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 13. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. CHECK DEGASSER OPERATION. 16. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 17. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TEST DAILY. PBU DS WGI-8 MUD PROGRAM DEPTH DENSITY VIS YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) GELS GELS CC/30MIN (%) (%) MUD TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 to to to to to 13-3/8 9.2 100 40 6 csg pt. SET 13-3/8" CASING GEL-BENEX SPUD MUD DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 13-3/8" 9 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to to TREATED K-10 9.7 15 10 4 10 10 6 POLYMER K-10 9.8 10 6 2 4 10 2 4 LIGHTLY to to to to to to to to to TREATED 9-5/8" 10 15 10 4 10 6 5 9 POLYMER SET 9-5/8" CASING DEPTH DENSITY PV YP INT 10min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE , 9-5/8" 8.7 10 6 2 8 8 2 4 LIGHTLY to to to to to to to to to TREATED 7" Liner 9.1 15 10 4 10 6 5 6 POLYMER SET 7" LINER THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. ANY MAJOR CHANGES SHOULD BE DISCUSSED WITH THE ARCO DRILLING SUPERINTENDENT OR DRILLING MANAGER. CEECK LIST FOR NEW WELL PERMITS ITEM APPROVE D, ATE, (1)' Fee ~ ~,~ .~//~d~) 1. (9 thru ~3)'- ' 10. (10 and 13') ' 12. 13. (14 thru 22) ('LF3 thru 28) Company , ~ ~ ~ Lease & Well No. /~ ,, Is the permit fee attached .......................................... 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ................... ' Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ ~_ ... Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... ~ ... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. ~-- ,,, Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~-~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ' ~2T th Geology: Engin~ee~ng:' ~ ~ rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT oN/oFF POOL CLASS STATUS AREA NO. SHORE 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. **** LIS READ **** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/04/25 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/04/25 ORIGIN OF DATA: WGI8 TAPE NAME: PBU/EOA CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: WGI8.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/25 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC. WELL: WGI-8 API#: 50-029-22038 LOGGED: 04/13/90 LOCATION: 963' FNL, 1060' FEL, SEC. 11, TWP. llN, RGE 14E, PRUDHONE BAY FIELD EASTERN OPERATING AREA, NORTH SLOPE BOROUGH, ALASKA, U.S.A. RIG: DOYON 9 COMPANY REP.: BORDES SSDS ENGINEERS: GALVIN & KRELL COMMENTS: ALL DATA HAS BEEN DEPTH SHIFTED TO A SCHLUMBERGER CASEDHOLE GAMMA RAY LOG (GR-CET) PROVIDED BY ARCO. NEUTRON & DENSITY LOGS ARE CORRECTED FOR TOOL WEAR AND BOREHOLE GAUGE CHANGES. MATRIX=SANDSTONE @ 2.65 G/C3, FORMATION WATER SALINITY=il,500 PPM CL, FLUID DENSITY=i.0 G/C3 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT EWR MWD TVD CALC ROP MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD GR CET DRHO MWD CAL MWD GRC MWD FXE MWD NDIS DATDRL RHOB MWD EDIS DATDRL DEVI DATDRL NPSC MWD LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 GAPI 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 DEG 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT EWR MWD TVD CALC ROP MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GR CET DRHO MWD CAL MWD GRC MWD FXE MWD NDIS DATDRL RHOB MWD EDIS DATDRL DEVI DATDRL NPSC MWD FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 GAPI 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 DEG 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 ** DATA VERIFICATION (every 100 FT) ** DEPT EWR TVD ROP NN1 GR DRHO CAL RHOB EDIS DEVI NPSC 8175. -999. -999. 000 -999.250 7933.534 -999.250 250 72.625 .000 -999.250 250 -3.490 15.475 -999.250 8200. -999. -999. 000 -999.250 7957.649 -999.250 250 79.688 .000 -999.250 250 2.315 15.208 -999.250 8300. 2303. 3. 000 30.958 8054.129 115.576 618 66.938 -.065 8.400 409 25.694 15.291 45.325 8400. 2947. 2. 000 7.558 8150.569 59.805 428 90.188 -.013 8.400 560 49.485 15.377 22.735 8500. 3592. 2. 000 295.674 8246.973 106.272 000 14.047 .038 8.400 184 73.677 15.462 16.484 8600. 3649. 2. 000 599.849 8343.330 84.493 055 14.547 .006 8.400 191 98.253 15.601 16.500 8700. 3749. 2. 000 278.443 8439.594 125.956 184 16.406 -.003 8.400 198 123.146 15.819 14.593 8800. 3550. 2. 000 90.104 8535.754 98.723 200 16.359 .001 8.630 248 148.345 16.042 18.375 8900. -999. -999. 000 -999.250 8631.836 17.906 250 -999.250 .000 -999.250 250 173.765 16.099 -999.250 ** 111 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: WGI8.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/25 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 NFO NFl NN0 GRC FXE NDIS -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -1.888 -999.250 1.232 413.730 411.825 2360.000 83.909 .425 13.281 815.449 787.828 2993.789 135.724 .686 24.818 1235.000 1235.000 3608.000 26.456 .306 35.826 1199.864 1157.333 3655.599 21.074 .338 46.371 1321.798 3.296.596 3848.000 29.529 .491 57.027 1178.400 1094.100 3570.500 32.426 .347 67.909 -999.250 -999.250 -999.250 -999.250 -999.250 78.959 8175.00 TO 8950.00 FT ********** END OF FILE (EOF # 2) ********** ** FILE HEADER ** FILE NAME: WGI8.RPT SERVICE NAME: RLL VERSION #: V ~2.40 DATE: 90/04/25 MAX. RECORD LENGTH: FILE TYPE: E2 PREVIOUS FILE NAME: ** COMMENTS ** FILE SEQUENCE # 2 1024 ***** REPEAT DATA ***** 1. ALL DATA CURVES HAVE BEEN SHIFTED TO CASEDHOLE GAMMA RAY. 2. NEUTRON & DENSITY ARE CORRECTED FOR TOOL WEAR AND BOREHOLE GAUGE CHANGES. 3. DIRECTIONAL DATA FOR TVD CALCULATIONS WERE SUPPLIED BY "DATADRIL" AS DETERMINED FROM SINGLE SHOT FIELD DATA. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT EWR REPEAT FXE REPEAT RATE REPEAT NF0 REPEAT NFl REPEAT NN0 REPEAT NN1 REPEAT RHOB REPEAT CAL REPEAT GRC REPEAT NPSC REPEAT ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 2 4 0 1 68 OHMM 0 0 0 0 2 4 0 1 68 HOUR 0 0 0 0 2 4 0 1 68 FT/H 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 G/C3 0 0 0 0 2 4 0 1 68 INCH 0 0 0 0 2 4 0 1 68 P.U. 0 0 0 0 2 4 0 1 68 P.U. 0 0 0 0 2 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API ID ORDER# LOG TYP CLS MOD DEPT FT 0 0 0 0 FILE SZE PROC SPL REPR NO. LVL CODE 2 4 0 1 68 EWR FXE RATE NF0 NFl NN0 NN1 RHOB CAL GRC NPSC REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT OHMM HOUR FT/H CTS CTS CTS CTS G/C3 INCH P.U. P.U. 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 100 FT) ** DEPT EWR FXE RATE NF0 NN1 RHOB CAL GRC NPSC 8620.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 8700.000 3640.000 213.959 7.146 130.831 1155.000 2.193 8.450 30.017 17.639 8800.0O0 3174.998 71.836 6.405 152.490 853.669 2.242 8.400 27.568 22.102 8900.000 -999.250 -999.250 -999.250 110.902 -999.250 -999.250 8.170 -999.250 -999.250 ** 32 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: WGI8.RPT SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/25 MAX. RECORD LENGTH: FILE TYPE: E2 NEXT FILE NAME: 1024 8620.00 TO NFl -999.250 1091.000 875.164 -999.250 8950.00 FT NN0 -999.250 3864.000 3298.333 -999.250 ********** END OF FILE (EOF # 3) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/04/25 ORIGIN OF DATA: WGI8 TAPE NAME: PBU/EOA CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/04/25 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT