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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-09 PRUDHOE BAY UNIT 13-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 13-09 50-029-20671-00-00 181-158-0 W SPT 8381 1811580 2095 1363 1363 1363 1363 68 102 103 102 4YRTST F Bob Noble 6/5/2025 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 13-09 Inspection Date: Tubing OA Packer Depth 376 2350 2262 2210IA 1363 102 45 Min 2164 1363 103 60 Min 2123 Rel Insp Num: Insp Num:mitRCN250616213111 BBL Pumped:2.9 BBL Returned:2.7 Thursday, July 24, 2025 Page 1 of 1 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: Injector 13-09 (PTD #1811580) failed MIT-IA Date:Tuesday, June 10, 2025 8:05:46 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, June 10, 2025 7:26 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector 13-09 (PTD #1811580) failed MIT-IA Mr. Wallace, DHD performed passing PPPOTs on 06/06. Fullbore performed and offline MIT-IA on 06/09 that failed with a LLR ~ 0.375 gpm @ 2,350 psi. The well 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: Thursday, June 5, 2025 6:22 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector 13-09 (PTD #1811580) failed AOGCC MIT-IA Mr. Wallace, Injector 13-09 (PTD #1811580) failed its 4-year AOGCC MIT-IA on 06/05/25. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Operations is working toward shutting-in and freeze protecting the well. Plan Forward: 1. DHD: PPPOT-T/PPPOT-IC 2. Fullbore: Offline MIT-IA/Establish LLR 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 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, 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 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. 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: Injector 13-09 (PTD #1811580) failed AOGCC MIT-IA Date:Friday, June 6, 2025 7:39:43 AM Attachments:TIOChart.pdf 13-09.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, June 5, 2025 6:22 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector 13-09 (PTD #1811580) failed AOGCC MIT-IA Mr. Wallace, Injector 13-09 (PTD #1811580) failed its 4-year AOGCC MIT-IA on 06/05/25. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Operations is working toward shutting-in and freeze protecting the well. Plan Forward: 1. DHD: PPPOT-T/PPPOT-IC 2. Fullbore: Offline MIT-IA/Establish LLR 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 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 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 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. WELLHEAD= CRAY ACTUATOR= AXLESON OKB. ELEV = 78' BF. E-EV = _? KOP= 2800' Max Angle = 47" Q 7600' Datum MD = 1058& Datum TVD= 8800'SS 20" CONDUCTOR, 94#, K40, D= 19.124" 82' 13-3/8" CSG, 72#, L-80, D = 12.347" 2424' 5-1/2" TBG, 17#, L-80 TCI, .0232 bpf, D = 4.892" 9-5/8" CSG, 47#, L-80 BTC XO TO SOO-95 BTC 9253' Minimum ID = 3.726" @ 10103' 4-112" HES XN NIPPLE 4 1/2" TBG, 12.6#, L-80 TCII.0152 bpf, ID - 3.958" 10162' 7" SCAB LNR, 26#, L-80 VAMTOPHC, 10249' .0383 bpf, D = 6276" TOP OF 7"LNi 10250' 9-5/8' CSG, 47#, S00-95 BTC, D = 8.681" 10572' PERFORATION SUMMARY REF LOG_ BHCS ON 11/13/81 ANGLEATTOPPERF: 30" @ 10664' Note: Refer to Production DB for historical perf data SIZE SPF MEFWAL Opn/Sgz DOTE 3-3/8" 4 10664 - 10684 O 1226/91 3-118" 4 10742 - 10762 O 0621/84 3-118" 8 10772 - 10792 O 11120/82 3-1/8" 4 10772 - 10792 O 02/10/83 4" 4 10827 - 10831 S 01/31/83 4" 4 10832 - 10836 S 0128/83 4" 4 10851 - 10855 S 0124/83 112W DI 13-09 SAFETY NOTES: H2S READINGS AVERAGE 126 ppm WHEN ON MI. WELL REQUIRES A SSS V WHEN ON ML ":: CHROME NIPPLES .." 2026' -j5-1/2" HES X NIP (9-CR), ID - 4562" 279F H 5-12" X 4-12" XO, ID = 3.958" 2901' 9 5/8" X 7" BKR G2 ZXP LTP D w / TIEBACK,= 6.30" 91' 2115/8" x 7" BKR FLDCLOCK II HGR D= 62W' 10OW -j4-12" HES X NP (9-CM, ID= 3.813" 10103' 4-11/2" HES XN NP (9-CR), ID= 3.725" 10162 4-12" WLEG, ID= 3.958- ELMD TT NOT LOGG® 10250' BKR PORTED TIEBACK SEAL ASSY w / 4-1" HOLES, D = 6.140" Ili plk;!:i111111111M17i"97ttsIW&A W4GlP.eI:A]N71rBylP11IIII 10820' --17" BRIDGE RUG PRUDHOE BAY UNIT WELL: 13-09 PERMIT NO: 1811580 API No: 50-029-20671-00 SEC 13, T10N, R14E, 1290' FSL & 155' FWL DATE REV BY COMMENTS DATE REV BY COMMENTS 11/19/81 ROWAN 26 ORIGINAL COMPLETION 0728115 DJS/JMD SET PXN PLUG 0628/151 02/06183 N1 ES RIND 052321 TBD/JMD PULLED PXN PLUG 052121 04/30/11 WES RWO SCAB LN 05/01/11 PJC DRLG DRAFT CORRECTIONS 05/03/11 CR/ PJC FINAL DRLG CORRECTIONS Hilcorp North Slope, LLC 01/16/12 TMNJMD ADDED H2S SAFETY NOTE I a 4.OM 3,900 3,800 3.700 3,GM 3,500 3.400 3,300 3,200 3,100 3,000 2,900 2,800 2.700 2,600 2,500 2.400 2,300 2,200 2.100 2,000 1,900 1,300 1,700 1.6m 1,500 1,400 1,300 1,200 1,100 1,000 900 800 700 600 500 400 300 200 100 @112125 0119M @12&25 04W25 0411 &25 04,2325 OM7125 05+14125 @5121125 052&'25 DE {A25 300 290 230 270 26D 250 240 230 220 210 200 190 130 170 1fi0 3 150 m m 140 130 120 110 100 90 80 70 fi0 50 40 30 20 10 TIO Plot f Tubing — On ■ Bleed * Operable + Not Oper ♦ Under Eval Man. IA —� Man. OA Man. OOA Man. OOOA O Man. WHT FLN F wur UIRTALT11Mu_ TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name PRUDHOE BAY UNIT 13-09 Insp Num: milSAM210613192739 Rei Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 16, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-09 PRUDHOE BAY UNIT 13-09 Ste: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-20671-00-00 Inspector Name: Austin McLeod Permit Number: 181-158-0 Inspection Date: 6/13/2021 Packer Well 09 Pretest Initial 15 Min Type Inj j W ' TVD PTD 1811580 673 iType Test SPT' Tcst psi BBL Pumped:2 7 - BBL Returned: �27 — Interval 4YRTST - r/F Notes: MITIA Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8381 Tubing 672 - 673 672 672 - 2095 IA 415 2354 2281 - 2260 2.5 - OA 443 - 646 643 638' P ✓ Sr- 1Z'zel4 'Lo > �X-2-) Wednesday, June 16, 2021 Page I of I Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Friday, May 21, 2021 2:33 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Bo York; Aras Worthington; Oliver Sternicki Subject: OPERABLE: Injector 13-09 (PTD #1811580) Due For AOGCC MIT -IA Mr. Wallace, Injector 13-09 (PTD #1811580) surface kit issues have been resolved and the well is ready to be put on injection. The well is now classified as OPERABLE. An AOGCC MIT -IA will be scheduled when the well is thermally stable. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/ Compliance Ryan.Holt@Hilcorp.com P:(907)659-5102 M: (907) 232-1005 From: AK, D&C Well Integrity Coordinator <AKDCWellintegrityCoordinator@bp.com> Sent: Saturday, May 30, 2015 2:46 PM To: AK, OPS FS3 OSM <AKOPSFS30SM@BP.com>; AK, OPS FS3 Field OTL <AKOPSFS3Field OTL@bp.com>; All OPS F53 Facility OTL <AKOPSFS3FacilityOTL@bp.com>; AK, OPS FS3 DS Ops Lead <AKOPSF53DSOpsLead@bp.com>; AK, D&C Well Services Operations Team Lead<AKDCWellServicesOperationsTeam Lead @BP.com>; AK, D&C Wireline Operations Team Lead<AKDCWireIineOperationsTeamLead@BP.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS PCC EOC TL <AKOPSPCCEOCTL@bp.com>; G GPB FS3 Drillsites <ggpbfs3drillsites@BP.com>; Chou, Irwin <Irwin.Chou@bp.com>; 'chris.wallace@alaska.gov' <ch ris.wa I lace @a la ska.gov> Cc: AK, D&C Well Integrity Coordinator <AKDCWeIIlntegrityCoordinator@bp.com>; AK, D&C DHD Well Integrity Engineer <AKD&CDHDWelllntegri@bp.com>; AK, D&C Projects Well Integrity Engineer <AKDCProjectsWelllntegrityEngineer@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; Sternicki, Oliver R <Oliver.5ternicki@bp.com>; Regg, James B (DOA) (jim.regg@alaska.gov) <jim.regg@alaska.gov> Subject: NOT OPERABLE: Injector 13-09 (PTD #1811580) Due For AOGCC MIT -IA 09 Injector 13-09 (PTD #1811580) is due for an AOGCC MIT -IA on 06/18/2015. The well will not be placed on injection for the test before the due date. The well is reclassified as Not Operable until the well is ready to be placed on injection, and will be added to the Quarterly Not Operable Injector Report. Thank you, Kevin Parks BP Alaska - Well Integrity Coordinator r. Global Wells V Organization Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, May 30, 2015 2:46 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA) Subject: NOT OPERABLE:Injector 13-09 (PTD #1811580) Due For AOGCC MIT-IA Attachments: image001.png All, Injector 13-09 (PTD#1811580) is due for an AOGCC MIT-IA on 06/18/2015. The well will not be placed on injection for the test before the due date. The well is reclassified as Not Operable until the well is ready to be placed on injection, and will be added to the Quarterly Not Operable Injector Report. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator G�/�/ Global Wells �/V Organization SCAN NED JUN 0 9 2015 Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 08, 2011 TO: Jim Regg g . 71411( P.I. Supervisor r` l SUBJECT: Mechanical Integrity Tests l 1 BP EXPLORATION (ALASKA) INC 13 -09 FROM: Bob Noble PRUDHOE BAY UNIT 13 -09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ..1 `�— NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 13 - 09 API Well Number: 50 029 - 20671 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110621163356 Permit Number: 181 - 158 - Inspection Date: 6/18/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 13 -09 Type Inj. W TVD 8381 ' IA 188 2500 - 2459 2454 P.T.DI 1811580' TypeTest SPT Test psis 2500 OA 640 878 876 870 Interval INITAL P/F P - Tubing 453 454 451 462 Notes: M 1et, (- - list - 2 0 q 5 Cs JUL b July 08, 2011 Page 1 of 1 2Q2011 Not Operable Injector Re, • Page 1 of l Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 4:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 2Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 2Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 2Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 2Q2011.zip» Notes on wells: Removed from Quarterly Injection Report: 13 -09 (PTD #1811580): RWO repaired TxIA comm. On 04/30/11 i r, END 3- 43/P -36 (PTD #1931700): Surface casing leak repaired with Brink platelets on 05/17/11 LGI -08 (PTD #1860570): Not Operable Producer that had been mismarked in BP system as a not operable injector thereby being generated to report MPF -92 (PTD #1981930): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 MPF -95 (PTD #1981790): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 P2 -16 (PTD #1931230): RWO repaired PC leak and TxIA comm. On 04/15/11 U -10 (PTD #1851970): TxIA comm. That was repaired with a tubing patch on 06/05/2011. Moved to Monthly Injector report pending AOGCC witnessed test WGI -06 (PTD #1900300): RWO repaired TxIA comm. Well moved to Monthly Injector report pending AA cancellation Z -12 (PTD #1891020): TxIA communication repaired with cement packer on 05/24/11. Added to Quarterly Injection Report: L -223 (PTD #2090990): MIT -IA failed on 05/01/11. MPS -07 (PTD #2020720): MIT -IA failed on 04/09/11 MPS -13 (PTD #2021140): Passed MIT -IA on 04/11/11. LTSI that requires AOGCC MIT -IA when put on production. V -227 (PTD #2091160): Exhibiting rapid IA repressurization. Classified as Not Operable on 06/20/11. 7/5/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, June 23, 2011 P.I. Supervisor f 1 t ( q 11 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13 -09 FROM: Bob Noble PRUDHOE BAY UNIT 13 -09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 3P2— NON Comm Well Name: PRUDHOE BAY UNIT 13 - 09 API Well Number: 50 029 - 20671 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110621163356 Permit Number: 181 - 158 - Inspection Date: 6/18/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13 -09 ` Type Inj. w TVD 8381 IA 188 2500 ' 2459 2454 -1 P.T.Dj' 1811580 ' TypeTest 1 SPT Test psi 2500 - OA 640 878 876 870 Interval 4YRTST p,p P Tubing 453 454 451 462 Notes: Nli n.. 4-- c,d 2-fJcis 4ANIVELI JUN 2 4 201`1 Thursday, June 23, 2011 Page 1 of 1 STATE OF ALASKA RECEFVED e ALASK/ AND GAS CONSERVATION COMMIS .�l !, ,' 4 . REPORT OF SUNDRY WELL OPERA NS Ahi .a iii & Ges CM- U3i +bn4004 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended TWIloritige ® Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number. BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory • 181 - 158 3. Address: ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 - 50 - 029 - 20671 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 028315 - PBU 13 - 9. Field / Pool(s): — Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 11420' feet Plugs (measured) 10256' / 10820' feet true vertical 9614' feet Junk (measured) 10758' feet Effective depth: measured 11248' feet Packer: (measured) 10003' feet true vertical 9460' feet Packer: (true vertical) 8381' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 110' 110' Surface 2395' 13 -3/8" 2424' 2424' 4930 2670 Intermediate Production 10543' 9-5/8" 10572' 8865' 6870 4760 Liner 1158' 7" 10250' - 11408' 8591' - 9603' 8160 7020 Scab Liner 7348' 7" 2902' - 10250' 2897' - 8591' 7240 5410 JUN 0 7 2411 Perforation Depth: Measured Depth: 10664' - 10792' True Vertical Depth: 8943' - 9056' Tubing (size, grade, measured and true vertical depth): 5 17# x 4 12.6# L - 10162' 8517' Packers and SSSV (type, measured and true vertical depth): 7" x 4 -1/2" HES 'TNT packer 10003' 8381' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing, mill up packer. Run EZSV and test. Run 7" scab liner (26#, L -80) and cement w 207 Bbls of Class 'G' cement (Yield 1.16). Drill out cement and push EZSV to 10758'. Run new completion. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: I Subsequent to operation: 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory ❑ Development ° ® Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ ❑ Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG- ® WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Charles Reynolds, 564 -5480 311 Printed Name Terrie Hubble Title Drilling Technologist OS/ h Prepared By Name/Number: Signature �� L Ili • 1 • Phone 564 -4628 Date X 11 ( Terrie Hubble, 564 -4628 Form 10-404 Revised 10/2010 - BDM MAY 2 5 2011 `/- , S ": i f Submit Original Only 74 • • 13 -09, Well History (Pre Rig Workover) Date Summary 2/20/2011 WELL SHUT IN ON ARRIVAL. INITIAL T/ I/ O = 0/ 450/ 150 PSI. LOGGED LEAK DETECT LOG FROM 10100' - 10225'. CONFIRMED THAT PX PLUG AND PACKER ARE NOT LEAKING. FINAL T/1/ O = 500/ 500/ 0. WING STILL APPEARS TO BE LEAKING. TURNED OVER TO DSO. DSO CONFIRMED LOCATION. JOB COMPLETE. 3/4/2011 WELL S/I ON ARRIVAL. UNABLE TO CONTINUE JOB DUE TO STEM PACKING LEAK ON THE SWAB VALVE. GREASE CREW TRIED TO FIX, BUT WERE UNABLE, WILL NEED TO BE SWAPPED OUT FWHP= 500/500/100. WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 3/6/2011 T /I /0= 500/500/0 Performed a build up test on SSV, and a build up test on Master Valve to verify barriers. Removed 5x7 Gray Swab Valve. Installed 5x7 FMC mod 120. Performed low pressure test -500 psi. for 5 min. (passed). Performed high pressure test at 5,000 psi. for 5 min (FAILED). Wing Valve bleeding by. Called grease crew to service valve. Performed high pressure test again. (FAILED). Unable to sustain pressure. Bled all voids to 0 psi. Cleaned up tools & equipment. 3/9/2011 T /I /O =SSV /500/0 +, Temp =SI. PPPOT-T (FAIL), PPPOT -Tbg spool port (PASS), PPPOT -IC (PASS). Pre RWO. PPPOT -T: Stung into test port (150 psi) Bled to 0 psi. Function LDS, all moved freely (3/4 "). Unable to pressure test void above 3000 psi. Torque LDS to 600 lb/ft. Still unable to pressure void above 3000 psi, bled to 0 psi. RU onto tubing spool test void which tests metal/ metal and body seal (0 psi). Pumped through void, good returns. Pressured to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test void (100 psi), bled to 0 psi. Functioned LDS, all moved freely (3/4 "). Pumped through void, good returns. Pressured to 3500 psi for 30 minute test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 3/12/2011 RAN 3.60 CENT W/ 3.60 BELL GUIDE & 2" JU (UNABLE TO LATCH PRONG). MADE SEVERAL RUNS W/ 3.0" & 3.5" x 10' PUMP BAILERS. RECOVERED 7 GALLONS OF FILL TOTAL. Ran 2" JUS AND PULLED PRONG FROM PLUG BODY AT 10244' SLM / 10256' MD. RAN 2.25" PUMP BAILER NO FILL RECOVERED. RAN 4 1/2" GR AND LATCHED NIPPLE REDUCER @10244' SLM / 10256' MD. 3/13/2011 PULLED NIPPLE REDUCER FROM 10244' SLM / 10256' MD. RAN 2.50" CENT /SB TO 10600' SLM / 10612' MD. RAN TANDEM SLB SBHPS & MADE ONE STOP AT 10589' MD. WELL LEFT S/1, DSO NOTIFIED. Note: 2 -7/8" PX PLUG BODY LOST DOWN HOLE. 3/13/2011 WELL SHUT -IN ON ARRIVAL. INITIAL T /I /O = 450 / 400 /0 RIG UP E -LINE WHE AND CHECK TOOLS. WELLHOUSE REMOVED PRE -RIG. MANBASKET REQUIRED TO BREAK LUBRICATOR AT QTS. WAITING ON LRS TO LOAD AND KILL WELL. WAITING ON MAN BASKET. 3/14/2011 WELL SHUT -IN ON ARRIVAL. INITIAL T /I /O = 450 / 400 /0 LRS FINISH L &K WELL. ARM HES PLUG AND RIH WITH MH -22 (5X3) / PCCL / 1- 11/16" WEIGHT (X2) / FIRING HEAD / HES SHORTY / HES 4.5" OBSIDIAN PLUG: MAX OD = 3.66 ", LENGTH = 23.8', WEIGHT = 220 LB, FISHING NECK = 1- 3/8". SET PLUG AT 10215' MID ELEMENT DEPTH. CCL TO MID ELEMENT = 19.9', CCL STOP DEPTH = 10196.1'. POOH AND CONFRIM SET. RIH WITH MH -22 (5X3) / CAL -B / WPSA / 3 -3/8" - 2" XO / 2" SHOCK MADREL (X2) / FIRING HEAD / 4.15" POWERCUTTER. OAL = 14.6', OD = 4.15, WEIGHT = 300 LB, FISHING NECK = 1 -3/8 ". CUT 5.5" TUBING WITH 4.15" POWERCUTTER AT 10105' CUT DEPTH. CCL TO CUTTER = 12.15', CCL STOP DEPTH = 10092.85'. POSITIVE INDICATION OF SHOT AND 150 LB PRESSURE INCREASE. HANDOVER TO DSO. JOB COMPLETE. 3/15/2011 T /I /0= 400/500/80. (Load & Kill for RWO) Spear into tbg w/ 5 bbls neat meth followed by 510 bbls 9.8# brine. Freeze protect tbg w/ 5 bbls diesel. Spear into IA w/ 5 bbls meth followed by 300 bbls brine. FWHP= vac/vac/0 3/17/2011 T /I /O =0/0/0 temp =Sl MIT -OA PASSED to 2000 psi. Pump 3 bbls crude to reach test pressure. OA lost 100 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 140 psi over 30 min test. Bleed OAP to 0 psi ( -1.5 bbls). FWHP 0/0/0 Page 1 of 2 • 13 -09, Well History (Pre Rig Workover) Date Summary 3/18/2011 WELL SHUT IN ON ARRIVAL. INITAIL T /I /O = 0/0/0 PSI. EQUIPMENT SPOTTED. LRS ON LOCATION TO PUMP DOWN IA. RUNNING IN HOLE WITH ELINE TOOLSTRING. OAL = 31', TOOL WEIGHT = 240 LBS. FISHING NECK 1 -3/8" OD. 3/19/2011 LRS PUMPED 100 BBLS OF 9.8 BRINE AT 70 °F AND 60 BBLS DIESEL FREEZE PROTECT DOWN IA AT 5 BPM TAKING RETURNS TO FORMATION THROUGH KNOWN PC LEAK AT 5700' - 5850'. TUBING HAS JET CUT AT 10105'. CONFIRMED PACKER AT 10159' AND 4.5" CIBP AT 10215' IN TUBING ARE HOLDING. STOP COUNTS AND TEMPERATURE OVERLAYS INDICATE THAT BOTH ARE HOLDING AND THAT ALL FLUIDS ARE FLOWING INTO FORMATION THROUGH KNOWN PC LEAK. SSV VALVE WOULD NOT FULLY STROKE CLOSE AFTER RIGGING OFF WELL. DSO NOTIFIED BEFORE LEAVING LOCATION. FINAL T /I /O = 0/0/200 PSI. JOB COMPLETED. WELL TURNED OVER TO DSO. 3/20/2011 T /I /0 = 0/0/0 Conduct PJSM. During initial barrier tests, Tree Cap o -ring failed due to improper installation of nut and plug by previous workgroup. Installed lubricator to set BPV. Could not accomplish a good flat line pressure test to 500 psi or 3500 psi against master and SSV. Attempted to set 5" Gray K BPV # 613 but was unable to positively set BPV in profile. Installed tree cap and tested to 500 psi. (passed) Installed heater on tubing spool to heat BPV profile. Job in progress. 3/20/2011 T /I /O = 0/0/0 Tested tree (pre -rig workover) Opened MV to see well pressure. Almost 0 psi on tubing. Closed MV and tested tree to 500/4000 psi. Good tests. Opened master valve and closed SSV. Tested against SSV to 500/4000 psi. Good tests. Bled off tree. Closed Swab valve and tested to 500/4000 psi. Good tests. Bled off pressure and drained tree down to flow cross. Closed all valves on the tree. Job Complete. 3/21/2011 T /I /O =0/0/0 Set BPV, Torque THA x TS, Pressure test tree, PPPOT - T(FAIL) Tested barriers, Rigged up CIW lubricator with 5" gray BPV # 613, Pressure tested low 500 psi 5 min (PASS) then 3500 psi high 5 min (PASS) Set BPV @ 125 ". Stung into test port PPPOT -T (0+ psi) bled to 0 psi. Torqued THA x TS to 2146 ftlbs. Attemped to test void, void would bleed down to 1400 psi in about a min. bled void to 0 psi. Rigged up CIW lubricator with gray 5" test dart. Pressure tested low 500 psi 5 min (PASS) then 3500 psi high 5 min (PASS) Set test dart @ 120 ". Tested tree to 4000 psi while monitoring void pressure. Tree pressure test 4000 psi 5 min (PASS), Void had 0 psi build up during test. Bled tree (0 psi) Performed a PPPOT -T Pressured void to 3000 psi, imediately dropped to 1665 psi started a charted test, after 15 min 1422 psi, after 30 min 1384. Bled void to 0 psi. Pulled test dart, Reinstalled tree cap and tested to 500 psi (PASS). Job Complete. 4/1/2011 T /I /O =0/0/0 Pull 5" Gray BPV Pre Rig. Performed barrier test, Removed tree cap. Rigged up lubricator with 5" Gray Pulling /Running tool. Pressure tested lubricator low 500 psi for 5 min (PASS) then Tested high 3500 psi 5 min (PASS) bled to 0 psi. Pulled 5" gray K plug #619 © 108" with gray lubricator. Reinstalled tree cap and tested to 500 psi (PASS). Job Complete. 4/2/2011 T /I /O =0/0/0 Set BPV, Set Test Dart, PPPOT -T, Pull Test Dart Tested barriers, removed tree cap, rigged up CIW lubricator with 5" gray BPV #613. Pressure tested low 500 psi 5 min (PASS) then 3500 psi high 5 min (PASS). Set BPV @ 125 ". Set Test Dart @ 120" with CIW lubricator. Pressure tested tree to 5000 psi for 30 min. Hold pressure on tree while performing a PPPOT -T. Stung into test port (0 psi). Using digital gauge, pressured test void to 4993 psi for 30 min test. Lost 8 psi in 5 min, lost a total of 30 psi in 15 min, lost a total of 62 psi in 30 minutes. (See analysis below). Bled void to 0 psi. bled tree to 0 psi. Pulled test Dart, rigged down lubricator. Installed tree cap and tested to 1000 psi (PASS) * ** Job Complete * ** Per DWOP 5 min /10psi testing guidlines for BOP and small component assurance testing: test is a (PASS) with only 8 psi pressure loss over 5 minutes. Per BPXA MIT guidelines for casing and tubing strings: test is a (FAIL) tossing 62 psi over 30 minutes without conclusive stabilization. Page 2 of 2 • 0 North America - ALASKA - BP Page 1 of 20 Operation Su Report Common Well Name: 13 -09 — AFE No Event Type: WORKOVER (WO) I Start Date: 3/15/2011 End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES j Spud Date/Time: Rig Release: Rig Contractor NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date I From - To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) (ft) 4/16/2011 00:00 - 03:30 3.50 RIGD ; P PRE RIG DOWN IN PREPARATION TO MOVE OFF P2 -16. 03:30 - 04:30 1.00 RIGD r P PRE , RIG DOWN OFF OF P2 -16. - TRUCKS ON LOCATION TO MOVE. - PULL PIT MODULE OFF AND STAGE FOR MOVE. - CLEAN UP MATS AND PREPARE SUB TO MOVE OFF WELL. - WSL AND PAD OPERATOR VERIFIED NEAR PROXIMITY WELLS LOCKED OUT AND I TAGGED OUT. - WELLS LOCKED OUT: 13, 14, 15, 17, 18. 04:30 - 05:30 1.00 RIGD P PRE ; PULL SUB OFF OF WELL AND POSITION IN I j CENTER OF PAD. 05:30 - 07:00 1.50 f RIGD P PRE LOWER DERRICK FOR RIG MOVE. 07:00 - 12:00 5.00 RIGD P PRE MOVE SATELLITE CAMP, SHOP, AND PIT MODULE TO DS13. 12:00 - 00:00 12.00 RIGD P PRE I MOVE SUB BASE FROM PM2 TO DS13. 4/17/2011 00:00 - 03:00 3.00 RIGD P ! PRE MOVE RIG FROM P2 -16 TO DS13. ! SPOT RIG OVER WELL. RIGD P PRE 03:00 - 04:00 1.00 � 04:00 - 05:30 1.50 RIGD P 'RAISE (RAISE DERRICK. 1 - PJSM WITH RIG CREW AND TOURPUSHER. 05:30 - 06:00 0.50 RIGD P PRE I SPOT THE PIT MODULE. 06:00 - 10:30 4.50 RIGD P PRE CONTINIIF TO RIC; lJP ON CS13 -09 1 - BRIDLE DOWN. - SPOT CUTTINGS BOX. RIG UP LINES TO THE PITS. !- RIG UP FLOOR. ' - DSM RIGGING UP HARDLINE TO OPEN TOP TANK. - LOAD PITS WITH 120 DEG F 9.8 PPG BRINE. ; ** *RIG ACCEPT - 08:30HRS * ** x10:30 11:30 1.00 RIGU P DECOMP HELD A RIG EVACUATION DRILL. I I - ALL PERSONAL REPORTED TO THE I PRIMARY MUSTER AREA. - WSL MADE THE APPROPRIATE NOTIFICATIONS THAT THIS WAS A DRILL. I AAR ON EVACUATION DRILL WAS HELD. - NOTED THAT THERE ARE 2 ENTRANCES I TO THE PAD THAT NEED COVERED. I - ROSTER NEEDS TO BE LOCATED IN THE SECONDARY MUSTER AREA. HELD A PRE -SPUD MEETING WITH CREW 11:30 12:00 ! 0.50 WHSUR T I TO REVIEW THE WELL PLAN. NIPPLE UP DSM HYDRAULIC LUBRICATOR TO P DECOMP I THE TREE. Printed 5/11/2011 10:23:12AM •orth America e - ALASKA BP Page 2 of Operation Summary Report Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 End Date: 4/30/2011 X4- 0ORKQ -E (2,617,000.00 ) L 1 Project: Prudhoe Bay Site: PB DS 13 j Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. , UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To � Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) (ft) 112:00 - 16:30 4.50 I WHSUR P I DECOMP I ATTEMPT TO PRESSURE TEST THE DSM LUBRICATOR. - ATTEMPTED TO TEST THE LUBRICATOR TO I i 250/3500 PSI. I- TEST ATTEMPTS WERE MADE AGAINST THE SSV AND THE MASTER VALVE. - TOOL LENGTH PREVENTED TESTING iAGAINST THE SWAB VALVE. ' ' I - GREASED AND WORKED THE VALVES AND ATTEMPTED TEST AGAIN. - CALLED OUT DSM GREASE CREW. • ' - GREASED ALL THE VALVES AND 1 ATTEMPTED TO TEST AGAIN. WOULD NOT HOLD EITHER LOW OR HIGH L — PRESSURE. 16:30 - 17:00 0.50 WHSUR P T DECOMP I HELD A RIG EVACUATION / H2S DRILL. ALL PERSONAL REPORTED TO THE PRIMARY MUSTER AREA. - WSL MADE THE APPROPRIATE NOTIFICATIONS THAT THIS WAS A DRILL. - AAR ON EVACUATION DRILL WAS HELD. ' - DISCUSSED SECONDARY MUSTER POINT. - THIRD PARTY CONTRACTORS. 17:00 - 18:30 1.50 WHSUR P 1 DECOMP TEST LUBRICATOR TO 250 PSI LOW 3500 PSI ' HIGH. I - DSM VALVE CREW RIGGED UP THEIR TEST EQUIPMENT. - DSM GREASE- LOCKED THE MASTER VALVE. DSM CREW WAS ABLE TO ACHIEVE A TEST i OF 250 PSI LOW 3500 PSI HIGH. 18:30 - 19:00 1 0.50 WHSUR P 1 DECOMP I PULL THE BPV USING THE HYDRAULIC ' LUBRICATOR. 1 19:00 - 20:30 1.50 WHSUR P DECOMP I RIG UP TO REVERSE CIRCULATE OUT THE 1 DIESEL FREEZE PROTECT FROM THE TUBING. 1 - INSTALL AND RIG UP ON THE SECONDARY ANNULS VALVE ON THE IA. r I 1 L - DAY WSL COVERED WHILE NIGHT WSL ATTENDED THE TOWN HALL MEETING WITH ' BERNARD LOONEY, RICHARD LYNCH, TONY BROCK, AND MARK PATTESON. 20:30 - 00:00 3.50 WHSUR r P I i DECOMP CIRCULATE OUT THE DIESEL FREEZE PROTECT AND DISPLACE THE WELLBORE TO CLEAN, HEATED 9.8PPG BRINE. - REVERSE OUT DIESEL FROM TUBING TO OPEN TOP TANK. � I - 1 BPM AND 325 PSI. - PUMPED 30 BBLS BEFORE SEEING ANY (RETURNS. 1 I - PUMPED 20 EXTRA BBLS 9.8 BRINE TO I CLEAR DIESEL FROM TUBING. - SHUT DOWN AND SWAPPED LINES TO PUMP DOWN THE TUBING. - PUMPED A SAFE - SURF -O PILL AND _ DISPLACED AT 5 BPM AND 500 PSI. Printed 5/11/2011 10:23:12AM ,orth America.- ALASKA - BP :. Pag 3 of 20 Oper Summary Report . Common Well Name: 13 -09 _ AFE No Event Type: WORKOVER (WO) , Start Date: 3/15/2011 1 End Date: 4/30/2011 1 X4- OORKQ -E (2,617,000.00 ) I Project: Prudhoe Bay 1 Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 ©78.00ft (above Mean Sea Level) Date 1 From - To Hrs I Task I Code NPT NPT Depth; Phase 11 Description of Operations (hr) -- (ft) 4/18/2011 00:00 - 02:00 2.00 WHSUR P DECOMP CONTINUE TO DISPLACE WELLBORE TO CLEAN, HEATED 9.8 PPG BRINE. - 5 BPM AND 575 PSI. 1 - PUMPED 750 BBLS. 1 I - MONITORED WELL FOR 10 MIN. 1 - WELL SLIGHTLY OUT OF BALANCE. - PUMP AN ADDITIONAL 30 BBLS AT 5 BPM AND 575 PSI. 1 - MONITORED WELL FOR 10 MIN. 1 - NO FLOW. WELL IS BALANCED AND ' 1 DEAD. LOST 67 BBLS WHILE PUMPING. 1 1 - RECOVERED 5 BBLS DIESEL FROM TUBING AND 5 BBLS DIESEL FROM IA. - WSL CONTACTED NS RWO 1 SUPERINTENDENT OF WELL CONDITION. !SUPERINTENDENT GRANTED PERMISSION iTO PROCEED WITH THE WELL PLAN AS = WRITTEN. 102:00 - 05:00 1 3.00 WHSUR P DECOMP RIG UP LUBRICATOR AND INSTALL BPV. PRESSURE TEST BOTH. i - PJSM WITH RIG CREW, CAMERON ' 1 REPRESENTATIVES, AND DSM CREW. RIG UP LUBRICATOR ON TREE. '- TEST LUBRICATOR TO 250/3500 PSI FOR 5 CHARTED MIN. 1 - DSM GREASE CREW WORKED AND 1 1 GREASED TREE VALVES. i - DSM GREASE - LOCKED THE MASTER VALVE. - OBTAINED A PASSING TEST AFTER 60 1 1 MIN. OF WORKING VALVES. INSTALL BPV. - TEST BPV FROM BELOW. ! - 1050 PSI FOR 10 CHARTED MINUTES. 1 - 8.5 BPM. 1, r - INJECTED 104 BBLS OVER TEST 1 1 DURATION. H - RIG DOWN DSM LUBRICATOR. 05:00 - 06:00 1.00 WHSUR P DECOMP 41NSTALL TEST DART IN BPV AND PRESSURE TEST. 1- CAMERON INSTALLED TEST DART WITH I 1 DRY -ROD THROUGH TREE. - TESTED FROM ABOVE 250 PSI LOW 4000 ' PSI HIGH FOR 10 CHARTED MIN. - GOOD TEST. 1 06:00 - 09:30 3.50 WHSUR P ''�, �' DECOMP 1 NIPPLE DOWN THE TREE. I - RIG UP LINE IA. FILL THE IA CONTINUOUSLY WITH 9.8 PPG I BRINE. - STATIC LOSS RATE = 42 BPH. 1- BLEED OFF CONTROL LINES AND HANGER VOID. - CLEAN AND INSPECT THREADS. '- MADE A DUMMY RUN WITH THE 'X0'. I I I _ - 17 1/2 RH THREADS. T 09:30 - 12:00 ' 2.50 BOPSUR P DECOMP 1 NIPPLE UP ROPF ' - PJSM WITH RIG CREW. - NIPPLE UP BOP STACK. 1 + TAKE RKB MEASUREMENTS. CHANGE UPPER PIPE RAMS. 1 12 13:00 1.00 BOPSUR P DECOMP FROM 3 1/2" x 6" VBR TO 4 1/2" x 7" VBR. Printed 5/11/2011 10:23:12AM (North Arnerica - ALASKA -, BP . Page 4 • of 20 Operation Summary Common Well Name: 13 -09 1 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 End Date: 4/30/2011 1 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ! Phase Description of Operations (hr) O I - 13:00 - 14:00 1.00 BOPSUR T P DECOMP PICK UP BOPE TEST TOOLS AND RIG UP TO TEST WITH A 4 1/2" TEST JOINT. 14:00 - 15:30 1.50 BOPSUR P DECOMP ATTEMPTED TO TEST UPPER PIPE RAMS 1 WITH THE 4 1/2" TEST JOINT. [- THE 4 1/2" x 7" VBR LEAKED. 15:30 - 16:30 1.00 BOPSUR N SFAL r DECOMP CHANGED OUT UPPER PIPE RAMS. - CHANGED RAM BODIES WITH ANOTHER SET OF 41/2" x 7" VBR. 16:30 - 18:00 1.50 BOPSUR N SFAL DECOMP ATTEMPTED TO TEST UPPER PIPE RAMS WITH THE 4 1/2" TEST JOINT. - THE SECOND SET OF 4 1/2" x 7" VBR -- -- - - DECOMP 'FAILED. 118:00 19:30 1.50 BOPSUR N SFAL , CHANGED OUT UPPER PIPE RAMS. - INSTALLED NEW INSERTS IN THE 4 1/2" x 7" VBR. - RE- INSTALLED THE 4 1/2" X 7" VBR AS THE UPPER PIPE RAMS. 19:30 - 00:00 4.50 BOPSUR P DECOMP I TEST BOPE PER AOGCC REGULATIONS AND BP ADWOP POLICY. - PRESSURE TESTED TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MIN. f - TESTED CHOKE MANIFOLD VALVES; #1 -11, #14, #16. - MANUAL CHOKE AND MANUAL KILL VALVES. 30 - HCR CHOKE AND HCR KILL VALVES. - FULL OPENING SAFETY VALVE, HT -40. - 4" DART VALVE. - TOP DRIVE AIR ACTUATED IBOP. - LOWER MANUAL IBOP ON TOP DRIVE. - BLIND /SHEAR RAMS. - UPPER 4 1/2" x 7" VBR WITH 4 1/2" TEST 'JOINT. - LOWER 3 1/2" x 6" VBR WITH 4 1/2" TEST JOINT. - TESTED THE ANNULAR PREVENTER WITH 4 1/2" TEST JOINT. - 250 PSI LOW AND 3500 PSI HIGH FOR 5 I CHARTED MIN. - ALL TESTS WITNESSED BY BP WSL AND NABORS TOOLPUSHER. - AOGCC, BOB NOBLE, WAIVED THE STATE'S I ' [RIGHT TO WITNESS THE TEST. Printed 5/11/2011 10:23:12AM • orth America ALASKA BP Page 5 of 20 Operation Summary Report Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 End Date: 4/30/2011 X4- OORKQ -E (2,617,000.00 ) Project: Prudhoe Bay ' Site: PB DS 13 1 i Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 4/19/2011 00:00 - 03:30 3.50 BOPSUR P DECOMP CONTINUE TO TEST BOPE PER AOGCC REGULATIONS AND BP ADWOP POLICY. - PRESSURE TESTED TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MIN. - TESTED ALL CHOKE MANIFOLD VALVES (16 TOTAL). - MANUAL CHOKE AND MANUAL KILL VALVES. - HCR CHOKE AND HCR KILL VALVES. - 2 FULL OPENING SAFETY VALVES; HT -40 'AND4 1/2" IF. - 4" DART VALVE. - TOP DRIVE AIR ACTUATED IBOP. - LOWER MANUAL IBOP ON TOP DRIVE. I � - BLIND /SHEAR RAMS. - UPPER 4 1/2" x 7" VBR WITH 4 1/2" AND 7" TEST JOINT. - LOWER 3 1/2" x 6" VBR WITH 4 1/2" AND 5 11/2" TEST JOINT. - TESTED THE ANNULAR PREVENTER WITH 4 1/2" TEST JOINT. - 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN. - TESTED THE SUPER CHOKE AND MANUAL BEAN CHOKE. - 250 PSI LOW AND 2500 PSI HIGH FOR 5 CHARTED MIN. - LOST 300 PSI OVER 5 MIN. - PERFORMED AN ACCUMULATOR DRAW DOWN TEST. - 16 SEC TO 200 PSI, 96 SEC TO FULL PRESSURE. - 5 BOTTLES WITH 1950 PSI. - ALL TESTS WITNESSED BY BP WSL AND NABORS TOOLPUSHER. - AOGCC, BOB NOBLE, WAIVED THE STATE'S RIGHT TO WITNESS THE TEST. - STATIC LOSSES DURING BOPE TEST '✓ AVERAGED 16 BPH. 03:30 - 04:00 0.50 BOPSUR '' P DECOMP LAY DOWN AND BLOW DOWN TEST EQUIPMENT. 04:00 06:30 2.50 WHSUR P DECOMP PULL TEST DART AND BPV. PJSM WITH RIG CREW AND DSM CREW. - NIPPLE UP DUTCH RISER ON BOP STACK. - PICK UP LUBRICATOR WITH QUICK TEST SUB AND MU TO DUTCH RISER. PRESSURE TEST LUBRICATOR. - 250 PSI LOW 3500 PSI HIGH FOR 5 CHARTED MIN. DISCONNECT FROM QUICK TEST SUB AND I PULL LUBRICATOR. - DRY -ROD OUT TEST DART. - RECONNECT LUBRICATOR AND TEST QUICK TEST SUB. - PULL BPV AND LAY DOWN LUBRICATOR. 06:30 08:00 ~ RIG DOWN DUTCH RISER. 1.50 PULL P DECOMP RIG UP CONTROL LINE SPOOLER AND 5 1/2" TBG HANDLING TOOLS [ 1_ MOVE FISHING TOOLS TO FLOOR Printed 5/11/2011 10:23:12AM orth America ALASKA - BP Page 6,o of 20 Operation Summary Report Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 ' End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. ' UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1 08:00 - 10:00 2.00 PULL P DECOMP , PUI I TRCI HANGER To Fl nnR - MAKE UP SPEAR AND RIH 1 - BOLDS - UNSEAT TBG HANGER @ 275K - PUW = 180K - PULL TBG HANGER TO FLOOR - LD SPEAR - BREAK OUT TBG HANGER 110:00 - 13:00 3.00 PULL P DECOMP CIRCULATE THRU CHOKE - CLOSE ANNULAR - CIRC BOTTOMS UP THRU CHOKE 1 -3BPM @140 PSI MW IN 9.8 PPG, MW OUT 9.8 PPG 13:00 - 13:30 0.50 PULL P DECOMP RIG DOWN CIR EQUIPMENT I- BLOW DOWN CHOKE AND SURFACE 'EQUIPMENT - MONITOR WELL - WELL ON LOSSES OF 6 -10 ' BPH STATIC ' 13:30 - 16:30 3.00 PULL P T DECOMP POH WITH 51/2" TBG TO SSSV 2033' - RECOVER 3 SS BANDS, AND 25 CLAMPS 1 - PUW 175K 1- RD CAMCO SPOOLER - LD SSSV 0 0 0 7.50 PULL P DECOMP M - W 5 1/ 16:30 - 00:00 I '� ECOP : 5 1/2" TBG FROM 8072' TO 500' 4/20/2011 � 00:00 - 00:30 0.50 PULL P DECOMP CONT. TO POH WITH 5 1/2" TBG & LD I- RECOVER 255 JNTS PLUS ONE CUT OFF JNT - CUT OFF JOINT = 14.38' - 1 SSSV !I - 1 SLIDING SLEEVE 00:30 - 01:30 1.00 PULL P DECOMP : RD 5 1/2" TBG HANDLING EQUIPMENT TOOLS 1 1 - RD TONGS, ELEVATORS, SLIPS CLEAN & CLEAR FLOOR 101:30 03:30 2.00 BOPSUR P DECOMP TEST BOPS - PRESS TEST LOWER PIPE RAMS WITH 4" I TEST JOINT ' - 250 PSI LOW, 4000 PSI HIGH FOR 5 MIN i EACH. CHARTED GOOD TEST - PRESS TEST ANNULAR WITH 4" TEST JOINT - 250 PSI LOW, 3500 PSI HIGH FOR 5 MIN EACH. CHARTED GOOD TEST I - RD TEST EQUIPMENT - PULL TEST PLUG 1 1- BLOW DOWN LINES 03 :30 - 04:30 1.00 BOPSUR P DECOMP PU CAMERON WEAR RING & INSTALL 1- ATTEMPT TO INSTALL WEAR RING. UNABLE TO UN-J WITH LDS IN. 1 - PULL WEAR RING AND CHECK FOR MARKS - PUMP OUT STACK - INSTALL WEAR RING AND UN-J WITH LDS OUT. - RILDS 04:30 - 07:00 2.50 FISH P DECOMP ! PU BAKER DRESS OFF ASSEMBLY. BHA # 2 MOVE BAKER FISHING TOLLS TO FLOOR — _ PU AND MAKE UP BHA #2 I I Printed 5/11/2011 10:23:12AM •orth America - ALASKA - BP Page 7 of 20 Operation Summary Report Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 ! End Date: 4/30/2011 IX4- 0ORKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To r Hrs Task Code I NPT NPT Depth ! Phase Description of Operations (hr) (ft) 07:00 - 10:00 3.00 FISH P DECOMP PU DRILL PIPE IN SINGLES & TIH TO 2925' MD - WORK CSG SCRAPPER ACROSS LINER TOP (SETTING DEPTH. CONT TIH TO 3737' MD 1** KICK WHILE TRIPPING DRILL (D -1) ** 10:00 - 10:30 0.50 FISH P DECOMP ' SAFETY STAND -DOWN REVIEW GULF INCIDENT, ONE YEAR ANNIVERSARY OPERATIONAL SAFETY 10:30 - 15:00 4.50 FISH P DECOMP CONT TIH WITH DRILL PIPE TO 10037' MD -PUW 182K, SOW 142K 15:00 - 19:00 4.00 FISH P DECOMP I WASH OVER TBG STUMP 10105' MD AND DRESS OFF - ESTABLISH PARAMETERS - TAG TBG STUMP @ 10105' MD- PUMP HI-VIS SWEEP 10 BPM, 1800 PSI. - MILL OVER TBG STUMP AND DRESS OFF 2' TO 10107' 5 BPM, 520 PSI, 60 RPM, TQ OFF 6K, TQ ON 7 -9K. WOB 5K PUW 182K, SOW 142K, ROT 162K VERIFY ABILITY TO PASS OVER STUMP WITH NOT PUMPS OR ROTATION X 3 19:00 - 20:30 1.50 FISH P DECOMP CIRCULATE AND CONDITION - PUMP HI-VIS SWEEP - 10 BPM @ 1800 PSI AND 60 RPM, TQ 6K WHILE RECIPROCATE PIPE TAKE SPR @ 19:00 HRS, 10100' -PUMP 1 2BPM @ 100 PSI 3 BPM @180 PSI - PUMP2 2 BPM @ 100 PSI 3 BPM @ 180 PSI MONITOR WELL - WELL STABLE WITH LOSSES 20:30 00:00 3.50 FISH P DECOMP TOH WITH BHA #2 FROM 10107' TO 822' 4/21/2011 00:00 - 00:30 0.50 FISH P DECOMP . POH WITH BHA # 2 00:30 - 03:00 2.50 FISH P 1 DECOMP LD BHA # 2 INNER MILL TATTLE TALES INDICATED GOOD SIGNS OF MILLING - RECOVER 2 GAL. OF CUTTINGS FROM i BOOT BASKETS - CLEAR RIG FLOOR U i 03:00 - 04:00 1.00 � EVAL P DECOMP �PU RTTS PACKER 04:00 EVAL P 07:30 3.50 DECOMP TIH WITH RTTS PACKER TO 9987' MD - PUW 173K SOW 130K Printed 5/11/2011 10:23:12AM orth America - ALASKA BP Page 8 of 20 . Operation Summary Report Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) I Start Date: 3/15/2011 End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) 1 Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ! (hr) (ft) 07:30 - 09:00 1.50 EVAL P DECOMP PRESS TEST BELOW PACKER ■ - SET RTTS PACKER PER HALLIBURTON REP. 0 1 - PRESSURE TEST FROM BELOW PACKER el ITHRU TOP DRIVE 250 PSI LOW FOR 5 MIN GOOD TEST 2500 PSI HIGH. BLED TO 1625 PSI IN 10 MIN. 1 •TEST FAILED 2500 PSI HIGH AGAIN. BLED TO 1625 PSI IN 10 MIN. TEST FAILED i RU CEMENT LINE AND MANIFOLD. - ATTEMPT TO TEST AGAIN TO 2500 PSI. 1 BLED TO 1672 PSI IN 10 MIN. TEST FAILED - RELEASE RTTS PACKER AND NOTIFY OPS SUPERINTENDENT AND RWO ENGINEER 09:00 - 11:00 2.00 EVAL P DECOMP � CIRC AND COND. 1 j- RUN IN WITH ONE STAND DP AND 15' PUP, TO 10096' MD - CIRC BTMS UP AT 7 BPM AND 762 PSI FOR 582 BBLS. 11:00 - 12:30 1.50 EVAL P DECOMP 1 PRESSURE TFST FROM RFI OW RTTS - SET RTTS @ 10089' PER HALLIBURTON REP. - ATTEMPT TO TEST TO 2500 PSI THREE rTIMES. BLED TO 1626 PSI IN 10 MIN. TEST FAILED - LOSING 900 PSI IN THE FIRST 15 MIN, AND 70 PSI IN SECOND 15 MIN. - RELEASE RTTS 1 - BLOW DOWN LINES 12:30 - 14:30 2.00 EVAL P DECOMP POH WITH RTTS PACKER TO 5004' MD. 14:30 - 15:00 1 0.50 EVAL P DECOMP i SET RTTS PACKER PER HALLIBURTON REP 1 15:00 - 16:00 1.00 EVAL P DECOMP leRESSURE TEST C:SC; FROM 4996' TO SURFACE, I - CLOSE ANNULAR :- PRESS TEST CSG T GOOD 300 PSI LOW FOR 5 MIN CHARTED. G O TEST 1 4000 PSI HIGH FOR 30 MIN CHARTED. Gfllfl TFST LOST 73 PSI IN FIRST 15 MIN LOST 36 PSI IN SECOND 15 MIN. 1 RESULTS REVIEWED WITH ETL AND I APPROVED. 16:00 17:00 1.00 EVAL N DFAL 5,004.00 DECOMP _ . DISCUSS OPTIONS FOR PLAN FORWARD 17:00 - 19:30 2.50 EVAL P DECOMP I RELEASE RTTS PACKER AND POH 19:30 - 20:00 0.50 EVAL P DECOMP SERVICE TOP DRIVE AND DRAW WORKS 20:00 - 21:30 1.50 FISH P DECOMP PICK UP BHA - LOAD DRILL COLLARS IN PIPE SHED AND I STRAP. BRING BAKER FISHING TOOLS TO FLOOR, L — CALIPER AND STRAP 1 21'30 - 00:00 2.50 FISH P DECOMP MAKE UP BHA #3 4/22/2011 00:00 - 03:00 I 3.00 1 FISH 1 P DECOMP , TIH WITH BHA # 3 - TIH TO 10099' Printed 5/11/2011 10:23:12AM • orth America - ALASKA BP Page 9 of 20 Operation Summary Report Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) - - - -- - - -- - - -- — - -- Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: 1 Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 04:00 1.00 FISH P DECOMP ATTEMPT TO LATCH TBG STUMP - ESTABLISH PARAMETERS - PUW 190K, SOW 140K, ROT 165 - 53 SPM @ 210 PSI - 60 RPM, TQ 5.5K - PICK UP SINGLE AND TAG TOP OF FISH @ 10107' WORK OVERSHOT OVER FISH - UNABLE TO GET DESIRED OVERPULL j I CONT TO WORK PIPE AND PUMPS - ONLY ABLE TO GET 5K OVERPULL - LD SINGLE 04:00 - 08:30 4.50 FISH P DECOMP ; POOH WITH BHA #3 - MONITOR WELL FOR 10 MIN - WELL ON LOSSES OF 6. BPH - POH FROM 10,099' TO 320' 08:30 - 10:30 2.00 FISH P DECOMP LAY DOWN FISH - MONITOR WELL 10 MIN - 6 BPH LOSSES - RACK BACK COLLARS '- LAY DOWN FISH RECOVERED 24' CUT JOINT. 5.5' PUP JOINT. _ AND 1 SEAL ASSEMBLY. 10:30 - 11:00 0.50 FISH P DECOMP I PICK UP BAKER FISHING TOOLS I - MOVE FISHING TOOLS TO FLOOR - STRAP TOOLS AND CALIPER 11:00 - 12:00 1.00 FISH P DECOMP PU BHA #4 AND RIH PU SPEAR ASSEMBLY TO RECOVE�i ' RARRFI AND ANCHOR I ATCH 12:00 - 15:30 3.50 FISH P I DECOMP ITIH WITH BHA #4 TO 10,098' PUW 195K, SOW 142K 15:30 - 16:30 1.00 FISH P DECOMP SLIP & CUT DRILL LINE - CUT 134' DRILL LINE SERVICE CROWN 16:30 - 17:30 1.00 FISH P DECOMP 'ATTEMPT TO ENGAGE BARREL AND ANCHOR LATCH - ESTABLISH PARAMETERS - PUW 195K, SOW 142K, ROT 165K - 3BPMAT210PSI -TAG PBRAT 10,138' CONTINUE IN TO NO -GO AT 10,144' - SAW PUMP PRESS INCREASE TO 260 PSI I AS FISH WAS ENGAGED 1- WORK SLACK OFF & PICK UP TO VERIFY FISH WAS ENGAGED IN RIGHT HAND T -BEGAN WORKING G Q WHILE WORKING PIPE - ANCHOR RELEASED WITH 21 TURNS TO F2ICHT .. - VERIFY ANCHOR WAS FREE WITH 13 — - - _ TURNS TO RIGHT 17• 30 18:30 1.00 FISH P DECOMP CIRC BOTTOMS UP - 470 GPM AT 1950 PSI 1 1 - MONITOR WELL 10 MIN - NO FLOW, WELL ON LOSSES 1 18:30 - 22:30 4.00 FISH P DECOMP ! TOH TO BHA AT 320' - MONITOR WELL - WELL ON LOSSES 22:30 - 00:00 1.50 FISH P DECOMP LAY DOWN FISH - LAY DOWN BARREL AND ANCHOR LATCH Printed 5/11/2011 10:23:12AM forth America - ALASKA - BP Page 1a of 2O Operation Summary Report Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 I End Date: 4/30/2011 1 1X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 4/23/2011 00:00 - 01:30 1.50 FISH P DECOMP PU BHA #5 - PU PACKER MILL AND SPEAR ASSEMBLY - DECOMP FISH P RIH WITH DC'S TO 328' 8' x01:30 - 05:00 3.50 TI H TO 10,108' - INSTALL BLOWER HOSE - TAKE SLOW PUMP RATES ON BOTH PUMPS - OBTAIN PARAMETERS I -PUW 200K, SOW 142K, ROT 167K 1- 4 BPM @ 400 PSI, 60 RPM, TQ 7K ** KICK WHILE TRIPPING DRILL (D -1) ** 05:00 - 09:30 4.50 FISH P DECOMP MILL OVER PACKER TAG PACKER TOP AT 10,157' - ENGAGE PACKER WITH SPEAR AND PU TO 215K TO CONFIRM LATCH ' - MILL OVER PACKER - STAGE UP ON PUMP TO MAX OF 6 BPM AT 790 PSI - RPM 90, TQ 7K TO 15K WOB3KTO15K - LOSSES DURING MILLING AT 6 BPH 0 i I AFTER MILLING 3 FT. OVER PACKER, 100% RETURNS WERE LOST AND WOB DROPPED TO ZERO. 09:30 - 11:00 1.50 FISH P DECOMP BULLHEAD 630 RBI S 9 R PPr RRINF I- CLOSE ANNULAR - BULLHEAD DOWN ANNULUS 9 BPM AT 1360 PSI. - SHUT DOWN PUMPS AND MONITOR WELL FOR FLOW AND PRESSURE. OPEN ANNULAR 11:00 11:30 0.50 FISH P DECOMP MILL OVER PACKER - MONITOR WELL FOR FLOW - SET HOLE FILL AT 60 BPH 1- ATTEMPT TO PULL PACKER WITH NO SUCCESS - CONTINUE TO MILL ON PACKER WITH 60 I RPM AND 8 -13K WOB PACKER MILLED FREE - CHASE PACKER TO 10,244' TO ENSURE IT WAS FREE AND SPEAR WAS FULLY ENGAGED 11:30 16:00 4.50 FISH P DECOMP I PULL OUT OF HOLE WITH BHA # 5 10,244' TO 329' - HOLE FILL AT 80 BPH, INCREASE TO 100 BPH. NO RETURNS PUW 200K, SOW 145K INTERMITTENT OVER -PULLS FROM 10K TO 160K ** KICK WHILE TRIPPING DRILL (D-1)** Printed 5/11/2011 10:23:12AM ' • orth America - ALASKA - BP Page 11 o 20. O peration Summary Report Common Well Name: 13 -09 _ J AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: : Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task ' Code NPT NPT Depth Phase I Description of Operations (hr) (ft) 16:00 - 20:30 4.50 FISH I P DECOMP LAY DOWN FISH , 1 - HOLE FILL RATE UP TO 120 BPH. NO RETURNS. - LD DC'S - LD BHA AND PACKER - HAD TO PUNCH 4 1/2" TBG DUE TO IRON SULFIDE SLUDGE ON TOP OF PLUG. - PUNCH TBG ABOVE & BELOw PLUG FOR TRAPPED PRESSURE PRECAUTION. 7 TBG PUNCHES TOTAL RECOVER 45 LBS OF METAL CUTTINGS FROM BOOT BASKETS. i- RECOVERED 100% OF THE FISH 20:30 - 21:00 0.50 EVAL P DECOMP ' PU HALLIBURTON EZSV & RUNNING TOOL - HOLE FILL RATE UP TO 120 BPH. NO RETURNS. - BRING TO RIG FLOOR I - PJSM 21:00 00:00 3.00 EVAL P DECOMP TRIP IN HOLE ON DP WITH HALLIBURTON EZSV & RUNNING TOOL , '- HOLE FILL RATE UP TO 120 BPH. NO 'RETURNS. TIN TO 9135' 4/24/2011 00:00 - 00:30 { 0.50 EVAL P DECOMP (TRIP IN HOLE ON DP WITH HALLIBURTON EZSV & RUNNING TOOL I I - HOLE FILL RATE UP TO 120 BPH. NO I RETURNS. _ ! - TIH TO 10355' 1 00:30 - 01:00 0.50 EVAL r P T DECOMP SET HALLIBURTON EZSV - HOLE FILL RATE UP TO 120 BPH. NO RETURNS. ! - SET EZSV WITH 35 TURNS TO RIGHT AND . SHEAR OFF PLUG WITH 40K OVERPULL i I - SLACK OFF AND TAG PLUG WITH 10K I DOWN - EZSV SET AT 10,350' 01:00 - 01:30 0.50 EVAL P j DECOMP CIRC & COND - FILL HOLE UNTIL RETURNS ESTABLISHED - INITIAL LOSS RATE OF 45 BPH 01:30 - 02:00 0.50 EVAL P DECOMP RIG SERVICE ! - ADJUST BRAKES - SERVICE TOP DRIVE r02:00 - 05:30 3.50 EVAL P DECOMP I CIRC & COND !- 7BPMAT964PSI - CBU. AFTER CIR 200 BBLS BEGAN SEEING ! I GAS AND OIL BREAKING OUT - CONT. TO CBU. GAS STILL BREAKING OUT AFTER BU. I- PU TO 10170', 80' ABOVE LINER TOP - CBU AGAIN. GAS DROPPED OFF - MONITOR WELL FOR 10 MIN - NO FLOW I I WELL ON LOSSES OF 20 BPH 105:30 - 09:30 4.00 EVAL P DECOMP ' POH WITH EZSV RUNNING TOOL AND DP I - PUW 195K, SOW 126K - DROP 2.125" HOLLOW RABBIT DOWN DRILL PIPE ' - POOH TO EZSV RUNNING TOOL & LD MONITOR WELL FOR 10 MIN - NO FLOW WELL ON LOSSES OF 9 BPH Printed 5/11/2011 10:23:12AM , fth America ALASKA BP Page 12 of 20 Operation Summary Report Common Well Name: 13 -09 — AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 I End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) 1 Project: Prudhoe Bay ! Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) L 09:30 - 14:00 4.50 EVAL P DECOMP RIH WITH HALLIBURTON RTTS TO 10,200' - PJSM - PU RTTS PACKER & RIH 1 ' - BREAKCIRC - SET RTTS PACKER AT 10.200' , 14:00 15:00 ' 1.00 i EVAL P ; DECOMP PRESSURE TEST 7" LINER TOP AND EZSV PLUG - PRESSURE TEST BELOW RTTS PACKER 250 PSI LOW FOR 5 MIN, AND 2500 PSI HIGH FOR 10 MIN. CHARTED. GOOD TEST LOST 96 PSI IN 10 MIN. j- RECIEVED PERMISSION TO PROCEED 15:00 - 16:30 1.50 EVAL P DECOMP CIRC & COND. - CIRC BU - 8 BPM AT 1080 PSI - MONITOR WELL FOR 10 MIN - NO FLOW ! WELL ON LOSSES OF 9 BPH 16:30 - 20:30 4.00 EVAL P DECOMP I POH WITH RTTS - PUW 190K, SOW 125K H 20:30 - 21:00 0.50 EVAL P DECOMP POH AND LD RTTS PU BHA #6 CLEAR RIG FLOOR I- BRING BAKER TOOLS TO FLOOR PJSM 21:00 23:00 ! 2.00 EVAL P DECOMP MAKE UP BHA # 6 - PU 7.5" TBR DRESS AND POLISH MILLS PU 6.25" DC'S FROM PIPE SHED 23:00 - 00:00 1.00 EVAL P DECOMP TIN WITH BHA # 6 TO 2117' 4/25/2011 00:00 - 02:00 2.00 FISH P DECOMP I TIH WITH BHA # 6 02:00 - 03:00 1.00 FISH P DECOMP I WORK BAKER TBR 7.5" DRESS & POLISH MILL - TAG LINER TOP WITH MILL 90 1(1 950' - WORK MILL AT 30 RPM, TQ 8 -10.5K - — - SPM 35, 110 PSI 03:00 04:00 1.00 FISH P DECOMP CIRC & COND - CBU AT 410 GPM, 1620 PSI '- MONITOR WELL FOR 10 MIN. WELL ON !1 LO 104:00 - 07:30 3.50 P DECOMP FISH TON N TO TO BHA # 6 07:30 - 09:00 1.50 FISH P DECOMP LAY DOWN BHA 1- STAND BACK BHA ! - INSPECT POLISH & DRESS OFF MILLS 1- GOOD INDICATION OF 6' SEAL BORE ' - LD BAKER MILL ASSY. 09:00 - 10:00 1.00 FISH P DECOMP i LAY DOWN DC'S - RIH WITH DC'S LD DC'S TO PIPE SHED - CLEAN AND CLEAR FLOOR 10:00 - 12:00 2.00 CASING P DECOMP 1RU TO RUN 7" SCAB LINER - PU TQ TURN AND POWER TONGS I- RU SHORT SCAFFOLD AND FILL UP LINE ! 1 - BRING CENTS TO FLOOR - MONITOR WELL - WELL ON LOSSES OF 8 BPH. Printed 5/11/2011 10:23:12AM • orth America - ALASKA - BP Page 13 of 20 • Operation Summary Report Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 I End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 ©78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 23:00 11.00 CASING P DECOMP RUN 7" 26# L -80 VAM TOP SCAB LINER - RUN 6' SEAL ASSY PORTED FLOAT COLLAR - INSERT LANDING COLLAR - 177 JNTS TOTAL OF 7" 26# L -80 VAM TOP LINER - BAKER FLEXLOCK III HANGER - BAKER C-2 ZXP LTP TORQUE TURN CONNECTIONS 11950 FT /LBS OPTIMAL PUW 195K, SOW 158K 23:00 - 00:00 1.00 CASING P DECOMP ;CIRC LINER VOLUME - 5 BPM AT 220 PSI. - CIRC 280 BBLS 9.8 PPG BRINE 4/26/2011 00:00 - 02:00 2.00 CASING P DECOMP RN WITH 7" 26# L -80 VAM TOP LINER ON DP TO 10200' - EST PARAMETERS - PU 245K, SO 180K 02:00 - 03:00 1.00 CASING P DECOMP STING INTO LINER TOP - PU CEMENT HEAD - STING IN AND TAG NO GO - SET DOWN 5K. P/U AND TAG AGAIN WITH 10K. P/U - ROLL PUMP AT 1 BPM AT 65 PSI - ATTEMPT TO STING IN WITH 10K, AND PRESSURE UP - NO PRESS INCREASE - MADE SECOND ATTEMPT TO STING IN WITH 10K AND PRESS UP - NO PRESS INCREASE - 3RD ATTEMPT WAS SUCCESSFUL WITH 15K AND ABLE TO HOLD 500 PSI - PICK UP 5' TO EXPOSE CEMENTING PORTS. PRESS BLED OFF - PU 245K, SO 180K 03:00 - 04:00 1.00 CASING P DECOMP CIRC BOTTOMS UP -5 BPM AT 540 PSI Printed 5/11/2011 10:23:12AM orth America ALASKA - BP Page 14 of 20 Operation Summary Report ' Common Well Name: 13 -09 ' AFE No Event Type: WORKOVER (WO) I Start Date: 3/15/2011 End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: ' Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase I Description of Operations (hr (ft) 04:00 - 07:00 3.00 CASING P DECOMP PUMP 907 RRI S 15 a PPP; r i A SS r; -rMT C - PJSM WITH CEMENTERS, RIG CREW, CM2H ��� / ;.J'� HILL, AND BAKER REPS V - PUMP 5 BBLS 9.8 BRINE PRESS TEST CEMENT LINES TO 4500 PSI !AND CHECK PUMP TRIPS - MIX ANf) Pt IMP 707 RRI S 15 R CI ASS 'P.' CEMENT 5.5 BBLS/MIN AT 320 PSI YIELD 1.16 CU FT /SK i MIX WATER 5.085 GAL/SK - DROP PLUG - SLB PUMP 1 BBL CEMENT AND 9 BBLS 9.8 BRINE I - SWITCH TO RIG PUMPS AND CONT. , DISPLACEMENT WITH 9.8 PPG BRINE I - 3500 STKS INTO THE DISPLACEMENT OF 15150 STKS SEALS PUMPED OUT AT 1100 PSI - CONT. TO DISPLACE CEMENT - HAD TO REDUCE DISPLACEMENT RATE ;FROM 7.8 BBLS/MIN TO 1 BBLS/MIN AS PRESS INCREASED S - 2000 PSI MAX PRESSURE DUE TO LINER I HANGER POTENTIALLY SETTING I- BUMPED PLUG WITH 2150 PSI WITH 287 I BBLS i- SO TO NO GO WITH 20K DOWN, PU TO 230K. PRESS UP TO 2100 PSI - PRESS BLED OFF SO TO NO GO WITH 20K DOWN, PU TO 1 180K, PRESS UP TO 3000 PSI - PRESS BLED OFF I- SO TO NO GO WITH ALL AVAIL. PIPE WT, ! PRESS UP TO 4150 PSI - SAW INDICATION OF SET AT 3600 PSI - BLEED OFF PRESS AND CHECK FLOATS. FLOATS HOLDING. - ROTATE 20 TURNS TO RIGHT TO RELEASE RUNNING TOOL ! - PU TO CONFIRM FREE OF LINER. I - RD CEMENT LINE - PRESSURE UP TO 500 PSI WHILE PULLING I OUT OF LINER. - CIRC AT 8 BPM 450 PSI FOR 40 BBLS - SLOW PUMP RATE TO 2 BPM 80 PSI - SLACK OF ON DOG SUB TO 40K X 3 TO CONFIRM I - PU OUT OF LINER TOP ; PU 85K, SO 80K I I !NPR MP SFT AT 9401', I CEMENT IN PLACE @ 06:15 HRS 1 07:00 - 08:00 1.00 CASING P r DECOMP [CIRC OUT CEMENT - CIRC 3 X BU AT 12 BPM, 810 PSI. - CIRC OUT 80 BBLS CEMENT CONTAMINATED BRINE 08:00 - 10:00 2.00 CASING l P , DECOMP PULL OUT OF HOLE WITH 4 " DP POOH FROM LINER TOP AT 2901' 1 -- 10:00 10:30 0.50 WHSUR I� P DECOMP j PULL WEAR BUSHING . — — Printed 5/11/2011 10:23:12AM , orth America - ALASKA , BP page ,15 of 20 Operation Summary Report Common Well Name: 13 -09 j AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 1 End Date: 4/30/2011 IX4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud DatefTime: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 10:30 12:30 2.00 BOPSUR (hr) (ft) - . P I DECOMP ; RU TO TEST BOPS - PU TEST JOINT AND SET TEST PLUG IN BOP - FOUND ACCUMULATOR ISSUE - PRESSURE REGULATOR. 1 12:30 - 18:30 6.00 BOPSUR N RREP DECOMP RIG REPAIR - REPAIR PRESS REGULATOR FOR ANNULAR lON ACCUMULATOR UNIT 18:30 - 00:00 5.50 BOPSUR P DECOMP TEST ROPF PFR Anncr: RFG111 ATIONS ANTI BP ADWOP POLICY. i - PRESSURE TESTED TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MIN. - TESTED ALL CHOKE MANIFOLD VALVES ' - MANUAL CHOKE AND MANUAL KILL VALVES. - HCR CHOKE AND HCR KILL VALVES. r 0 - 2 FULL OPENING SAFETY VALVES; 4" AND 31/2" I - 4" DART VALVE. TOP DRIVE AIR ACTUATED IBOP. - LOWER MANUAL IBOP ON TOP DRIVE. - BLIND /SHEAR RAMS. - UPPER 4 1/2" x 7" VBR WITH 5 1/2" TEST JOINT. - LOWER 3 1/2" x 6" VBR WITH 4 " AND 51/2 " TEST JOINT. TESTED THE ANNULAR PREVENTER WITH 4 " TEST JOINT. - 250 PSI LOW AND 3500 PSI HIGH FOR 5 1 1 I CHARTED MIN. - PERFORMED AN ACCUMULATOR DRAW DOWN TEST. - 19 SEC TO 200 PSI, 80 SEC TO FULL PRESSURE. - 5 BOTTLES WITH 1950 PSI. H2S AND LEL ALARMS WERE TESTED AS PART OF THE STATE TEST - ALL TESTS WITNESSED BY BP WSL AND NABORS TOOLPUSHER. - AOGCC, MATT HERRERA WITNESSED BOP 00:00 00:30 0.50 BOPSUR TE� 1- 4/27/2011 0 - ! P DECOMP LD TEST TOOLS AND BLOW DOWN TOP i DRIVE. 00:30 - 02:00 1.50 DHB P DECOMP I PRESS TEST 7" LINER TOP LINER AND PACKER AND 9 5/8" CSG TO SURF - FILL STACK & CLOSE BLIND RAMS - PRESS TEST 250 PSI LOW FOR 5 MIN CHARTED I- PRESS TEST 4000 PSI HIGH FOR 30 MIN CHARTED , LOST 91 PSI IN 1ST 15 MIN LOST 36 PSI IN 2ND 15 MIN GOOD TEST - BLEED OFF PRESS & OPEN BLIND RAMS l DISCUSS PRESS TEST RESULTS WITH WTL - RECIEVED OK TO PROCEED 02:00 - 04:30 2.50 WHSUR P DECOMP ' ND BOP, AND TBG SPOOL - BREAK STACK AT TBG SPOOL - SET STACK BACK ON PEDESTAL - ND TBG SPOOL Printed 5/11/2011 10:23:12AM orth America - ALASKA BP Page 16 of 20 Operation Summary Report , Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES 1 Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. 1 UWI_ — Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date i From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 05:00 0.50 WHSUR P DECOMP CHANGE OUT 9 5/8" PACK OFF 05:00 - 06:30 j 1.50 WHSUR P DECOMP 1 NU TBG SPOOL 06:30 - 07:30 1.00 WHSUR P DECOMP 1 TEST TBG SPOOL VOID - PRESS TEST 250 PSI LOW FOR 5 MIN :CHARTED - ATTEMPT TO TEST TO 5000 PSI - FOUND LOCK DOWN SCREW PACKING LEAKING - TIGHTEN 1- PRESS TEST 5000 PSI HIGH FOR 30 MIN CHARTED LOST 94 PSI IN 1ST 15 MIN GAINED 32 PSI IN 2ND 15 MIN DUE TO TEMP LOST 62 PSI FOR OVERALL TEST GOOD TEST DISCUSS PRESS TEST RESULTS WITH WTL - F _ _ 'RECEIVED OK TO PROCEED 07:30 - 09:30 2.00 BOPSUR P DECOMP NU BOP TO TBG SPOOL - TORQUE BOLTS - CENTER STACK - INSTALL RISER rt09:30 10:30 1.00 BOPSUR P DECOMP .TEST BREAK BETWEEN TBG SPOOL & BOP '- PRESS TEST 250 PSI LOW FOR 5 MIN ICHARTED - PRESS TEST 4000 PSI HIGH FOR 5 MIN CHARTED _ { - GOOD TEST '10:30 - 11:00 0.50 BOPSUR P DECOMP f INSTALL WEAR BUSHING 111:00 - 13:30 2.50 CLEAN P DECOMP l PU BHA # 7 FOR CLEAN OUT 113:30 - 17:30 4.00 CLEAN P DECOMP TIH WITH 4" DP TO 9916' MD t - PU 200K, SO 125K - BREAK CIRC EVERY 30 STDS 17:30 - 19:00 1.50 CLEAN P I DECOMP .SERVICE RIG ! - SLIP & CUT 126' DRILL LINE - SERVICE DRAW WORKS — — SERVICE CROWN SERVICE TOP P DRIVE 1 1900 - 00:00 5.00 CLEAN P DECOMP , DRILL CEMENT I - CEMENT STRINGERS AT 9940' - 80 RPM TQ 8K OFF - 7 BPM © 1325 PSI - PU 195K SO 120K, ROT 150K DRILL SOLID CEMENT 10003 TO 10063' I- TAG WIPER DART HIGH AT 10063'. DRILL WIPER DART - CON. TO DRILL CEMENT - - TAG LANDING COLLAR AT 10148'. DRILL LC 4/28/2011 1 00:00 - 03:00 3.00 CLEAN P DECOMP ' CONTINUE TO DRILL AND CLEANOUT SHOE 1 TRACK F/ WIPER DART © 10063' T/ TIE -BACK SEAL ASSY © 10250'. RIH T/ 10' ABOVE EZBP I @ 10350'. 03:00 - 04:30 1.50 CLEAN P DECOMP I CIRCULATE AND CONDITION HOLE. PUMPED 120 BBL HI-VIS SWEEP @ 9 BPM, 2165 PSI. NO ' NOTABLE RETURNS. 04:30 - 07:00 2.50 CLEAN P DECOMP DISPLACED 9.8 PPG BRINE IN WELLBORE WITH HEATED 120 DEG F 8.5 PPG SEAWATER. CIRCULATED @ 9 BPM, 2025 PSI. I Printed 5/11/2011 10:23:12AM •orth America - ALASKA BP Page 17 of 20 O peration Summary Report Common Well Name: 13 -09 �� AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay j Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. : UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs j Task Code I NPT NPT Depth Phase I Description of Operations i (hr) (ft) I 07:00 - 07:30 0.50 CLEAN I P 1 ' DECOMP RIH AND TAG EZBP an 10346' MD. DRILL 'THROUGH EZBP AT: 80 TDS RPM, 85 PUMP SPM, 10 -15 KLBS WOB, 630 PUMP PSI. BROKE THROUGH PLUG AND OBSERVED LOSS OF RETURNS. 1 SLOW PUMP RATES: 10350' MD, 8970' TVD, 8.5 PPG: MP 1 &2 = 80 PSI @ 2 BPM, 200 PSI @3BPM. 07:30 08:30 1.00 I CLEAN I P ; DECOMP ! PICKED UP 5 ABOVE EZBP, CLOSED ;ANNULAR PREVENTER AND LINED UP TO !PUMP DOWN KILL LINE AND DRILLPIPE. I BULLHEADED 300 BBLS 8.5 PPG SEAWATER INTO FORMATION @ 7 BPM. ICP = 778 PSI, FCP = 1124 PSI. SHUTDOWN PUMPS AND OPENED ANNULAR. CHECKED FOR FLOW. I NO FLOW. 08:30 - 10:30 ! 2.00 CLEAN P DECOMP RIH. TAGGED EZBP a 10347' AND I CONTINI IFD nRll I ING DRILLED AND ' PUSHED EZBP TO 10758'. MADE THREE ' UNSUCCESSFUL ATTEMPTS TO PUSH FURTHER THAN 10758' MD (ROTATION & PUMPS, PUMPS ONLY, AND STRAIGHT I SETDOWN UP TO 15 KLBS WOB). POOH T! I I - 10575' MD, ABOVE PERFS, AND SHUT DOWN PUMPS. CHECK HOLE FOR LOSSES. HOLE ;TAKING APPROX. 100 BBLS PER HOUR. I MAINTAIN FLUID LEVEL IN WELLBORE WITH MIX PUMP. FINAL TAG DEPTH = 10758' MD, 9026' ND 10:30 - 19:00 8.50 CLEAN P DECOMP HELD PJSM WITH CREW ON RIG FLOOR. . TOH, LAYING DOWN DRILLPIPE SINGLES, F! -10575' TO 325'. CHECK FOR FLOW PRIOR TO BHA ENTERING STACK. NO FLOW. CONTINUE OUT OF HOLE, LAYING DOWN I BHA. BIT WAS IN GAUGE, -75% OF THE TEETH WERE CHIPPED 19:30 0.50 F 19:00 - P RUNCOM I- RUNCMP PULLED WEAR BUSHING 119:30 22:00 2.50 LRUNCOM P 7 RUNCMP RIG UP TO RUN COMPLETION TUBING ,M /U I LANDING JOINT TO HANGER AND MAKE DUMMY RUN. RIG UP AND FUNCTION TEST TORQUE TURN EQUIPMENT AND 4 -1/2" 00:00 2.00 RUNCOM P RUNCMP ELEVATORS. 22:00 - RIH W/ 4-1/2" X 5 -1/2" TUBING COMPLETION ASSY TO 913' AT MIDNIGHT. HALLIBURTON COMPLETIONS REP AND NABORS CASING REP ON LOCATION. OPTIMUM MAKEUP ' TORQUE FOR 4 -1/2 ", 12.6 #, L -80, TC-II TBG = 13900 FT -LBS. CONTINUE FILLING HOLE TO MAKEUP FOR LOSSES OF -90 BPH. CONNECTIONS BELOW PACKER ARE BAKERLOK'D AND JET LUBE SEAL GUARD , I THREAD COMPOUND USED ON ALL OTHER CONNECTIONS. Printed 5/11/2011 10:23:12AM • •orth America - ALASKA - BP AK Page 18 of 20 luir Operation Summary Report Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 End Date: 4/30/2011 X4 -OORKQ E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. 1 UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 4/29/2011 00:00 10:00 10.00 RUNCOM (ft) - � P I � RUNCMP CONTINUE TO RIH WITH 4 -1/2 ", 12.6 #, L -80, TC -II X 5 -1/2 ", 17 #, L -80, TC-II COMPLETION ASSY F/ 913' AT MIDNIGHT T/ SETTING DEPTH OF 10162' MD, 8517' TVD. MONITORING CONSISTENT HOLE LOSSES OF —80 BPH AND FILLING HOLE CONSTANTLY WITH MIX PUMP. OPTIMUM MAKEUP TORQUE FOR 5 -1/2" TBG = 5500 FT -LBS. FINAL PU WEIGHT = 156 KLBS, SO WEIGHT = 120 KLBS. 10:00 - 12:00 2.00 RUNCOM P RUNCMP CIRC & CONDITION IMAINTAIN HOLE FILL CONDUCT PJSM WITH RIG CREW, LITTLE RED, CAMERON, WSL, & NABORS TP ON PUMPING CORROSION INHIBITOR, AND FREEZE PROTECT. RU LRS -- 12:00 13:00 1.00 RUNCOM - P RUNCMP PRESS TEST SURFACE LINES I- TEST 300 PSI LOW, AND 4000 PSI HIGH FOR F5 MIN EACH. GOOD TEST 13:00 - 15:00 2.00 RUNCOM P RUNCMP MAKE UP AND LAND TUBING HANGER. - PICK UP CAMERON TUBING HANGER. - RUN IN THE HOLE AND LAND THE TUBING HANGER. - WIRE LINE ENTRY GUIDE AT 10,162'. - UP WEIGHT = 156K LBS, DOWN WEIGHT = 120K LBS. - RUN IN THE LOCK DOWN SCREWS. - BACK OUT THE LANDING JOINT AND LAY DOWN. 15:00 - 17:00 2.00 RUNCOM P RUNCMP REV CIRC REV CIRC 225 BBLS 120 DEG INHIBITED SEA 1 WATER AT 3 BPM AND 150 PSI. FOLLOW WITH 96 BBLS HEATED DIESEL AT 3 BPM AND 300 PSI. 117:00 - 18:00 1.00 RUNCOM P RUNCMP 'LITTLE RED SERVICES BULLHEAD 51 BBLS. HEATED DIESEL DOWN TBG AT 2 BPM AND 600 PSI. RD LRS. Printed 5/11/2011 10:23:12AM . • orth Am :- ALASKA - BP Page 19 of 20 Operation Summar Report . Common Well Name: 13 -09 AFE No Event Type: WORKOVER (WO) Start Date: 3/15/2011 I End Date: 4/30/2011 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. : UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT ' NPT Depth Phase Description of Operations 1 118:00 - 21:00 3.00 r RUNCOM (ft) (hr) P ! '� RUNCMP ',SET HALLIBURTON 'TNT' PACKER AND MIT THE TUBING AND IA. 1 DROP 1 7/8" BALL & ROD. LAY DOWN THE ' LANDING JOINT AND FILL TBG. FLUID TO SURFACE. FILL IA. CLOSE THE BLIND SHEAR RAMS. PRESSURE UP ON THE TUBING TO 250 PSI. CONTINUE TO PRESSURE UP AND SET 'TNT' PACKER WITH 3200 PSI. BLEED OFF TO 500 . PSI AND HOLD. PRESSURE UP AND MIT TUBING: - 4000 PSI FOR 30 CHARTED MINUTES. - LOST 113 PSI IN THE FIRST 15 MIN. - LOST 35 PSI IN THE SECOND 15 MIN. BLED THE TUBING BACK TO 1500 PSI. PRESSURE UP AND MIT THE IA. 6' �� - 250 PSI FOR 5 CHARTED MIN. Vs - 4000 PSI FOR 30 CHARTED MIN. - LOST 108 PSI IN THE FIRST 15 MIN. - LOST 45 PSI OVER THE SECOND 1 MIN. I- RIG DOWN AND BLOW DOWN ALL TEST I EQUIPMENT. DISCUSSED MIT TEST RESULTS WITH ADW WELLS TL. * *SEE SCANNED AND ATTACHED TEST I CHART ** 21:00 - 00:00 3.00 T I BOPSUR P t RUNCMP ,SET TWC & TEST j RIG UP DRILL SITE MAINT. LUBRICATOR. PRESS TEST LUB. 250 PSI LOW, AND 3500 PSI HIGH FOR 5 MIN EACH. GOOD TEST. SET TWC. RIG DOWN LUBRICATOR. CLOSE I BLIND RAMS. ATTEMPT TO TEST. FIRST TEST FAILED ON 4000 PSI HIGH TEST. CHECK FOR SURFACE LEAKS. 4/30/2011 00:00 - 04:30 4.50 BOPSUR P RUNCMP CC)NTINI IF Tn TFST - Nye , RIG UP LUBRICATOR AND RE -TEST 250 PSI ' I LOW, AND 3500 PSI HIGH FOR 5 MIN EACH. GOOD TEST. PULL TWC. RE- INSTALL LUBRICATOR AND RE -TEST 250 I PSI LOW, AND 3500 PSI HIGH FOR 5 MIN EACH. GOOD TEST. INSTALL TWC. RD LUBRICATOR. CLOSE I BLIND RAMS. TEST TWC I - 250 PSI FOR 5 CHARTED MIN. -4000 PSI FOR 10 CHARTED MIN. GOOD TEST 04:30 - 07:30 3.00 BOPSUR P RUNCMP I NIPPLE DOWN AND STAND BACK BOP STACK. I ;- BLOW DOWN ALL LINES AND SUCK FLUID OUT OF STACK. • - NIPPLE DOWN BOP STACK AND SECURE _ - ON STUMP. 07:30 - 09:30 2.00 WHSUB P RUNCMP i f NIPPLE UP ADAPTER FLANGE Printed 5/11/2011 10:23:12AM ' r, 4114 • o rth Americ - ALASKA - BP Page 20 of 20 . Operation Summary Report. . Common Well Name: 13 -09 I AFE No u Event Type: WORKOVER (WO) Start Date: 3/15/2011 End Date: 4/30/2011 1 X4- 00RKQ -E (2,617,000.00 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 13 -09 @78.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ' Phase Description of Operations (hr) (ft) 09:30 11:30 2.00 WHSUB P RUNCMP TEST ADAPTER FLANGE AND VOID. - 250 PSI LOW FOR 5 MINUTES. - 5000 PSI HIGH FOR 30 MINUTES. - GOOD TEST. * *SEE SCANNED AND ATTACHED TEST CHART** 11:30 - 13:00 1.50 WHSUB P RUNCMP NIPPLE UP TREE 13:00 - 14:30 1.50 WHSUB P RUNCMP TEST TREE. ,= 250 PSI LOW FOR 5 MINUTES. - 5000 PSI HIGH FOR 30 MINUTES. 1- GOOD TEST. * *SEE SCANNED AND ATTACHED TEST _ CHART ** 14:30 - 16:00 1.50 WHSUR P RUNCMP , SECURE TREE AND CELLAR FOR RIG MOVE. RIG DOWN ALL TEST EQUIPMENT. REMOVE ' SECONDARY ANNULUS VALVES. INSTALL FLANGES AND GAUGES. RIG DOWN FLOOR EQUIPMENT AND PREPARE RIG FOR TRANSPORT. LAY DOWN DERRICK * ** RIG RELEASED FROM DS 13 -09 AT 16:00 I HRSON 4 -30- 2011. * ** Printed 5/11/2011 10:23:12AM 'WELLHEAD = GRAY GRAY . 3 -0 9 �/ yA O S ** C HROME NIPPLES SSSV ACTUATOR = AXLESON KB. ELEV = 78 BF. ELEV ? I I KOP = 2800' Max Angle = 47 @ 7600' ® I I 2026' H5-1/2" HES X NIP (9 -CR), ID = 4.562" I Datum MD = 10588' *1,03- ✓s{` ✓E MEE.D EC Datum TVD = 8800' SS 20" CONDUCTOR, 944, H -40, ID = 19.124" H 82' 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2424' 2795' J-15-1/2" X 4 -1/2" XO, ID = 3.958" 1 5 -1/2" TBG, 17 #, L -80 TCII, .0232 bpf, ID = 4.892" I 2795' 2901' 1- 9 -5/8" X 7" BKR C-2 ZXP LTP Minimum ID = 2.313" @ 10256' v w / TIEBACK, ID =6.30° 4 -1/2" x 2-7/8" NIP REDUCER �: �� 2191' I�9- 5 /8 " X7 " BKR FLIXLOCK III HGR, ID = 6.230" I ■ .. 9 -5/8" CSG, 47 #, L -80 BTC XO TO SOO -95 BTC I 9253' 7 ►� •« L 9972' H4 -1/2" HES X NIP (9 -CR), ID = 3.813" • ►• t4i '4 ��� �� �« 10003 J X 4-1/2" HES TNT PKR,ID =3.856" 1 • � 4 10040' I -1 /2" HES X NIP (9 -CR), ID = 3.813" I • ♦ l• it V 4 1/2" TBG, 12.64, L -80 TCII .0152 bpf, ID = 3.958" H 10162' I 0 ' V, 10103' H4 -1/2" HES XN NIP (9 -CR), ID = 3.725" I ♦ 1 N ` 6.• 10162' 114-1/2" WLEG, ID = 3.958" I 7" SCAB LNR, 26 #, L -80 VAM TOP HC, H 10249' I ►j � j ► 4 ♦ H ELMD TT NOT LOGGED I .0383 bpf, ID = 6.276" ►« TOP OF 7" LNR 1H 10250' I •♦ !A 10250' 11 BKR PORTED TIEBACK SEAL ASSY w / 4 -1" HOLES, ID = 6.140" 9 -5/8" CSG, 47 #, S00 -95 BTC, ID = 8.681" H 10572' PERFORATION SUMMARY REF LOG: BHCS ON 11/13/81 41Ihr ' J 10758' I I FISH - 2 -7/8" PX PLUG BODY (03/12/11)1 ANGLE AT TOP PERF: 30° @ 10664' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 10664 - 10684 0 12/26/91 41/t r I 10819' H FISH - 29" SL DUMP BAILER (12/01/84) I 3 -1/8" 4 10742 - 10762 0 06/21/84 I 10820' I-I 7" BRIDGE PLUG I 3 -1/8" 8 10772 - 10792 0 11/20/82 3 -1/8" 4 10772 - 10792 0 02/10/83 4" 4 10827 - 10831 S 01/31/83 4" 4 10832 - 10836 S 01/28/83 I 4" 4 10851 - 10855 S 01/24/83 PBTD h 11248' ■••••••r' 7" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.184" H 11408' 4-0-.-0-.1* TD H 11420' DATE REV BY COMMENTS ' DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/19/81 ROWAN 2E ORIGINAL COMPLETION WELL: 13 -09 02/06/83 N1 ES RWO PERMIT No:'1811580 04/30/11 N7ES RWO (SCAB LNR) API No: 50- 029 - 20671 -00 05/01/11 PJC DRLG DRAFT CORRECTIONS SEC 13, T1 ON, R14E, 1290' FSL & 155' FWL 05/03/11 CR/ PJC FINAL DRLG CORRECTIONS BP Exploration (Alaska) ,�. 04/18/11 $chk erge NO. 5719 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -16 BCRD -00092 PRODUCTION PROFILE ! J ' Y ) 'tr 03111/11 1 / j- 1 14-12 BBKA -00091 PRODUCTION PROFILE / (5 03/05/11 1 ! 1 Z-02A B-000 INJECTION PROFILE 1—'�, 4- (�" 3 03/19/11 1 / 1 13-09 BDAD DAD -00030 38 LDL ( 'C /�6�� 03/19/11 1 / 1 7 4111' L5-36 BJOH -00014 PRODUCTION PROFIL 1 j ( 03/16/11 1 1 3-25 L4-15 BBSK -00059 PRODUCTION PROFILE 03/16/11 1 1 / 1 03 -25A BG4H-00042 PRODUCTION PROFILE / 03/18/11 1 1 Z -112 BL65 -00021 MEM PR /ODD PROFILE D 03/01/11 1 1 . l 02/23/11 1 J -17C BAUJ -00061 MCNL �1 n5'...6 02/09/11 1 7 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 APR 1 9 2UVV .. Co , ;a Km kidierw • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, April 22, 2011 10:54 AM To: 'Reynolds, Charles (ALASKA)' Subject: RE: 13 -09i Change of Scope (PTD 181 -158) Charles, Per our phone conversation you have approval to change the completion as stated in your attached work program. Removing the production packer and extending the scab liner will make the completion much cleaner in the long run. Good luck. Guy Schwartz Senior Petroleum Engineer y AOGCC APR e 2O "� 793 -1226 (office) SLAMS 444 -3433 (cell) Original Message From: Reynolds, Charles (ALASKA) [mailto:Charles.Reynolds @bp.com] Sent: Friday, April 22, 2011 9:53 AM To: Schwartz, Guy L (DOA) Subject: 13 -09i Change of Scope Guy, We would like to keep you in the loop on a change in operations for the 13 -09i RWO. After proceeding with our original workover plan we were unable to get a passing test on the composite plug in the 4 -1/2" tailpipe. Since this plug is necessary during the cementing operations for the scab liner we have elected to remove the original production packer and run the scab into the production liner top as previously discussed. I have attached our plan forward and a schematic of the newly proposed completion. Please feel free to ask any questions or comment. I will be best reached by cell phone throughout the day or this coming weekend. Thanks, Charles Reynolds Ce11:575 -6234 Desk:564 -5480 1 WELLHEAD = 'RAY GRAY • 1 R AY G SAFETY : S ACTUATOR = AXLESON KB. ELEV = 78' p OST -R W 0 �1'p I 1-1515 BF. ELEV = ? - ff KOP = 2800' Max Angle = 47 @ 7700' Datum MD = 10588' Datum TV D = 8800' SS 1 0 ii ` 2000' 1 5 -1/2" L -80 X -t 2" 5 -1/2" MCX Injection Valve, set Post -Rig 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2424' Al 5-1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" —{ ® . -2800' H 5 -1/2" x 4 -1/2" L -80 X -Over 2925' H 7" L -80 Liner Hanger /LTP I Minimum ID = 3.725" @ 10256' 4 -1/2" XN NIPPLE (A p PA(C 1) ! 14-1/2" TBG, 12.6 #, L-80, .0152 bpf , ID = 3.958" H I 10150' I---'— 9,995' — 4-1/2' L -80 X- Nipple, ID = 3.812" 17" Scab - Liner, 26 #, L -80, Vam -HC, ID = 6.276" H 10130' I!� • 10,045' - - 7" x 4-1/2" HES TNT Packer 10,080' 4-1/2' L -80 X- Nipple, ID = 3.812" !TOP OF 7" LNR 1-1_ 10250' 10,150' — 4 -1/2 L-80 X Nipple, ID = 3.812" —10134' I--I 7 -112" LTP Seal Assembly I 1 9 -518" CSG, 47 #, L- 80/SOO -95, 10 = 8.681" H 10571' J L. PERFORATION SUMMARY I REF LOG: BHCS ON 11/13/81 ANGLE AT TOP PERF: 30 @ 10664' I Note: Refer to Production D6 for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE I 3-3/8" 4 10664 - 10684 C 12/26/91 3-1/8" 4 10742 - 10762 C 06/21/84 3-1/8" 8 10772 - 10792 C 11/20/82 3-1/8" 4 10772 - 10792 C 02/10/83 10819' H 29" SL DUMP BAILER 12/01/84 I 4" 4 10827 - 10831 S 01/31/83 4" 4 10832 - 10836 S 01/28/83 1 0820' —1 7" BRIDGE PLUG 4" 4 10851 - 10855 S 01/24/83 1PBTD 11278' 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 11408' l• TD H 11420' � - DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11119181 ORIGINAL COMPLETION 09/26/06 RLM/PAG PATCH PULLED (01/09 & 01/10/06) WELL: 13-09 02/04/83 RWO 03/15/08 JIM/TLH PATCH PULLED (01/10/06) PERMIT No: 1811580 08/28/03 ATD/KK SET TTP 06/08/08 JMITLH PKR DEPTH CORRECTION API No: 50- 029 - 20671 -00 12/05/03 TJPTTLP SAFETY NOTE CHANGE SEC 13, T1 ON, R14E, 2382.77' FEL & 3095.89' FNL 02/07/04 NUAITLP MIN ID, ECLIPSE PKR, REDUC NIP /PXN 06/22/04 ATD/TLH I I P SET CORRECTION L BP Exploration (Alaska) • • 13 -09i RWO Well Plan Operational Note #3 This note combined with all other ops notes and the approved wellplan constitutes wellplan revision 3 Prepared by: Charles Reynolds Date: 4/21/2011 1 T / ?(- /'S 8 Follow the approved well plan and any other ops notes through Step 13, and then proceed as follows. 14. Install wear bushing then make -up a fishing BHA to catch the 5 - tubing stub in 9 -5/8" 47 #. Review non - shearable equipment procedure prior to picking up BHA. • 8 -W HMC w/ 5 -W Superloy insert • 8 - %" 150 overshot with 5 -%2" basket grapple /MCP • 8 - %" top extension • 6 -W OD Bowen Bumper Jar • 6 -W OD Bowen Oil Jar • 6 - %" OD Pump Out Sub • 9 x 6 - %" Drill Collars • 6 -'/4' OD Bowen Acc Jar 15. RIH on drillpipe to top of cut tubing fish above Brown 3 -H packer. Establish rotating, PU, and SO weights. Dress off and engage tubing stub on top of PBR and set grapple with light jarring. Rotate out latch with 15 — 18 turns to the right. PU, Flow check for 10 min verifying no flow then POOH. Flow check again for 10 min verifying no flow before pulling the BHA through the stack. Maintain constant hole fill up to a rate of 60 -BPH. LD PBR /latch. Inspect all completion equipment for NORM 15b. If only the seal stem was recovered, RIH and recover barrel and anchor latch. Caliper OD of slick stick to determine proper spear size. Establish rotating, PU, and SO weights. Engage slick stick and rotate out the latch with 15 —18 turns to the right. Flow check for 10 min verifying no flow then POOH. Flow check again for 10 min verifying no flow before pulling the BHA through the stack. Maintain constant hole fill up to a rate of 60- BPH. LD BHA. Inspect all completion equipment for NORM • Itco Spear sized catch remaining PBR assembly • 8 - %" top extension • 6 - %" OD Bowen Bumper Jar • 6 -%4" OD Bowen Oil Jar • 9 x 6 -1/4" Drill Collars • 6 - %" OD Bowen Acc Jar 16. PU packer milling assembly and mill Brown 3 -H packer. Establish rotating, PU, and SO weights. Mill packer. Be aware of potential for trapped gas below the packer, be prepared after milling packer to shut in annular preventer and bullhead away 615 bbls (volume down annulus from surface to perfs) of 9.8 ppg brine down the drillpipe x casing annulus at 7 BPM minimum. Push packer to TOL at 8532' MD. Flow check for 10 min verifying no flow then POOH. Flow check again for 10 min verifying no flow before pulling the BHA through the stack. Maintain constant hole fill of up to 60 -BPH. LD packer assembly. Inspect all completion equipment for NORM • 8 -W MM Mill w /4 - %" PRT Spear w/ 4.750" Grapple w/4.5' of extension • Triple Connection Sub • 3 - 7" OD Boot Collar Baskets • 4 -%" Reg Box x 4 - %" IF Box Sub • 6 - %" OD Bowen Bumper Jar • 6 - %" OD Bowen Oil Jar • 9 x 6 -/4" OD Drill Collars • 6 - %" OD Bowen Acc Jar 16b. If the packer was not recovered, RIH and retrieve packer. Flow check for 10 min verifying no flow then POOH. Flow check again for 10 min verifying no flow before pulling the BHA through the stack. Maintain constant hole fill of up to 60 -BPH. Inspect all completion equipment for NORM. • Itco Spear to catch 4.750" ID • Spear Ext. 5' (Optional) • Spear Stop sub • 6 - %" OD Bowen Bumper Jar • 6 - %" OD Bowen Oil Jar • 9 x 6 -34" OD Drill Collars • • • 6 -%4" OD Bowen Acc Jar 17. MU 7.50" tie -back polishing mill and 9 -5/8" scraper BHA. RIH and polish the tie -back receptacle. Last tag on TOL was at 10,247'. Circulate hi -vis sweep at 10 BPM. When circulating don't exceed 3000 psi max. Flow check for 10 min verifying no flow then POOH SBDP. Flow check again for 10 min verifying no flow before pulling the BHA through the stack. Maintain constant hole fill of up to 60 -BPH. • 7.5" tie -back polish mill dressed for 10' tie back sleeve • 6 -W OD Bowen Bumper Jar • 6 -'/4" OD Bowen Oil Jar • 9 x 6 -%4" OD Drill Collars taseeti0 ar a. • ur 18. MU 7" EZSV + hydraulic setting tool, space out pipe and 9 -5/8" RTTS and RIH to set the 7" EZSV at -10,350'. Drop ball and pressure up to set 7" EZSV according to HES Rep. PU to shear off of EZSV and pressure up to shear out ball seat. Pull up hole and set RTTS inside the 9 -5/8" production casing above the7' liner top. Pressure test 7" EZSV and liner top packer to 2500 psi for 10 charted minutes. Flow check for 10 min verifying no flow then POOH SBDP. Flow check again for 10 min verifying no flow before pulling the BHA through the stack. LD BHA. Maintain constant hole fill of up to 60 -BPH. 19. RU Torque Turn services and compensator for premium connection casing. Rabbit the liner and jewelry with a 6.15" rabbit before RIH. PU and run 7" casing as follows, filling casing every 5 joints and making up to the torque specs below: • 7 -1/2" OD 6ft long tie back seal assembly with (4) 1" holes between upper and lower sets of seals. • 1 joint 7" 26# L -80 BTC casing • 1 joint 7" 26# L -80 casing w/ BTC pin, with 7" BTC HES PORTED Float Collar bucked on the pin end • 1 joint 7" 26# L -80 casing with Baker insert landing collar installed in the pin • 7" 26# L -80 VamTop -HC casing w/1 free - floating straight -vane centralizer per joint to -2,925' MD • 9 5/8" x 7" Baker FLEXLOCK Liner Hanger (w/ wiper -plug (REMOVE LWP LATCH) loaded) pinned to shear at -2800 psi • 9 -5/8" x 7" Baker C -2 ZXP Liner Top Packer • Hydraulic pusher tool (pinned for 3,200 -psi) and rotating packer setting dog sub • 4 "DP 7" 26 #, L -80 casing is not shearable. Be sure to have safety joint, TIW valve, and necessary crossovers ready. Review non - shearable equipment procedure prior to picking up casing. * *Use Jet Lube Seal Guard on all VamTop -HC connections ** * *7 ", 26# VamTop -HC Make -up to 11,950 ** 7 ", 26 #, L-80, VamTop Collapse Burst Tensile ID Make - up Torque HC 100% 5,410 psi 7,240 psi 604,000 Ib 6.276" 11,950 ft/lbs Opt 80% 4328 psi 5,792 psi 483,200 Ib 6.151" drift 13,050 ft/Ibs Max 10,850 ft/Ibs Min 20. RIH with scab liner. Establish parameters with the tie back seals above the liner top. Slack off and engage the seals. Pressure up to 500 -psi and pick up to expose the ports. Establish circulation at -0.5 -BPM. Mark the pipe at this depth. Do not move drill string during the cement job. Do not pump cement without Schlumberger field blend test results Cement Slurry Specs: 15.8ppg Class "G ", No Free H 1.16 cf /sk Yield, Fluid Loss < 250mL 3.5 - 6 hrs Thickening Time, 15hrs max to 1,000 -psi compressive strength, 0.200% BWOC Antifoam, 0.300% BWOC Dispersant, 0.020 gal /sk Retarder 21. RU Schlumberger cementers (cementing unit must have 5,000 psi pop -off). Mix cement with 80 °F fresh water. PT cement lines to 4500 psi. Pump calculated volume of 15.8 ppg Class G cement at 4 -6 bpm. Pump a total of 207 bbls 15.8 ppg Class "G" cement with 4 -6 hours thickening time at -195 °F BHST Cernent volume = annular volume from -10,105' to 2,925' (184 bbls) + 20 bbls excess + shoe tract. 13 -09i RWO OPERATIONS NOTE 3: APPROVED BY ODE _ OPSSUPT.. __ ETL WTL Page 2 • • 22. Cement the 7" scab as follows: • 5 bbls freshwater to PT • 207 bbls 15.8 Class "G" w/ specifications from above • Displace with 9.8ppg NaCI brine • Drop the pump down plug and start pumping brine. Do not wash up before dropping the plug. Leave -2 bbls (pumps and line capacity) of cement on top of the wiper plug. 23. Drop pump -down drill -pipe plug and displace cement. Reduce pump rate to 1 -2 bpm when within 10 bbls of latching pump -down drill -pipe plug to liner wiper plug. Liner wiper plug should shear from running tool when pressure gauge shows -1,000 psi pressure spike. Displace wiper plug to landing collar with no more that 2,200 -psi pump pressure to avoid setting liner hanger prematurely. 24. Slow pumps to 1 -2 bpm within 5 bbls of bumping the liner wiper plug in the landing collar. Bump plug with a max pressure of 2,200 -psi. Bleed off all pressure and slack off to fully engage the seals. Increase DP pressure to 3,000 - psi to set FLEXLOCK III liner hanger. NOTE: Pump until plug bumps up to 5 bbls over calculated displacement. If plugs do not bump after over - displacement bleed off all pressure and engage the seals. Record cement -in -place time on morning report. 25. Slack off 30-40K lbs to ensure liner hanger is set. Increase pressure to 3,500 -psi to activate the hydraulic pusher tool. Bleed off pressure to 1,000 -psi and rotate to release C -2 running tool from liner. Pick up DP until pressure drops. Circulate 50 -bbls of brine at 5-6 bpm. Slack off 50K and rotate to set the liner top packer. RD cementers. Consider standing back 1 stand. Continue circulating at at 8 -10bpm while reciprocating DP with 60ft strokes until well is clean. Do not tag liner top. Perform flow check for 10 min verifying no flow, POOH with liner running tool assembly standing back. Flow check again for 10 min verifying no flow before pulling the BHA through the stack. 1 26. RIH with 7" Drill Out assembly on 4" DP. • 6" Bit for 7" 29# • 6" Spiral bladed string mill • 4 -3/4" Lubricated Bumper Jar • 4 -3/4" Oil Jar • (4) Boot Baskets • (6) 4 -3/4" Drill Collars • Pump out sub • 4" DP as required 27. RIH to - 9,000'. MU 9 -5/8" stormpacker to the drill out assembly and set one stand below surface. Pressure test storm packer against the blind rams to 1000 psi for 10 charted minutes to verify barrier status. 28. Review "SOP: Procedure for Replacing Casing Packoffs". Bleed the annulus and packoff void off before retracting lock down screws. Leave the lower annulus valve open during the operation and testing of replaced packoff. Back out lock down screws and break the tubing spool from the casing spool and set the BOP /tubing spool back, barriers are 7" EZSV and 9 -5/8" stormpacker. Replace packoffs, change out tubing spool, NU BOPE. Run in all lock down screws to energize the seal and lock down packoff. Test packoff void (tubing spool x casing spool flange and packoff seals) to 5,000psi for 30 -min. Follow the general pressure testing criteria as documented in CRT-AK-10-45 Criteria for working with pressure. • Any MIT that exhibits an overall pressure loss of less than 10% of the maximum test pressure over the entire 30 minute test period and one that meets the stabilization criteria will be defined as acceptable and "leak- tight ". In BPXA, the stabilization criteria for an acceptable MIT shall be defined as: • A test in which the total pressure loss in the second 15 minute test period is less than or equal to ha f the pressure loss in the first 15 minute test period and • A test in which the pressure fall -off rate is less than 5 psi /min for the final 15 minute test period. Note: The MIT may be extended for an additional 15 minute period to demonstrate stabilization if the pressure loss results are inconclusive. A failed MIT will therefore result from either a >10% overall pressure loss over the entire test period, or failure to meet both of the stabilization criteria. 29. Set test plug in tubing spool and close blinds to test BOPE x Tubing Spool flange to 4000 psi (BOPE test pressure) for 5 charted minutes. Remove Test plug. Follow the general pressure testing criteria as documented in CRT- AK -10 -45 Criteria for working with pressure. a. All tests shall include a low-pressure test of 200 to 300 pounds per square inch (psi) for 5 minutes before proceeding to the full pressure test. 13 -09i RWO OPERATIONS NOTE 3: APPROVED BY ODE_ OPS SUPT. ETL 1NTL Page 3 • • b. For routine operational assurance testing of valves, manifolds, and blowout preventers (BOPs), a satisfactory pressure test is represented by the test pressure held for a minimum of 5 minutes after the pressure has stabilized (defined as stable or decreasing pressure fall off less than 10 psi/minute [min]). A 5- minute test on a BOP or valve is sufficient to give assurance that there is integrity and that the unit under test is operating without any obvious major problems. Equipment verification pressure tests following manufacture or major servicing need stricter assurance requirements. 30. RIH and release 9 -5/8" stormpacker. Perform flow check for 10 min verifying no flow. POOH and lay down storm packer. 31. Verify that cement has reached a minimum of 1000 psi compressive strength on UCA. Close lower VBR and test casing and recently set 7" scab liner to 4000 psi (1.2 x Injection header pressure + S.F.) for 30 charted minutes. Send test results to WTL and obtain confirmation of passing tests and document in Openwells prior to proceeding. Follow the general pressure testing criteria as documented in CRT- AK -10 -45 Criteria for working with pressure. • Any MIT that exhibits an overall pressure loss of less than 10% of the maximum test pressure over the entire 30 minute test period and one that meets the stabilization criteria will be defined as acceptable and "leak- tight ". In BPXA, the stabilization criteria for an acceptable MIT shall be defined as: • A test in which the total pressure loss in the second 15 minute test period is less than or equal to half the pressure loss in the first 15 minute test period and • A test in which the pressure fall -off rate is less than 5 psi /min for the final 15 minute test period. Note: The MIT may be extended for an additional 15 minute period to demonstrate stabilization if the pressure loss results are inconclusive. A failed MIT will therefore result from either a >10% overall pressure loss over the entire test period, or failure to meet both of the stabilization criteria. 32. RIH to the 7" landing collar and establish PU, SO and rotating parameters. Drill out shoe track at 7 -14k WOB, -80 RPM, pumping at -7 BPM. Pump 20 bbl sweeps as needed to clean hole. Once clean returns are obtained swap wellbore over from 9.8 ppg brine to heated seawater at max rate. 33. Continue RIH down to the 7" EZSV at -10,350'. Drill out EZSV at 7 -14k WOB, -80 RPM, pumping at -7 BPM. Pump 20 bbl sweeps as needed to clean hole. Expect that once EZSV releases the well will go on a vacuum, however, S annular preventer and bullhead 35 bbls of seawater (2 x volume from EZSV to pert) at a minimum of 7 BPM. From this point maintain hole fill with 120 deg F seawater up to 60 BPH. 34. After drilling up EZSV, continue RIH to push debris to bottom. Note: Last tag on this well was 10,760' with slickline so scale, schmoo or fill may be encountered in the last 15'. CBU with final hi -vis sweep. Shut down and perform flow check for 10 min. POOH, stop to flow check for 10 min prior to pulling BHA through the stack. Continue filling hole up to 60 BPH with 120 deg F seawater. 13 -09i RWO OPERATIONS NOTE 3: APPROVED BY ODE. _OPS_SUPT.. ETL, WTL Page 4 • • 35. Prepare to PU tubing. Pull the wear bushing. Assemble "as run" tubing tally and sent to ops superintendent and ODE for review. Run 5 -W x 4 - %2" 12.6# L -80 TCII with 7" x 4 - %" HES TNT packer and tailpipe assembly. Ensure accurate dimensional records are made and kept for all equipment run in the well. Discuss any discrepancies with RWO engineer. Rabbit 4 -1/2" tubing and jewelry with a 3.833" rabbit, and rabbit 5 -1/2" tubing and jewelry with a 4.767" before RIH. See the attached 'Proposed Completion Schematic'. Use Torque Turn services and a compensator for all premium tubing connections. Continue filling hole with 120 deg F seawater while running tubing up to 60 BPH. • 4 - Wireline re -entry guide -10,295' • 1 joint of 4 - %" 12.6# L -80 TCII tubing • 15' 4 -W 12.6# L -80 pup • 4 -' /z" "XN" nipple 3.725" ID, 3.813" packing bore, with RHC -M at - 10,250' • 15' 4 -%" 12.6# L -80 pup • 1 joint of 4 - %" 12.6# L -80 TCII tubing • 15' 4 -W 12.6# L -80 pup • 4 -Y2" "X" nipple 3.813" ID at - 10,180' • 15' 4-%" 12.6# L -80 pup • 15' 4 -%" 12.6# L -80 pup • 7" x 4-%" L-80 HES TNT Packer at -10,150' • 15' 4 - %" 12.6# L -80 pup • 15' 4 -W 12.6# L -80 pup • 4 -' /2 "X" nipple 3.813" ID at - 10,120' • 15' 4 -%" 12.6# L -80 pup • 4 - %" 12.6# L -80 TCII tubing • 4- x 5- Crossover at 2,800' • 15' 5 -W 17# L -80 pup • 5-Y2 "X" nipple 4.562" ID at -2000' • 15' 5 -'/" 17# L -80 pup • 5-%" 17# L -80 TCII tubing • 5- TCII x 7" TCII Crossover pup • Gray New Standard Tubing Hanger 12" x 7" TC -II bottom Tubing hanger, 6" type 'J' Profile Take precautions while running the tubing: clean threads if contaminated, use a stabbing guide, properly dope and hand - start each pin. Use Jet Lube Seal Guard thread compound. Tubing should arrive on location with the proper thread dope. Utilize Single joint compensator and Torque turn each connection. * *Use "Jet Lube Seal Guard" Thread Compound ** ** Baker -Loc all connections below the packer** * *If required, clean tubing threads before applying new Jet Lube Seal Guard ** * *Optimum 4 -' /z" 12.6# TC -II Make -up Torque is 3,900 ft -Ibs ** 4' /z" 12.6# L TC - I1 Collapse Burst Tensile ID Make -up Torque 100% 7,500 psi 8,430 psi 288,000 Ib 3.958" ID 3,900 ft-Ib opt 3.833" drift 4,200 ft -Ib max 80% 6,000 psi 6,744 psi 230,000 Ib 3,500 ft -Ib min * *Optimum 5- 17# TC -II Make -up Torque is 4,350 ft -Ibs ** 5' /Z" 17# L TC - II Collapse Burst Tensile ID Make -up Torque 100% 6,290 psi 7,740 psi 397,000 Ib 4.892" ID 4,350 ft -Ib opt 4.767" drift 4,600 ft -Ib max 80% 5,032 psi 6,192 psi 317,600 Ib 4,100 ft-Ib min 13 -09i RWO OPERATIONS NOTE 3: APPROVED BY ODE, OPS SUPT., ETL, WTL Page 5 • • 36. RIH with completion placing 7" x 4 -1/2 "production packer in the first full joint above the 7" landing collar, space out pups should not be required as there will be a 40' spaceout window. Record PU and SO weights. PU crossover pup + tubing hanger, and landing joint. Land the tubing hanger and RILDS. 37. Heat all fluids to 120 °F. Reverse circulate 225 bbls corrosion inhibited seawater at 3 BPM followed by 96 bbls of diesel. RU Hot oil pump to landing joint and freeze protect the tubing -2,200' with 51 bbls of diesel. 38. Drop ball 'n' rod, continue to fill tubing with heated seawater. Pressure up on the tubing to set the packer and test the tubing to 4,000psi for 30 charted minutes. Bleed off the tubing to 1,500psi. Test the IA to 4,000psi for 30 minutes. Bleed off all pressure, assure IA is fluid packed to surface, fill with heated corrosion inhibited seawater as necessary. Record and notate all pressure tests on chart. Send test results to WTL obtain confi p ation of rm assin tes e t nd document in Openwells prior to proceeding. Follow the general pressure testing criteria as documented in CRT- AK -10 -45 Criteria for working with pressure: • Any MIT that exhibits an overall pressure loss of less than 10% of the maximum test pressure over the entire 30 minute test period and one that meets the stabilization criteria will be defined as acceptable and "leak-tight". In BPXA, the stabilization criteria for an acceptable MIT shall be defined as: • A test in which the total pressure loss in the second 15 minute test period is less than or equal to half the pressure loss in the first 15 minute test period and • A test in which the pressure fall -off rate is less than 5 psi /min for the final 15 minute test period. Note: The MIT may be extended for an additional 15 minute period to demonstrate stabilization if the pressure loss results are inconclusive. A failed MIT will therefore result from either a >10% overall pressure loss over the entire test period, or failure to meet both of the stabilization criteria. 39. Lay down landing joint. Set TWC and test to 4,000 psi from above for 10 charted minutes, we will be unable to test the TWC from below. ND BOPE and NU 13 -5/8" 5K x 7- 1/16" 5K adapter flange and 7- 1/16" tree. (barriers are the RHC /ball and rod with kill weight fluid and TWC) Test tubing hanger void and seals to 5,000 psi. Test tree to 5,000 psi. Follow the general pressure testing criteria as documented in CRT- AK -10 -45 Criteria for working with pressure: • Any MIT that exhibits an overall pressure loss of less than 10% of the maximum test pressure over the entire 30 minute test period and one that meets the stabilization criteria will be defined as acceptable and "leak- tight ". In BPXA, the stabilization criteria for an acceptable MIT shall be defined as: • A test in which the total pressure loss in the second 15 minute test period is less than or equal to half the pressure loss in the first 15 minute test period and • A test in which the pressure fall -off rate is less than 5 psi /min for the final 15 minute test period. Note: The MIT may be extended for an additional 15 minute period to demonstrate stabilization if the pressure loss results are inconclusive. A failed MIT will therefore result from either a >10% overall pressure loss over the entire test period, or failure to meet both of the stabilization criteria. 40. Secure the tree and cellar. RDMO. * Complete a post -rig inspection with the Pad Operator after moving rig off of the pad * II Approved by: Charles Reynolds, ODE Approved by: Jim Willingham, Ops Supt. Approved by: Dave Reem, ETL Approved by: Dave Reem, WTL Delegate 13 -09i RWO QQR�►TIONSNOTE 3: APPROVED BX� OP SUPT.. ETL. WTL Page 6 • • Page 1 of 2 Schwartz, Guy L (DOA) From: Reynolds, Charles (ALASKA) [Charles.Reynolds @bp.com] Sent: Wednesday, April 06, 2011 12:47 PM To: Schwartz, Guy L (DOA) Subject: RE: 13 -091 RWO changes (PTD 181 -158) Attachments: 13 -09 Tubing Hanger Packoff (Re -Test Results) Guy, I apologize for stalling on this. I finished that procedure Friday afternoon and on Saturday I received a call from the slope that they had done further diagnostic testing on the tubing hanger. It looks like we will be able to proceed according to the original plan and we will not be doing additional prep work nor will we be pulling the production packer. I've attached Tyler Norene's email for your clarification. It looks like we have all the barriers we need to nipple down the tree and to test our BOPs against. Charles Reynolds BP Alaska Rig Workovers Ph: (907) 564 -5480 14ait } APR 0 7 2011 Cell: (907) 575 -6234 Email: Charles.Reynolds @BP.com From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Wednesday, April 06, 2011 12:00 PM To: Reynolds, Charles (ALASKA) Subject: FW: 13 -09i RWO changes (PTD 181 -158) Just a reminder to send me the updated full procedure... We are still using the same sundry for the workscope. Thanks. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Friday, April 01, 2011 2:40 PM To: 'Reynolds, Charles (ALASKA)' Subject: RE: 13 -09i RWO changes (PTD 181 -158) Charles, Looks like we should be able to keep using the same sundry. The work scope hasn't changed dramatically and the new completion is even more robust than the original plan. Send me the new procedure draft as soon as Se you can. p y Guy Schwartz Senior Petroleum Engineer AOGCC 4/6/2011 • • • Page 2 of 2 793 -1226 (office) 444 -3433 (cell) From: Reynolds, Charles (ALASKA) [ mailto:Charles.Reynolds @bp.com] Sent: Friday, April 01, 2011 10:34 AM To: Schwartz, Guy L (DOA) Subject: 13 -09i RWO changes Guy, Attached is a comparison of the previously planned operations summary and the proposed operations summary. I've underlined any significant changes that are being made. Feel free to reel me over to ask any questions. Thanks,. Charles Reynolds BP Alaska Rig Workovers Ph: (907) 564 -5480 Cell: (907) 575 -6234 Email: Charles.Reynolds@BP.com 4/6/2011 • 0 I it , v _._.. i zi - - - - r i ■ _rte sue. , , a J . _._ 30 j. ATLANTIC RICHFIELD COMPANY PRUDHOE BAY WELLHEAD 20" X 13, 3/8" X 9, 5/8" X 5, 1/2" (-(- VETCO GRAY 30 HUGHES Metal Neck Seal 1 i Upper Test Port 9 - Elastomer Body Seal $ Inner Mandrel � � � � �� i'lLd Lower Test Port Metal x Metal Body Seal 29-112 i4 f 77 -1 2 1 - : J 1 :1_!::: j'`--i e P i 13 -09 Tubing Hanger Packoff (Re-Test Results) Page 1 of 1 Schwartz, Guy L (DOA) From: AK, D &C Well Services Operations Team Lead [ AKDCWellServicesOperationsTeamLead @BP.com] Sent: Sunday, April 03, 2011 10:22 AM To: Reynolds, Charles (ALASKA); Reem, David C; Rossberg, R Steven Cc: Cismoski, Doug A; Kara, Danny T; Allely, Josh (BPXA); Igwe, Josiah; AK, D &C Wells CT Scheduler; AK, D &C Wireline Operations Team Lead r e/-/.C8 Subject: 13 -09 Tubing Hanger Packoff (Re -Test Results) r-F.D — Attachments: Gray Gen II.ppt Gentlemen, You may need to open the attachment prior to reading this... «Gray Gen II.ppt» Before attempting the 13 -09 pre rig coil work, we took a real close look at the prior attempts to get a passing PPPOT -T. My previous experience working with Gray Gen II systems made me suspicious of the failing test results. These are good systems with numerous metal x metal seals and extremely tight tolerances, but certain design features can work against you when attempting to get a passing pressure test using the upper test port. The main issue is with the metal x metal neck seal on the tubing hanger. Because of its relatively thin wall and tapered design, the neck will occasionally leak when testing from below using the upper test port. But when you test the tree from above and monitor the upper test port for pressure buildup, the same neck will not leak and is actually energized by pressure in the tree. This can result in a directional leak and a misdiagnosis of the actual problem. Previous passing pressure tests using the lower test port had already eliminated the main body seal, the lower metal x metal seal, and the control lines as potential leak sights. The only other opportunity for a leak path was the hanger's inner mandrel (see drawing). We designed a test that basically took the neck of the hanger out of the equation by leaving 5000 psi on the tree while performing a 5000 psi test on the upper test port. Per our DWOP testing guidelines using the 5 min/ 10 psi rule for BOP's and other assurance testing the 5000 psi test passed with flying colors losing only 8 psi in the first 5 minutes. This was a big change from the previous attempts to test this void. This also proves that the inner mandrel of the tubing hanger has integrity. Since the neck of the hanger is exposed in the 13" BOP stack, it's integrity has no bearing on getting the rig safely on the well. The overall hanger integrity is excellent and should be considered a competent barrier in my opinion. I could not reach Charles this weekend, so I called Reem and told him these results. We decided to release the coil unit and cancelled the job for now. 2y(er Worene AK D&C Well Services TL Office: (907) 659 -582 Pager: (907) 659 -5100 N. 1023 Cell: (907) 903 -2264 4/6/2011 Original Ops Summary • Revi.ps Summary 1. Pre -rig work is done 1. Pre -rig work to be done: a) Service Coil to drill out Composite Plug b) Service Coil to lay in sand across existing perfs c) Service Coil to lay cement plug on sand as Ivishak Barrier d) Service Coil to test cement plug with treating packer 2. MIRU, Circ out well, ND Tree 2. Same rw Ger& 5;7 ee, S� 3. NU BOPE + Sp 1, Set Test plug, Test BOPE, Pull Test Plug, 3.NU BOPE, Test Same Pull Hanger and replace, Test TBG Spool x Test Spool API Flange 4. Pull tubing Same *" RIH, dress off TBG stub and set grapple. Attempt to rotate out 5. RIH and dress TBG stub"' Ottch and POOH. b) If not revocered - RIH and recover anchor latch — r - min on BOT 3 -H packer, push down to LNR top and recover b) If not recovered - RIH and spear packer and pull 7. RIH with mill polish 7" liner top 6. RIH with RTTS and test production packer /Composite plug 8. RIH with RTTS + seals and test 7 liner top and casing above scab and Casing above scab top top 7. Run 7" scab liner + 5 -1/2" overshot and fully cement same 9. Run 7" scab liner + seal assembly and fully cement same 8. Change out 9 -5/8" packoffs and tubing spool 10. Same 9. PT scab liner 11. Same 10. RIH and drill out 7" Shoe track 12. RIH, drill out 7" shoe track, drill out cement plug, wash out sand to plug below perfs 11. RIH and drill out 4 -1/2" composite plug 12. Run 4 -1/2" x 5 -1/2" completion 13. Same 13. RDMO 14. RDMO Post -rig work Post -rig work a) Pull Ball +Rod a) Pull Ball +Rod / Dp ;ti.v�' It :... , � � 1� ��° r0 4 fr S ,at .- rip or l .. . System Drawing ` Bill of Materials ADAPTER SPOOL Item Qty Description 1 1 Adapter Spool 13 -5/8" 5M Flange Bottom x 13 -5/8" 5M Stdd Flange Top, full set tiedown screws, w/o outlets, �� , & four type CD -2 support Alignment pins, 1/2" npt test port for testing between the 1 Riser Mandre seals Part # 2248945 -02 -02 Vii i I `{)-- - 2 1 13 -5/8" Nom Riser Mandrel, 13 5/8" 5K i with 9-1/2" Reg Acme Thred . Riser 7 1 I II f3) top prep to accept Otis Quick 1 .1 /i Union, o ring & special land 1._ ing shoulder for Alignment --3 pins �� Part# 2180939 -04 ki I I 3 2 Ring Gasket, BX -160 Part # ,..�._ . - - 1 1 13 -5/8" 5K Annular RP080090 RP- 001439 Riser Mandrel Installation re Rev 02 CAMERON and Retrieval Procedure Page 4 03/30/11 Schlumberger NO. 5715 Alaska Data & Consulting Services Company: State of Alaska 2525 Gembell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 4 Log Description Date BL Color CD P1 -07A BJGT -00020 PRODUCTION PROFILE C)C 03/05/11 1 .2.0 /.17 1 S -18B BL65 -00020 MEMORY DDL / — • 02/22/11 1 _ • , 1 13-09 BG4H -00035 LDL , — 1 .:;a_ • 1 09 -02 BBSK -00052 RST _ 02/16111 1 _ ��� 1 D -16A BG4H -00034 RST ' — 02/19111 1 _ - ,L - 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 APR 4 2O1 t { y • ( ;t) '1)1( • • a,F ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader S BP Exploration (Alaska), Inc. `$ f P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13 -09 Sundry Number: 311 -048 Dear Mr. Reem: N FEB 2 5 ZU1 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, r Daniel T. Seamount, Jr. Chair II DATED this Z day of February, 2011. Encl. STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS N APPLICATION FOR SUNDRY APPROVAL 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 Suspended Well ❑ Stimulate IN Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 181 - 158 3. Address: ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 20671 - 00 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number. property line where ownership or landownership changes: PBU 13 -09 Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028315 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11.. ` ` PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11420' 9613' 11278' 9487' 10256' / 10820' 10819' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 110' 110' Surface 2395' 13 -3/8" 2424' 2424' 4930 2670 Intermediate Production 10543' 9 -5/8" 10571' 8864' 6870 4760 Liner 1158' 7" 10250' - 11408' 8591' - 9603' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 10664' - 10792' 8943' - 9056' 5 -1/2 ", 17# x 4 -1/2 ", 12.6# L -80 / N -80 10268' Packers and SSSV Type: 9 -5/8" x 5-1/2" BOT Packer Packers and SSSV 10159' / 8514' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program 0 Exploratory 0 Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 15, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ® WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Charles Reynolds, 564-5480 Printed Name David Reem Title Engineering Team Leader Prepared By Name/Number. Signature yy Phone 564-5743 Date 2,_ 1 9 _ 20 II Elizabeth Barker, 564-5674 Commission Use Only Conditions of approval: N tify Commission that a representative may witness Sundry Number: -- ,1E %-i 1 ❑ Plug Integrity LAS Ib BOP Test Mechanical Integrity Test ❑ Location Clearance ` O 4 I r 000 Ps i 80p e 5/t— . 0 - i l Other: ,f 2500 ps z A h n .l air / C s i Cm CrlJ 7,E 7, ER 2 nil T' ,[ vet n mss✓ Di �+ .4- .L �, ` G t� r b ✓ 1 '�/ C� r� plO GX e �4 �► } Di & GPIs Cans. C ornissil Subsequent Form Required: / O — y y 6 ,„01. APPROVED BY Approved By: A v COMMISSIONER THE COMMISSION Date 2/2S/ Form 10- 403 ' 11EB ,` Submit In Duplicate DUPLICAT • • GP Y or { f 13 -09i Expense Rig Workover Scope of Work: Pull 5 -' /z" L -80 completion, cement a 7" scab liner, Replace Casing Pack -offs, run 4 -'/2 L -80 completion. MASP: 2,432 psi Well Type: Injector Estimated Start Date: March 15, 2011 Production Engineer: Paulina Meixueiro Intervention Engineer: Charles Reynolds Pre -Riq Work Request: E Run LDL to verify that Production Packer and PXN are barriers to the formation. Notes: LDL shows T x IA communication at 5857'. Suspected PC leak at 5700 - 5850'. Last LLR on Tubing was with a patch in place, 1.2 gpm @ 2000psi (2/21/2004). Last LLR on IA was 2 BPM at 750 psi (2/10/2004). S 2 Pull 2 -7/8" PXN @ 10,256', Pull 2 -7/8" x 4 -1/2" Nipple Reducer @ 10,256'. E 3 Set 4 -1/2" composite bridge plug @ - 10,215'. Jet cut 5 -1/2" tubing @ - 10,105'. Cut desired to be 15' down the full joint between the packer and sliding sleeve. (Reference tubing tally 2/4/83). F 4 MIT -OA to 2000 psi. Perform LLR on T x IA to verify barrier is holding. Pump down tubing at same rate from LDL, taking returns from IA. Circulate out the well to 9.8 brine and confirm dead. Diesel freeze protect to 100'. W 5 Check the tubing hanger and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. O 6 Set a BPV in the tubing hanger. O 7 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: 1. MIRU. ND tree. NU BOPE with Annular, 4 -'/2' x 7" VBRs, Blindshear, 3 -'/2' x 6" VBRs. Pressure test Blind Rams and VBR's to 4,000 psi, Annular to 3,500 psi. Circulate out freeze protection fluid and circulate well to 9.8 brine through the cut. 2. Pull and LD 5 -W tubing string to the cut. 3. RIH with 4" drillpipe and scrape the casing to 10,105' MD. 4. RIH with a RTTS to just above the tubing stub and pressure test the composite bridge plug then PUH ✓ to 3,000' and test the casing to surface. 5. Fully cement a 7" VT -HC scab liner from -2,925' to 10,050' MD. (Barriers: 4 -1/2" x 7" VBR, tested composite plug at 10,215' MD and kill weight fluid) 6. Change 9 -5/8" casing packoff. 7. RIH with 4" drillpipe and drilling assembly and drill up the 7" shoe tract and composite plug. 8. Run 4 -'/2" L -80 completion with a 7" Halliburton TNT packer. Position packer at -9,900' MD. Request: Given that this well is located on the front row of Drill Site 13 it falls under the regulation d of 20 ACC 25.265 (d) (1) (C). Upon completion of this rig workover this well will be returned to service as a WAG injector and as such we would like to request a varience under 20 ACC 25.265 (o) (1) to utilize a X- Nipple and wireline s et injection valve instead of installing a surface controlled subsurface safety valve. 9. Displace the IA to packer fluid and freeze protect to 2,000' MD. 10. Load tubing with FP fluid, Set the Packer, test tubing and IA to 4,000 psi. 11. Set BPV. ND BOPE. NU and test tree. RDMO. TREE =. GRAY GEN 2 WELLHEAD= GRAY III SAFEf.rES: ACTUATOR = AXLESON 13-09 KB. ELEV = 78' BF.ELEV__ ? KOP = 2800' Max Angle= 47 @ 7700' 1 2033' H 5 -1/2" OTIS RQM SSSV NIP, ID = 4.562" I Datum MD = 10588' Datum TVD = 8800' SS I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I 2424' I --A Minimum ID = 2.313" @ 10256' 4 -1/2" x 2 -7/8" NIP REDUCER I I 1 10082' H 5 -1/2" OTIS SLIDING SLV, ID= 4.562" I ' 1 10154' I--) 5-1/2" BOT PBR ASSY I g ■— 1 10159' J-{ 9 -5/8" X 5-1/2" BOT PKR I 5-1/2" TBG -PC, 17 #, L -80, .0232 bpf, ID = 4.892" I-I 10164' 1 10164' I-I 5 -1/2" X4 -1/2" XO I TOP OF 7" LNR H 10250' Ii 1 10256' H 4 -1/2" OTIS XN NIP, ID = 3.725" I 10256' I- 4 -1/2" X 2 -7/8" REDUCING NP W/ 2 -7/8" PXN - SET 01/27/04 14 1/2" TBG, 12.6 #, N -80, .0152 bpf, ID = 3.958" I-I 10268' I I 10268' I-1 4 -1/2" TUBING TAIL I 1 10276' I-1 ELMD TT LOGGED 02/05/88 I 19 -5/8" CSG, 47 #, L- 80/SO0-95, ID = 8.681" H 10571' I-J 1 PERFORATION SUMMARY I REF LOG: BHCS ON 11/13/81 ANGLE AT TOP PERF: 30 @ 10664' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE Ally 1 1 10819' H 29" SL DUMP BAILER 12/01/84 I 3 -3/8" 4 10664 - 10684 C 12/26/91 3-1/8" 4 10742 - 10762 C 06/21/84 1 10820' I--I 7" BRIDGE PLUG I 3 -1/8" 8 10772 - 10792 C 11/20/82 3 -1/8" 4 10772 - 10792 C 02/10/83 4" 4 10827 - 10831 S 01/31/83 4" 4 10832 - 10836 S 01/28/83 4" 4 10851 - 10855 S 01/24/83 1PBTD H 11278' WAWA 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 11408' ∎••••••• *AV I TD J 11420' DATE REV BY COMMENTS DATE REV BY COMMENTS 1 PRUDHOE BAY UNIT 11/19/81 ORIGINAL COMPLETION 09/26/06 RLM/PAG PATCH PULLED (01/09 & 01/10/06) WELL: 13 -09 02/04/83 RWO 03/15/08 JIM/TLH PATCH PULLED (01/10/06) PERMIT No: 1811580 08/28/03 ATD /KK SET TTP 06/08/08 JM/TLH PKR DEPTH CORRECTION API No: 50- 029 - 20671 -00 12/05/03 TJP/TLP SAFETY NOTE CHANGE SEC 13, T1 ON, R14E, 2382.77' FEL & 3095.89' FNL 02/07/04 MJA /TLP MIN ID, ECLIPSE PKR, REDUC NIP /PXN 06/22/04 ATD /TLH TTP SET CORRECTION 11 BP Exploration (Alaska) • TREE = 3RAY GEN 2 WELU-EAD GRAY • 13 -09 , SAFETY'S _ • ACTUATOR = AXLESON KB. ©.eV = 78' BF. ELEV = _? KOP = 1900' Max Angle = 47 (ij 7700' Datum MD = 10588' Datum 8806 SS O � I I! 2000' 4 -112" L -80 X- Nipple, ID = 3.812" _4 -1/2" MCX Injection Valve, Set Post -Rig 1 3 -3/8" CSG, 72/1 L-80, ID = , 24 ' I H 1 2925' T' L -80 Liner Hanger /LTP,J Minimum ID = 3.725" @ 10256' 4-1/2" XN NIPPLE • ■ 9855' • 4-1/2" L -80 X- Nipple, ID = 3.812" ,� ■ 9920 4-12 L 80 XIpple, D 3812 4 -112" TBG, 12.6#, L -Sd, .0152 bpf, ID= 3.958" 10020' , : Packer - 17" Scab- Liner, 26#, L -80, VarrrHC, ID = 6.276" H 10105' � 9990' 4 -112" L -BD X -PG pP le, ID= 3.812" 10105' 5-1/2" x 7" Unique Overshot Z ►Z 10159' 9 - 5/8" X 5 BOT PKR 1 5 TBG -PC, 178, 1-80, .0232 bpf, 1) = 4.892" H 10164' [10 5-1 /2" X 4 XO 1 ITOP OF 7" LNR H 10250' 1 , , I 10266' H 4 -112" ors XN F , 10= 3.725" 1 14 TBG, 12.6a, N-80, .0152 bpf, O 1 0248' H I - = 3.958" .' 10268' H 4-1/2" TUBING TAIL 1 10276' ELSE) TT LOGGED 02/05/88 1 9-5/8- CSC;, 471, L- 80/S00.95, ID = 8.881" H 10571' PERFORATION SUMMARY REF LOG: BHCS ON 11/13/81 * ANGLEAT TOP RIFF: 30 Q 10664' Note: Refer to Ploduct DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE ' 3-318" 4 10664 -10684 ' C 12/26/91 3.1/8" 4 10742 -10762 C 06121/84 3.1/8" 8 10772 -10792 C 11/20182 3-1/8" 4 10772 -10792 C 02/10/83 1081!' 29° SL DUMP BALER 12X11/84 4" 4 10837 -10831 S 01/31/83 4" 4 10832 -10836 S 01128/83 10820' 7" 8RI)GE PLUG 4" 4 10851 -10855 S 01/244,83 P8TO 11278' VO.ffff r LNR, 2911, L -80, .0371 bpf, to = 6.184" i i 1140W ► 4 :4 4. T 11420' DATE Riff BY CO iENts DIATE IRS ,f BY COMMENTS 1 1 BAY UNIT 11119/81 MGM. L COM PLERON ' - 011126106 RI Ai8!PAC3 PATCH PILLED (01/09 & 01I10/06) AEU: 13-09 021041*3 MO ' 63/15/08 JM01'LH PATCH PULLS: (01/10/06) PeRMT No: 1811580 '0612903 ATTACK SET TP - 06109/06 JWTLH PICK D9 COI TION ' API No: 50-029 1205/03 TJWI'LP SAPPY NOTE CHANGE S83C1 TiON, RIO, 2382.77' Fla. 33096.89' FN. '02/07/04 - WA/ TIP MN 0, EOLOSE PKR, I' %JC MP4PXN 'OW2104 A'TIYlLH VP SET CORRECTION 1 BP ibcploration (flasks) e e FRANK H. MURKOWSKI, GOVERNOR AIASIiA. O~ AND GAS CONSERVATION COMMISSION I 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bob Gerik Petroleum Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 1J " ,6 \(6 . Re: Prudhoe Bay Field, Prudhòe Bay Oil Pool, 13-09 Sundry Number: 306-177 "ii'" ¡;. ¡¡.¡ 0 í ti'~ It.,.. ~.þ ~""AE~Nt:J ' bh , --. (){"" i"'1 ¡ ~l ~3 tJJLU Dear Mr. Gerik: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a repnÞsentative 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 followiJi.g the date of this letter, or the next working day if the 23rd day falls on a ho~iday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this /bday of May, 2006 Enc!. e e Abandon Alter casing 0 Change approved program 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRQ¥A.L;h 20 MC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 Type of Request: . ''Wâr'tfir Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5 Permit to Drill Number: Other' 2. Operator Name: BP Exploration (Alaska), Inc. 3 Address· P.O. Box 196612 Anchorage, AK 99519-6612 7 KB Elevation (ftl: Explorator;1 D Service ~ 181·1580 6 API Number: 50-029-20671-00-00 9. Well Name and Number: 78 KB 13-09 8. Property Designation: ADL-028315 11. 10. Fleld/Pools(s): Prudhoe Bay Field 1 Prudhoe 011 Pool PRESENT WELL CONDITION SUMMARY Total Depth MD (ft), Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured) 11420 9613.57 11278 9487.05 10256, 10820 10819 Casing Length Si;r;& TVD Burst Collapse Conductor 80 20" 94# H-40 30 11030 110 1530 520 Surface 2395 13-318" 72# L-80 29 2424 29 2424 5380 2670 Production 10543 9·5/8- 47# L·8CJ/SOO·9!> 28 10571 28 8864 687018150 476015080 Liner 1158 7" 29# L -80 10250 114088591.47 9603 8160 7020 Perforation Depth MD (ft): 10664 - 10684 10742 - 10762 10772· 10792 Packers and SSSV Type: Perforation Depth TVD (ft): 8943.22 - 8960.65 9011.62 - 9029.24 9038.05 - 9055.7 3-1/2" Eclipse Patch Packer 3-1/2" Eclipse Patch Packer 5·1/2" Baker 3·H BOT Packer Tubing Size: 5-1/2" 17# Tubing Grade: L-80 Tubing MD (ft): 35-10164 Packers and SSSV MD (ft) 5850 5910 10154 12 Attachments: Descriptive Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14 Estimated Date for Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status afler proposed work: Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ ø Service Ga Commencing Operations: 16 Verbal Approval Commission Representative 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Bob Gerik Title Petroleum Engineer Signature ./.1.¿..JI Phone 564-4476 Date COMMISSION USE ONLY 5/29/2006 Abandoned 0 WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Bob Gerik 5/15/2006 Conditions of approval Notify Commission so that a representative may witness Sundry Number: Plug Integrity [j BOP Test 0 Mechanical Integrity Test æ( Location Clearance o Other· ('{ROMS 8Ft MAY 1 7 2006 ¡Approved by APPROVED BY THE COMMISSION Date S,/£,... DÞ Form 10-403 Revised 712005 OR\G\NAL Submit in Duplicale e TREE = GRA Y G8'J 2 I¡VS.U-EAD = GRAY A C!UA TOR 0 .lI,XLESON KB. ELEV = 78' BF. ELEV , '} KOP - 2800' t.,,!.,:x Angle- 47 @ 7700' Ontu rn MD = 10588' Oa\umTVD - 8800' 5S 13.3.i8" eSG, 72#, L-80, D = 12347" Minimum ID = 2.970" @ 5850' 5-1/2" ECLIPSE PATCH ~.1I2" TI3G-PG 17#, L-80, .0232 bpi, ID, 4.892" [ I TOP OF 4-1/2" TBG-PC [ ITOP OF 7" LNR I 4 ;/Z"TBG, 126#. N-80, .0152bpf, ID' 3.958" 10268' e SAFETY NOTES: RAPID TxlA COMM, PC LEAK 13-09 o 2033' -i 5-1f2" OTIS ROM SSSV NIP, 10 -':.5fì2" I 1 0077' 5-1/2" OTIS SlIDIr-G SLV. 10 = 4.562" 5850' m( TOP A<ROF ECLIPSE PATD-! SET02i07i04 5910' md iBTM Fl<ROF ECLIPSE PA T~· SET 01.'3'104 10135' -j 5-112" BOT PBR A5SY -1 10154' H 9·5I8"X5-1i2"BOTA<R 1 0164' 5-1.'2" X 4-1.'2" XO 4-1/2" OTIS xN NP, 10 - 3.725" I 4·1/2"X 2-7;f)' REDLX;N3 NIP Wi 2-7.'8" PXN . SET 01/27104 10268' -i 4·1i2"1UBINGTAIL I 10276' H EUvDTTLOGGED02!05i88 195/8" CSG, 47#, L-BOIS00-95. 10 = 8681" PERFORA TION SLMMII RY REF LOG: BHCS ON 11113181 ANGLEA TTOPPERF: 30 @ 10664' r-bte: Refer to R-oáuctbn œ tor histoflcal perl data SIZE SPF IN1ERJ AL Q:>nlSqz 0/>, TE J·3I8" 4 10664 . 1 0684 0 12126191 3·118" 4 10742 ·10762 0 06121184 3-1,'8" 8 10772 -10792 0 11120/82 3·1.'8" 4 10772-10792 0 02.'10183 4" 4 10827 ·10831 S 01.'31183 4" 4 10832-10836 S 01r28/83 4" 4 10851 .10855 S 01'/24/83 11278' 11408' 11420' ~- 29"SLDUrvPBAILER,2¡{)1l84 1 0820' -j 7" BRIO::;E PLtJ3 DATE REV BY COM~NTS DIllE Æ;V BY CO M\A8'J'TS PRLDHOE BAY LNrT 11119181 ORIGINAL COMPLErlON 12105'03 T .FITLP SAFETY NJ1E OiANGE WELL: 13-09 02/04183 RWO 01131/04 MJA..ITL P BTh! FKROF ECLIPSE PA TŒJ PERMIT I\b: 181'580 00,.10/01 RNITLH CORRECTlONS 02107104 MJA..ITLP MIN ID, EO-IPSE A<R, RIDLC ~JPIP;(N A R I\b: 5Q-029-2ÜÖ71-Ü0 08/Z2iO:J BJMiKK IBP(PARl1ALLY INFLA1H 06122/04 A m/TLH TTP SET OJ~ECTION SEC 13, T10N. R14E, 238277' FEL & 3096 39' FNl 08/28103 JJlTL H PU..L 6J IBP 08.128103 A lDiKK SET TIP BP Exploration (Afas kal I L bp .,. ,"'.'11. --...~ ~ ~..- ~~ ·'1'· .,. e e To: D. Cismoski, J. Bixby GPB Well Ops TL Date: February 14, 2005 From: Janet Sack, Design Engineer Est. Cost: ~ lOR: 200 BOPD Subject: 13-09i "Slickstick" Patch Request PBD13WL09-N Please perform the following procedure(s): Step Type Procedu re 1 S Pull slickstick patch. 2 E Set bottom packer. ':< S Run slickstick and set upper packer w/ Efire. v 4- F MIT tubing. 5 S Pull TTP. SBHPS. Current Status: Last injectivity: Max Deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S level: Tie in Log: SI, TTP set 8/28/03 at 10256' 24000 BWPD @ 196 psi (bad data likely due to metering) 47 degrees at 7700' 2.718" at 10256' reducing nipple N/A, tag TTP @ 10256' 7/21/04 LDL on 7/21/04 Not in Database SWS LDL on 8/22/03 Well 13-09 is a produced water injector with TxlA communication which is waiting on a waiver for PWI. The well also has a production casing leak. In order to be waivered for TxlA communication with a production casing leak, tubing integrity needs to be established. A LDL run on 8-22-03 found a leak in the tubing at approximately 5857'. The log indicated that the fluid was likely cretaceous water from a leak in the production casing between 5700-5850' which was dumpflooding into the formation. A PDS caliper log run on 8-29-03 shows the tubing is in good to poor condition, with a possible hole located at 5866'; agreeing with the LDL data. There are 4 additional joints with wall penetrations in excess of 60%. A slickstick patch was set over the leak from 5850'- 5910' on 2/7/04, with no problems noted. Following the patch, an MITIA failed with a LLR=2 bpm at 750 psi and an MIT-T failed with a LLR=1.2 bpm at 2000 psi. The most recent LDL run on 7/21/04 shows the slickstick patch leaking at 5880', at the slickstick connection in the middle of the patch. The objective of this procedure is to pull the old slickstick patch and place a new patch over the hole at 5857' to establish tubing intHgrity in 13-09i. If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W) 564-5663, (H) 274-0929, (Cell) 240-8037. e e cc: w/a: Well File J. Sack J. .Julian B. Gerik North Slope Distribution w/o: S. Rossberg 2 e e Patch Specs 5-1/2" Eclipse patch 10= 2.87", 00= 4.470", Pressure rating burst & collapse=6000 psi. Patch Depth All depths are referenced to SWS lDl 8/22/03. Patch Setting Depths are 5850'- 5910' Patch Length: 60' from element to element -2 slicksticks. Leak is at -5857' Jt 148 at 5780' (39') Jt 149 at 5819' (40') Jt 150 at 5859' (35') SHORTER JOINT ,H 151 at 5894' (39') Pre-Patch Slickline 1. RU SL. 2. Pull slickstick patch set at 5850'-5910'. Check condition of patch and please send email to Jennifer Julian if anything of interest found. Eline Set Lower Packer assembly 3. RU EL. Confirm the Packer BHA's have been driftec' w/ a 2 7/8" PXN plug. RIH and tie into SSSV & if necessary sliding sleeve (reference SWS lDl 8-22-03). log up to setting depth. NOTE: Caution must be used when tieing in with the lDl from 8-22-03. The lDl CCl is not very clear, likely due to corrosion, and will be difficult to tie to. It is recommended that the SSSV at 2033' be used to tie in initially, as well as use the 35' short joint directly below the leak. If there is uncertainty in the tie in, it may be necessary to log the sliding sleeve located at 10077'. Depth was checked against SSSV on first patch setting attempt. 4. Set lower Eclipse packer assembly at -5910' per manufacturer's recommendations. SL Set Tieback Assembly and Upper Packer Assembly 5. Confirm the all BHA's have been drifted wi a 2-7/8" PXN plug. 6. RU SL. Run -30' spacer with tieback receptacle per manufacturer's recommendations. 3 e tit 7. RU Efire with upper packer assembly. RIH and tie into SSSV. 8. Set upper Eclipse packer assembly at -5850' per manufacturer's recommendations. DHD Post Slickstick 9. MIT tubing to 3500 psi. SL (Post MIT Pass) 10. Pull TTP. 11. Obtain SBHPS. 4 , .. . STATE OF ALASKA .. ALA all AND GAS CONSERVATION COM.SION REPORT OF SUNDRY WELL OPERATIONS o o o RECEIVED 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic D Exploratory Service Stimulate 0 WaiverD A'~~ Re-enter Suspended W I 5. Permit to Drill Num er. 181-1580 R1 6. API Number: 50-029-20671-00-00 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 78 KB 13-09 8. Property Designation: ADL-028315 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Total Depth measured 11420 true vertical 9613.57 feet feet Plugs (measured) 10256 PXN, 10820 BP Junk (measured) 10819 Effective Depth measured 11278 true vertical 9487.05 feet feet Casing Conductor Surface Production Liner Length 80 2394 10542 1158 Size MD 20" 94# H-40 30 - 110 13-3/8" 72# L-80 30 - 2424 9-5/8" 47# K-80/S00-9 29 - 10571 7" 29# L-80 10250 - 11408 TVD Burst Collapse 30 - 110 1530 520 30 - 2423.97 5380 2670 29 - 8863.7 6870/8150 4760/5080 8591.47 - 9602.88 8160 7020 Perforation depth: Measured depth: 10664 - 10792 True Vertical depth: 8943.22 - 9055.7 ,.<f.... Ie ''''It,'~·' . r··.·· r: \)\P~~~U'~~~~Lk;::1.>' t: 11. Tubing: (size, grade, and measured depth) 5-1/2" 17# 4-1/2" 12.6# L-80 N-80 28 - 10164 10164 - 10268 Packers and SSSV (type and measured depth) 5-1/2" Baker 3-H BOT Packer 10154 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFL FEB 1 7 2DOo Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing pressure SHUT-IN SHUT-IN 15. Well Class after proposed work: Exploratory Development Service R1 16. Well Status after proposed work: Oil Gas D WAG WINJ R1 WDSPl D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl x Contact Sharmaine Vestal I ~J Title Data Mgmt Engr Printed Name Sharmaine Vestal Phone 564-4424 Date 2/14/2006 Form 10-404 Revised 04/2004 Submit Original Only e e 13-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACliIVITYDA:J"i: 1,"1F1 SUMMAR.~",~. 1/9/2006 ***WELL SHUT IN ON ARRIVAL*** (PRE PATCH) RAN 4.5 CENT WI 4.14 G.R. SAT DOWN @ 5836 SLM. PULLED TOP ANCHOR AND SLlCKSTICK @ 5834 SLM PULLED SLlCKSTICK FROM 5869 SLM ***CONTINUED ON WSR 1-10-06*** 1/10/2006 ***CONTINUED FROM WSR 1-09-06*** PULLED LOWER SLICK STICK ALL PACKING RECOVERED. RIG DOWN 3RD PARTY CRANE,AND RELEASED. RAN 4 1/2 GS WI 5112 SL ADAPTER,SAT DOWN @ 5897 SLM. LATCHED AND JARRED FREE,RECOVERED LOWER ANCHOR, AND ALL RUBBER ELEMENTS,RDMO *** LEFT WELL SHUT IN,TURNED WELL OVER TO DSO *** FLUIDS PUMPED BBLS 2 2 I ::::L .' - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD Alter CasingD Change Approved Program D 2. Operator SuspendD Repair Weill!! Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate D WaiverO Stimulate D Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 181-1580 Name: BP Exploration (Alaska), Inc. 78.00 8. Property Designation: ADL-0028315 11. Present Well Condition Summary: Development D Stratigraphic D 9. Well Name and Number: 13-09 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): ExploratoryD ServiceŒ Total Depth measured 11420 feet true vertical 9613.6 feet Plugs (measured) Effective Depth measured 10820 feet Junk (measured) true vertical 9080.4 feet Casing Length Size MD TVD Conductor 50 20" 94# H-40 30 80 30.0 - 80.0 Liner 1158 7" 29# L-80 10250 - 11408 8591.5 - 9602.9 Production 9222 9-5/8" 47# L-80 31 - 9253 31.0 - 7751.5 Production 1319 9-5/8" 47# SOO-95 9253 - 10572 7751.5 - 8864.6 Surface 2394 13-3/8" 72# L-80 30 - 2424 30.0 - 2424.0 Perforation depth: Measured depth: 10664 - 10684, 10742 -10762,10772 -10792 True vertical depth: 8943.22 - 8960.65,9011.62 - 9029.24,9038.05 - 9055.7 OtherD 6. API Number 50-029-20671-00-00 10256,10820 Burst 1530 8160 6870 8150 4930 None Collapse 520 7020 4760 5080 2670 Packers & SSSV (type & measured depth): @ 28 @ 5850 @ 10164 @ 5850 @ 5910 @ 10154 @ 2033 RECE IVE D MAtt 3 0 2004 AlaaIœ on & Gas Cons. Comnf . Anchorage IS8íOn 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Ga~MCf I W;~~;~bl Casing ~ressure Tubing ( size, grade, and measured depth): 5-1/2" 17# L-SO 3-1/2" 9.3# L-80 4-1/2" 12.6# N-80 3-1/2" Eclipse Patch Packer 3-1/2" Eclipse Patch Packer 5-1/2" Baker 3-H BOT Packer 5-1/2" Otis RQM SSV 10164 5914 10268 13 Prior to well operation: Oil-Bbl 0 Subsequent to operation: Well Shut-In 14. Attachments: 15. Well Class after proposed work: ExploratoryD 200 DevelopmentD Tubing Pressure 198 346 ServiceŒ 16. Well Status after proposed work: Operational Shutdown 0 OilD GasD WAG 0 GINJD WINJŒ] WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 303-361 Copies of Logs and Surveys run - Daily Report of Well Operations. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron }1y ~~ Form 10-404 Revised 12/2003 Title Production Technical Assistant Signature , - i! 0.: l r\~orl~ !564-4657 '..- . . IØ)MS BF L. Date 3/26/04 MAlS~Oß\ .... " - 13-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/27/04 T/I/O=O/O/O LOAD TUBING WITH 88 BBLS CRUDE AND TEST. PASSED 2ND MIT. AT 1000 PSI FWP=O/O/O 01/27/04 CONTINUE FROM 1/26/03 PULL P- PRONG @ 10,231' (SLM) PULL 4-1/2 PXN PLUG @ 10, 236' (SLM) SET 0&0 @ 5846 MD, 5826 SLM. MIT-T PASSED. DRIFT W/ DUMMY PATCH (4.5300 X 6' 2") TO X-OVER @ 10164' MD, 10145' SLM. SET 4-1/2 X 2-7/8 REDUCING NIPPLE @ 10,256 MD, 10,236 SLM. SHEARED CHECK SET @ 10,236 SLM. SET 2-7/8 PXN PLUG BODY IN REDUCING NIPPLE SET 39" P-PRONG (1.375" FISH NECK) IN PLUG BODY (200# SITP) ***WELL TO REMAIN S/I*** 01/31/04 SET LOWER PACKER ELEMENT OF AN ECLIPSE PATCH@ 5910'. WELL WAS SHUT IN UPON ARRIVAL. WELL LEFT SHUT IN. PAD OPERATOR NOTIFIED. 02/06/04 ***CONT FROM 02-06-04*** SET 51/2" WEATHERFORD SLICK-STICK @ 5894' SLM (OAL-31') GIVE WELL BACK TO DSO/WELL LEFT S/I*** 02/07/04 THE UPPER SECTION OF A 5.5" WEATHERFORD ECLIPSE PATCH WAS SET @ 5850'. CCL TO ELEMENT WAS 15.8'. PATCH RUN IN HOLE AND STABBED INTO SLICK STICK, DEPTH WAS CHECKED AGAINST SSSV NIPPLE. WELL LEFT SHUT IN. PAD OPERATOR NOTIFIED. 02/08/04 T/I/O=SI/O/O. IA FL. (PRE MIT). IA FL @ SURFACE. 02/10/04 WHP=350/50/0. PUMP 25 BBLS DIESEL DOWN IA FOR MIT. NEVER PRESSURED UP. LLRT =2 BPM @ 750 PSI. FWP=525/200/0. FLUIDS PUMPED BBLS 88 45 133 Crude Diesel TOTAL Page 1 '\t-.l6 It- I 2..1 SI2.DO '5 STATE OF ALASKA f)(7-J' 12.{ ç 13 ALASKA OIL AND GAS CONSERVATION COMMISSION ~ f¿k.,~J APPLICATION FOR SUNDRY APPROVAL TfVI L 20 AAC 25.280 1. Type of Request: 0 Suspend 0 Operation Shutdown D Perforate D VarianceD Annular DisposalD Abandon Alter Casinq 0 Repair Well Œl Pluq Perforations 0 StimulateD Time Extension 0 OtherD Chanqe Approved Proqram 0 Pull Tubinq 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 181-1580 /' Development D Exploratory D 3. Address: P.O. Box 196612 Service Œ]./ 6. API Number / Anchorage, Ak 99519-6612 Stratigraphic D 50-029-20671-00-00 7. KB Elevation (ft): 9. Well Name and Number: 78.00 KB 13-09 / 8. Property Designation: 10. Field/Pool(s): ADL-0028315 Prudhoe Bay Field / Prudhoe Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (md): Junk (md): 11420 9613.6 10820 9002.4 10256 None 10820 Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 50 20" 94# H-40 30 - 80 30.0 - 80.0 1530 520 Liner 1158 7" 29# L-80 10250 - 11408 8591.5 - 9602.9 8160 7020 Production 9222 9-5/8" 47# L-80 31 - 9253 31.0 - 7751.5 6870 4760 Production 1319 9-5/8" 47# SOO-95 9253 - 10572 7751.5 - 8864.6 8150 5080 Surface 2394 13-3/8" 72# L-80 30 2424 30.0 - 2424.0 4930 2670 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10664 - 10684 8943 - 8960.7 5.5 " 17 # L-80 28 - 10164 10742 - 10762 9012 - 9029.2 4.5 " 12.6 # N-80 10164 - 10268 10772 - 10792 9038 - 9055.7 Packers and SSSV Type: Packers and SSSV MD (ft): 5-1/2" Baker 3-H BOT Packer 10154 5-1/2" Otis ROM SSV 2033 12. Attachments: Description Summary of Proposal ŒJ 13. Well Class after proposed work: Detailed Operations Program ŒJ BO~etch 0 Exploratory 0 DevelopmentD ServiceŒJ 14. Estimated Date for DecembeG~003 .-/' 15. Well Status after proposed work: Commencina Operation: OilD GasD PluggedD AÞandonedD 16. Verbal Approval: . -./ WAGD GINJD WINJŒ] / WDSPLD Date: Commission Representative: Perpared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Babcock Printed Name Dan Babcock Title Petroleum Engineer Signature ~-~ Phone 564-5735 12/4/03 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .303- 3fo{ Plug Integrity D BOP TestD Mechanciallntegrity Test D Location Clearance c:fR E C E 'V ED Other: DEC - 4 2003 Subsequent Form Required: jo-t./:..£:j Alaska Oil & Gas Cons. COIpmission BY ORDER OF . Approved by: ..... ., , Sianed By THE COMMISSION Da&~chor?!Zh(~tJ ;3 \I . / Sarah Patin ~CAlNJNElÜ) IDEt 3 @ 2003 Form 1 0-403 Revised 2/2003 ORIG'~'A.'.^. R8DMS SF L DEC 1 0 ¡O03 SUBMIT IN DUPLICATE bp To: D. Cismoski/John Smart, GPB Well Ops TL Date: December 2, 2003 From: Jennifer Julian Design Engineer Kristin Carpenter Engineer Est. Cost: $90 M lOR: 900 BOPD Subject: 13-09i Diagnostics & "Slickstick" patch AFE: PBJD13009 This rocedure includes the followin ste s: 1 S Pull TTP. Run D&D holefinder. MIT-T. Drift. Run reducing nipple re slickstick Set 5 ¥2" Ecli se bottom slickstick assembl if MIT-T asses Run 1 slickstick assembl Set 5 Y2" Ecli se u er slickstick assembl . MIT-T. Pull PXN lu if MIT-T asses Post-slickstick. 51, TTP set 8/28/03 @ 10256' . 24000 BWPD @ 196 psi (bad data likely due to metering) / 47 deg rees @ 7700' 3.725" @ 10, 256' 4 ¥2" Otis XN nipple N/ A, tag TTP @ 10256' 8/28/03 PD5 Caliper Log on 8/29/03 Not in Database SWS LDL on 8/22/03 2 E 3 S 4 E 5 0 6 S Current Status: Last injectivity: Max Deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S level: Tie in Log: Well 13-09 is a produced water injector with rapid TxlA communication with a waiver for PWI. The well has developed a production casing leak which needs to be secured. In /" order to continue to be waivered for TxlA communication with a production casing leak, tubing integrity needs to be established. A LDL run on 8-22-03 found a leak in the . tubing at approximately 5857'. The log indicated that the fluid was likely cretaceous /' water from a leak in the production casing between 5700-5850' which was dumpflooding into the formation. A PDS caliper log run on 8-29-03 shows the tubing is in good to poor condition, with a possible hole located at 5866', collaborating the LDL data. There are 4 additional joints with wall penetrations in excess of 60%. The D&D Holefinder will be run on this well prior to setting a slickstick patch over the leak at 5857' in order to ensure there are no additional leaks above the patch depth. If no other leaks are found, the tubing patch will be run to establish tubing integrity in 13-09i. If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W)564-5663, (H)274-0929, (Cell)240-8037. cc: w/a: Well File J. Julian Slope Distribution w/o: S Rossberg Slickline & Pump, Set D & D Holefinder Plug and Pressure Test, & Drift 1. Shoot fluid levels on IA and Tubing and order fluids to load IA and tubing and for pressure test. 0 & 0 is a mechanical plug and does not need to be set in fluid packed environment. 2. RU SL, Pump, and fluids. Load IA and tubing (this step can be done earlier) 3. Pull TTP. Tie into 4-1/2" Otix XN nipple at drillers depth at 10256'. MU 0&0 plug, RIH. Tie in is critical for all tool setting depths. 4. RIH wI 0&0 to 5846' DO (Middle of joint 149, Reference POS caliper 8-29-03- caliper is about 2 feet off of driller's depths, but this is close enough). MIT tubing to 1000 psi. Bleed off pressure on IA & Tubing. If MIT Tubing passes, this confirms the upper most leak is isolated. Proceed to step 6 to run patch drift. /' 5. If MIT tubing fails at setting depth, PUH and reset 0&0 plug at 5185' DO. This is the middle of joint #132. Re-MIT TBG to 1000 psi. Bleed off pressure on IA & Tubing. If MIT Tbg fails, POOH and check plug condition (i.e. elements are not damaged). If elements appear to be damaged, redress tool and repeat step #4. If elements are in good condition ROMO. Consult with town engineer about further diagnostics to identify additional leaks. t"/ 6. Run dummy patch to crossover at 1 0164'. Deep drift is requested because eline /' may need to tie into sliding sleeve at 10077'. 7. Run reducing nipple with PXN plug (Min I.D. of patch is 2.87"). ONLY PROCEED WITH PATCH PROCEDURE IF MIT TBG PASSES Patch SQecs 5-1/2" Eclipse patch, 2 run system ID= 2.87", OD= 4.470", Pressure rating burst & collapse=6000 psi. Patch Depth All depths are referenced to SWS LOL 8-22-03. Patch Setting Depths are 5850'-5910' Patch Length: 60' from element to element-2 slicksticks. Leak is at ~5857' Jt 148 at 5780' (39') Jt 149 at 5819' (40') Jt 150 at 5859' (35') SHORTER JOINT Jt 151 at 5894' (39') Eline Set Lower Packer assembly 8. RU EL. Confirm the Packer BHA's have been drifted wI the PXN plug. RIH and tie into SSSV & if necessary sliding sleeve (reference SWS LDL 8-22-03). Log up to setting depth. NOTE: Caution must be used when tieing in with the lDl from 8-22-03.. The lDl CCl is not very clear, likely due to corrosion, and will be difficult to tie to. It is recommended that the SSSV at 2033' be us~d to tie in initially, as well as use the 35' short joint directly below the leak. If there is uncertainty in the tie in, it may be necessary to log the sliding sleeve located at 1 0077' . 9. Set lower Eclipse packer assembly at ....5910' per manufacturer's recommendations. . SL Set Tieback assembly 10. Run ....30' spacer with tieback receptacle per manufacturer's recommendations. Eline Set Upper Packer assembly 11. RU EL. Confirm the Packer BHA's have been drifted wI the PXN plug. RIH and tie into SSSV. 12. Set upper Eclipse packer assembly at ....5850' per manufacturer's recommendations. . DHD Post Slickstick 13. MIT tubing to 3500 psi. SL Post Slickstick (If MIT-T passes), 14. RU SL. Pull PXN plug 15. Put well on injection TREE = GRA Y GEN 2 WELU-EAD = GRAY ACTUATOR =. . AXLESON KB. ELEV = 78' BF. ELEV = --_ ? KOP= 2800' Max Angle = 47 @ 7700' Datum MD - 10588' DatumTVD - 8800' SS 13-318" CSG, 72#, L-80, D = 12.347' 2424' Minimum ID = 3.725" @ 10256' 4-1/2" OTIS XN NIPPLE 15-1 f2." TBG-PC, 17#, L-80, ,0232 bpf, 10 = 4.892" I 1 TOP OF 4-1/2" TBG-PC I 1 TOP OF 7" LNR I 10164' 10164' 10250' 141/2" TBG, 12.6#, N-80, .0152 bpf. 10 = 3.958" 1 10268' 19-5/8" CSG,47#, L-80/S0o-95, 10= 8,681" I 10571' PERFORATION SUMMA.RY REF LOG: BHCS ON 11/1 3/81 ANGLEATTOPPffiF: 30 @ 10664' t\bte: Refer to A'oductbn œ for historical perf data SIZE SPF INTER\! AL OpnlSqz DATE 3-318" 4 10664 - 10684 0 12f2.6/91 3-1/8" 4 10742 - 10762 0 06f2.1/84 3-1/8" 8 10772 - 10792 0 11 f2.0/82 3-1/8" 4 10772 - 10792 0 02/10/83 4" 4 10827 -10831 S 01/31/83 4" 4 10832 - 10836 S 01f2.8/83 4" 4 10851 - 10855 S 01f2.4/83 7' LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 11420' 11278' 11408' 13-09 SAFETY NOTES: ***T X IACOMM (02/07/03 WAIVER)*- - I I 2033' 10077' 10135' 10154' 5-1/2" OTIS RQMSSSV NlP,ID =4.562" 5-1/2" OTIS SLIDING SLV, 10= 4.562" 5-1/2" BOT PBR ASSY 9-5/8" X 5-1/2" BOT A<R 10164' -I 5-1/2"X4-1/2"XO 1 1 0256' -1 1 0256' 1 0268' 1 1 0276' 1-1 1 0820' DATE REV BY COMMENTS DATE REV BY COM'v1ENTS 11/19/81 ORIGINAL COM PLETION 08/16/03 JCfvVTLH PULL lap (REMA.INING FISH) 02104183 RWO 08/22/03 BJfvVKK SET BKR IBIP (PARTIALLY INFLA 06/10/01 RN/1LH CORRECTIONS 08/28/03 JJ/1LH PULLED lap 02/11/03 JP/1LH W AIV ffi SA FErY NOTE 08/28/03 ATD'KK SETH? 08/07/03 JCfvVTLP PULL lap @ 10405' 08/11/03 BJMcN'TLH FISH (IBP) 4-1/2" OTIS XN NP, 10 = 3.725" 1 TTP (08/28/03) 4-1/2" lUBING TAIL ELMO IT LOGGED 02/05/88 I 29" SL DUrvP BAILER 12101/84 I 7" BRIOOEPLUG I PRUDHOE BA Y UNIT WELL: 13-09 ÆRMIT No: 1811580 A PI No: 50-029-20671-00 SEC 13, T10N, R14E, 2382.77' FEL & 3095.89' FN T ) BP Exploration (Alaska) BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp November 24, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 13-09 (PTD 181-1580) Application for Sundry Approval Dear Mr. Aubert: Attached is Application to Cancel Sundry form 10-404 for Sundry #301-159. This request is to cancel the current sundry for rapid T x IA communication. This well will remain shut in until we can restore tubing integrity. We have set a tubing tail plug to secure the well. If you require any additional information or clarification, please contact either Joe Anders or myself at (907) 659-5102. Well Integrity Engineer Attachments 1) Application for Sundry Cancellation form 10-404 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon[~ Suspend[--I Operation Shutdown[--'] Perforate[--1 VarianceS--1 Annular Disposal r-~ Alter Casingr-'1 RepairWell[~ Plug PerforationsD Stimulater--1 Time Extension[~] OtherE Change Approved ProgramE~] Pull Tubing[--'"-] Perforate New Pool[~] Re-enter Suspended WellF-1 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r~ Exploratory[~l 181-1580 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic [~ Service ~ 50-029-20671-00-00 7. KB Elevation (ft): 9. Well Name and Number: 78 13-09 8. Property Designation: 10. Field/Pool(s): ADL-0028315 Prudhoe / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11407 feet true vertical 9602 feet Plugs (measured) 4-1/2" PXN Plug @ 10256' MD Effective Depth measured 10820 feet Junk (measured) 29" SL Dump Bailer @ 10819' MD true vertical 8924 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 50 20" 94# H-40 30 80 30 80 1530 520 Surface 2394 13-3/8" 72# L-80 30 2424 30 2423.97 4930 2670 Intermediate 9222 9-5/8" 47# L-80 31 - 9253 31 - 7751,5 6870 4760 Intermediate 1319 9-5/8" 47# SOO-95 9253 10572 7751.52 8864.55 8150 5080 Production 1158 7" 29# L-80 10250 . 11408 8591.47 9602.88 8160 7020 Liner Perforation depth: Measured depth: 10664' - 10684'~ 10742' - 10762'~ 10772' - 10792' True vertical depth: 8943.22' - 8960.65' ~ 9011.62' - 9029.24' ~ 9038.05' - 9055.7' Tubing:( size, grade, and measured depth) 5-1/2" 17# L-80 @ 28' - 10164' MD/4-1/2" 12,6# N-80 @ 10164' - 10268' MD Packers & SSSV (type & measured depth) 5-1/2" Baker 3-H BOT Packer @ 10154' MD 5-1/2" Otis RQM SSV @ 2033' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tieatment descriptions including volumes used and final pressure: 13 Representative Daily Avera.qe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Exploratoryr"~ DevelopmentE] Service r~ copies of Logs and Surveys run __ 16. Well Status after proposed work: Operational Shutdown BI oilF'l Gasl--I WAG I1--1 GINJI--I WlNJIk-! WDSPq--I Daily Report of Well Operations __ Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact John Cubbon / Joe Anders 1301-159 Printed Name ~.~. ~~~_,~, Title Well Integrity Engineer Signature Phone 907-659-5102 Date 11/24/03 50 20"94# H-40 30 80 30 80 1530 520 2394 13-3/8"72# L-80 30 2424 30 2423.97 4930 2670 9222 9-5/8"47# L-80 31 - 9253 31 - 7751.5 6870 4760 1319 9-5/8"47# SOO-95 9253 10572 7751.52 8864.55 8150 5080 1158 7"29# L-80 10250 . 11408 8591.47 9602.88 8160 7020 Form 10-404 Revised 4/2003 I;:(,?TD #1811580) Failed CMIT T x IA for SulJ .... Compliance Subject: 13-09 (PTD #1811580) Failed CMIT T x IA for Sundry Compliance Date: Thu, 29 May 2003 16:01:43 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> To: "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us3 CC: "AOGCC Bob Fleckenstein (E-mail)" <Bob__Fleckenstein~admin.state.ak.us>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Prudhoe_Bay~admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegfityEngineer~BP.com> Hi Winton and Jim, 13-09 (PTD ~1811580) Failed an AOGCC witnessed CMIT T x IA on 5/27/03. The well has a variance from the AOGCC for water injection with rapid T x IA communication and was undergoing it's sundry-required 2 year CMIT T xIA. A brief ann-comm history for the well is as follows: > 04/25/01: MITIA Failed, 250 psi~15 min, .9 gpm > 05/07/01: Email to AOGCC/ T. Maunder, verbal okay to continue injection while evaluating leak. > 05/13/01: SL set PXN @ 10,256' MD > 05/16/01: MIT-T & CMIT TxIA both Passed to 2500 psi > 05/29/01: CT pulled plug body > 01/09/02: MITOA Passed for sundry prep > 05/19/02: SI well, tubing went on a vac, IAP dropped to 9 ps/. LLRT-IA = 1 BPM @ 1800 psi diff. > 05/19/02: Sent email to T. Maunder, will run LDL, then switch to Rapid TxIA requirements. > 05/31/02: LDL indicated leak in tubing at 5864' ( 1 BPM at 1300 psi). > 06/01/02: Sent email to T. Maunder that we ran the LDL and located the leak. > 5/24/03: SL set a TTP in the XN at 10,245' SLM > 05/27/03: CMIT T x IA failed, LLR of 1.3 BPM at 2300 psi. Our plan of action is as follows: 1. Pull the TTP and set an IBP below the TT. 2. Repeat the'CMIT T x IA to 2500 psi against the IBP. 3. If the CMIT T x IA passes, return the well to injection. If you have any questions, or would like additional information, please let me know. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 <<13-09.pdf>> Nalne: 1.,-0.:).pdf , i [-) 13.-09.pdfi1 Type: Acrobat (application/pdf)l .~ JEncoding: base64 6/17/2003 4:19 PM MEMORANDUM ~O ,, ,, TO: Randy Ruedrich /~¥C¢~ Commissioner THRU: Jim Regg P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 27, 2003 (¢\~,'[~,'0''~ SUBJECT: Mechanical Integrity Test BPX 13-9 PBU FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer De Well I 13-9 P.T.D.I 181-158 Notes: 2 Year test as required by variance Sundry #301-159 P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: P.T.D. Notes: Pretest Initial 15 Min. 30 Min. Type testI I Test psiI I Casing I ' I I I I P/F I IType Inj. Type test IType Inj. Type test Type Inj. 'ype INJ. Fluid Codes = = 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 DS 13 to witness the 2 year MIT on well 13-9. This well has rapid tubing by inner annulus communication. A plug had been set in the tubing tail at 10256, the packer is at 10154. The pump truck was rigged up on the annulus and an injection rate of 1.25 bbl per minute at 2300 psi was established with the tubing pressure tracking the annulus. Further diagnostics will be needed to detennine the lOcation of the leak (possibly the wire line plug). M.I.T.'s performed: 1_ Attachments: Number of Failures: 1_ Total Time during tests: 1 hour cc: MIT report form 5/12/00 L.G. 2003-0527_M IT_PBU_I 3-9_cs.xls 6/17/2003 TREE = GRAY GEN 2 WFI LI-EAD = GRAY SAFETY NOTES: ***T X IA COM M (0210'~. ^O, UA O.-- 13 09, KB. ELEV = ...... 7'8" m ~ WAIVER)*** BF. ELEV = ' _--_? - -- ~'-- --"----' --- --" KOP = 2800. I DatumMaX Angle:MD: '"' 47-@10588'7700. F~-- -'--{, 2033' Id 5-1/2" OTIS RQM SSSV NIP, ID= 4.562" DatumTVD = 8800' SS , ! I ,~-~,,cs~,~#,,-~o,~=,~.~,H ~4, 1-~ i ; r~- ~ 10077' Id 5-1/2,,oTis SLIDINGSLV, ID=4.562" I I Minimum ID = 3.725" @ 10256' i 4-112" OTIS XN NIPPLE I ; : I ; ~ 10135' I I ~: ~--1 ~o~4: Id .-~,~..x I,~!~''~-~:,~'#,~°,°'°~,'~=~-*~'' Id ~o~' ~--x / t ~o~,~'" Id ~-,,~,,x~-~,xo I I.,~c~ oF.1/2,, T~-~c I-4 10164' t-- -- ' I~o~ o~," ,~ 15' ~0tS0. ~-- - , I ! 1' 10256~' I-{ 4-1/2"'OTIS XN NIP, ID=3.725'iI i i I.~ ~,~..,,~. ~.~. ~o..o~,,.,o= ~.,~,.. I-t ~o2~*' I . ~ E 10268' ]~ . 4-1'2" TUBING TAIL I I ~ot.~' ,Id ~ ~"°~ o~o~** I , · I ~/~" cs~,~#, ~o~o~, ,~= o.~,, H ~o~7~' I~ I , , I r'~ PERFORATION SUMMARY , RB: LOG: BHCS ON 11/13/81 ANGLE AT TOPPERF: 30 @ 10664' Note: Refer to Production DB for historical perf data :SIZE,3-~/8" SPFI4 10664INTERVAL- 10684 Opn/Sqz 'O 12/26,91DATE ~;-[ J------~ 10819' Id 29~' SL DUMPBAILER 12J01/84, 3-1/8" 4 10742- 10762 O 06/21/84 ' 4" I 4 10827 - 10831 $ ' 01/31/83 ~ 4" i 4 10832 - 10836 S i 01128183 ' ' ' ' II 4" ' 4 10851 - 10855 $ ~ 01124183 I I ., DATE I:ac-'V BY COMtVENTS DATE REV BY COJV~EN'TS PRUDHOE BAY UNIT 11/19/81. ORIGINAL COMPLETION WELL: 13-09 01/29/01I SIS-LG F~-'VISION I PERMITNo: 1811580 ,I 02/04/83~ I R'WO ! APl No: 50-029-20671-00 06/1 0/01 I RN/tlh [CORRECTIONS ~ SEC 13, T10N, R14E 2382.77 FEL 3095.89 FNL 1/03~ .. 02/1 JP/tlh iWAIVERSAFETY NOTE I I BP Exploration (Alaska) ....... , , PERFORATION SUMMARY RE~ LOG: BHCS ON 11/13/81 ANGLE AT TOPPERF: 30 @ 10664' Note: Refer to Production DB for historical perf data SIZE SPF I INTERVAL OpnJSqz DATE ' 3-~/8" 4 10664 - 10684 O 12/26/91 3-1/8" 4 10742- 10762 O 06/21/84 3-1/8" 8 10772- 10792 O 11/20/82 3-1/8" 4 10772 - 10792 O 02/10/83 4" 4 10827 - 10831 S 01/31/83 4" 4 1 0832 - 10836 S 01/28/83 4" 4 10851 - 10855 S 01/24/83 DATE I:ac-'V BY COMtVENTS DATE REV BY COIVlVlEN'TS 11/19/81 ORIGINAL COMPLETION 01/29/01 SIS-LG REVISION 02/04/83 ~ RWO 06/10/01 RN/tlh CORRECTIONS 02/11/03 JP/tlh WAIVER SAFETY NOTE Re: 13-(~D (PTD 1811580)Increased Leak Rate Subject: Re: 13-09 (PTD 1811580) Increased Leak Rate Date: Mon, 17 Jun 2002 09:14:46 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Justin and Joe, Sorry about that, I thought I had gotten back to you on this well. What you propose is appropriate. As noted previously, I think this is a good demonstration of how the "graduated" waiver system should work. By copy of this email, you have approval to change the "waiver status" from slow communication to rapid communication, with the result being a 2 year CMIT TxlA. Please place a copy of this message in the well file. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer~' wrote: Hello Tom, We ran the LDL on 13-09 on May 31, 2000 and identified the leak in the 5-1/2" injection tubing at 5864' MD. As a result of the increased leak rate, BP respectfully requests that this well be allowed to continue on injection and that the well will be switched to the testing requirements for rapid TxlA communication (2-year CMIT TxlA). Please let me know if you would like to discuss further or if you have any additional questions. Thanks, John Cubbon 659-5102 ..... Original Message ..... From: Tom Maunder [mai/to:tom maunder~,admin, state, ak. us/ Sent'. Monday, May 20, 2002 11:45 AM To: NSU, ADW Well Integrity Engineer Subject: Re: 13-09 (PTD 1811580) Increased Leak Rate Thanks for the information. Your proposal is appropriate. I think this demonstrates how the system should work. You previously identified that the well would not pass the standard MIT, MIT was demonstrated by an alternate means and an enhanced monitoring program was instituted. In the course of performing the required annual LLRT, a greater leak rate was identified. You are investigating further and will likely propose that the well continue injection with additional monitoring/MIT demonstration. Good luck with the diagnostics, keep us informed. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: > Hello Tom. > Water injection well 13-09 (PTD 1811580) has a variance (301-159) for slow I of 2 6/17/2002 9:14 AM Re: 13-(iD (PTD 1811580) Increased Leak Rate > TxlA communication. During the annual LLRT, the leak rate was observed to > have increased from the previous test. On 5/16/02, a leak rate of 11.5 GPM > 200 psi differential was noted. The previous leak rate on 4/22/01 was <1 GPM > @ 2200 psi dX On 5/19/02, injection was stopped, tubing pressure went on > a vac and the lAP decreased to 9 psi. A LLR of 1 BPM @ 1800 psi diffwas > established. The well is currently injecting 8700 BWPD @ 975 psi. Summary of > events: > 04/22/01: MITIA Failed, 400 psi/30 min, .9 gpm @ 2200 psi diff > 05/13/01: SL set TTP > 05/16/01: MIT-T Passed, CMIT TxlA Passed > 05/29/01: CTpulled plug body > 05/16/02: LLR = 11.5 GPM @ 200 psi differential > 05/19/02: SI well, tubing went on a vac, lAP dropped to 9 psi. LLRT. IA = BPM @ 1800 psi diff. > Current plans are to run an LDL to locate the leak point. We will then > request the well will be switched to the testing requirements for rapid TxlA > corem (2-year CMIT TxlA). > Please call if you have any questions or would prefer a different approach. > We'll keep you informed of progress. > > Joe > Joe Anders, P.E./Kevin Yeager > Well Integrity Engineer > BP Exploration, (Alaska) inc. > (907) 659-5102 > email: NSUADWWelllntegrityEngineer~bp. com Tom Maunder <tom maunder@admin.state.ak.us> sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 6/17/2002 9:14 Al~ Re: 13-09 (PTD 1811580) Increased Leak Rate Subject: Re: 13-09 (PTD 1811580) Increased Leak Rate Date: Mort, 20 May 2002 11:45:17-0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "NSU, ^DW Well Integrity Engineer" <NSUADWWelllntegdtyEngineer@BP.com> Joe, Thanks for the information. Your proposal is appropriate. I think this demonstrates how the system should work. You previously identified that the well would not pass the standard MIT, MIT was demonstrated by an alternate means and an enhanced monitoring program was instituted. In the course of performing the required annual LLRT, a greater leak rate was identified. You are investigating further and will likely propose that the well continue injection with additional monitoring/MIT demonstration. Good luck with the diagnostics, keep us informed. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Hello Tom. Water injection well 13-09 (PTD 1811580) has a variance (301-159) for slow TxlA communication. During the annual LLRT, the leak rate was observed to have increased from the previous test. On 5/16/02, a leak rate of 11.5 GPM @ 200 psi differentia/was noted. The previous leak rate on 4/22/01 was <1 GPM @ 2200 psi diff. On 5/19/02, injection was stopped, tubing pressure went on a vac and the lAP decreased to 9 psi. A LLR of 1 BPM @ 1800 psi diff was established. The well is currently injecting 6700 BWPD @ 975 psi. Summary of events: > 04/22/01: MITIA Failed, 400 psi/30 min, .9 gpm @ 2200 psi diff > 05/13/01: SL set TTP > 05/16/01: MIT-T Passed, CMIT TxlA Passed > 05/29/01: CT pulled plug body > 05/16/02: LLR = 11.5 GPM @ 200 psi differential > 05/19/02: SI well, tubing went on a vac, lAP dropped to 9 psi. LLRT-IA = I ~_~ BPM @ 1800 psi diff. Current plans are to run an LDL to locate the leak point. We will then request the well will be switched to the testing requirements for rapid TxlA corem (2-year CMIT TxlA). Please call if you have any questions or would prefer a different approach. We'll keep you informed of progress. Joe Joe Anders, P.E./Kevin Yeager Well Integrity Engineer BP Exploration, (Alaska)/nc. (907) 659-5102 emaih NSUADWWelllntegrityEngineer@bp. com I of 2 5/20/02 11:45 AM Re: 13-09 (PTD 1811580)Increased Leak Rate i~ Tom Maunder <tom maunder~'~.admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 5/20/02 11:45 AM BP Exploration Alaska Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp O June 12, 2001 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Summary of Current Injectors with Sundries 04-17 (PTD 186-020) Application for Sundry Approval 13-09 (PTD 181-158) Application for Sundry Approval M-13 (PTD 180-124) Application for Sundry Approval U-05 (PTD 184-168) Application for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Approval form 10-403 for wells 04-17, 13-09, M-13 and U-05. These requests are for approval to continue produced water injection with known tubing x inner annulus communication. A proposed Action Plan and wellbore schematic is included for each well. Also attached is a listing of all injectors operating under a Sundry in the Prudhoe Bay and GPMA fields. As the number of injection wells operating under a sundry has increased, the monitoring and test programs have evolved. To provide a consistent approach to monitoring each well type, we have proposed standard test requirement for 4 types of problems. If you require any additional informatiOn or clarification, please contact either Kevin Yeager or me at (907) 659-5102. Sincerely, J~oe Anders, P.E. Well Integrity Engineer Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS -- '1~ -I'yp; of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well_ ' ........... Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ (Ann Corn) Change approved program _ Pull tubing _ Variance _ Perforate Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_ RKB 78.0 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 service__x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 3989' FNL, 5124' FEL, Sec. 13, T10N, R14E, UM (asp's 687388, 5931361) 13-09i At top of productive interval 9. Permit number / approval number 2801' FNL, 2482' FEL, SEC. 24, T1 ON, R14E, U M (asp's 690133, 5927337) 181-158 At effective depth 10. APl number 50-029-20671 At total depth 11. Field / Pool 3098' FNL, 2384' FEL, Sec.24, T10N, R14E, UM (asp's 690239. 5927043) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11420 feet Plugs (measured) Tagged PBTD @ 10757' MD on 6/21/1999. true vertical 9613 feet CIBP set @ 10820' MD. Effective depth: measured 10757 feet Junk (measured) true vertical 9025 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 300 Sx PF 80' 80' Surface 2346' 13-3/8" 2400 Sx Fondu & 400 Sx PFC 2424' 2424' Production 10493' 9-5/8" 500 Sx Class G 10571' 8864' Liner 1158' 7" ago Sx class e 11408' 9603' Perforation depth: measured 10664'- 10684'; 10742'- 10762'; 10772'- 10792'. true vertical 8944' - 8961'; 9012' - 9029'; 9038'- 9056'. Tubing (size, grade, and measured depth 5-1/2% 17#, L-80 @ 10164 MD; 4-1/2", 12.6#, N-80 @ 10268' MD. "q.i:~"' ::::,~,';3 !~il,i'i' .,ii': :':.' ~, ,..:: Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" DOT PACKER @ 10154' MD. 5-1/2" Otis RQM SSSV Nipple @ 2033' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: · June 18, 2001· 16. If proposal was verbally approved Oil __ Gas __ Suspended __ Name of approver Date approved Service _ Water Init_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Joe Anders @ 659-5102. Signed Irs~~~~'~ Title: PRB Well Integrity Engineer (North Slope) Date Joe A Prepared by Paul Rauf 564-5799 FOR COMMISSION'USE ONLY Conditions of approval: Notify Commission so representative may witness ~ ~"~' ~ (~ ~._~ I Approval no./-),~, Plug integrity __ BOP Test __ Location clearance --I.L~(.,,)/' "1 Mechanical Integrity Test~ ~,.\ ~ ~'- Subsequent form required 10- ~'"'~2~,~1~;~.~, ~,,,?:~,~',-~ ~'¢.¢..~::~ ~ ~--~"~, ~,x'~ ~ I~, I L~..~,."~-. __~pproved b~..ord.er of the c~mmission ,,,~ricnal Si~ed By ... Commissioner ..... Date ...... / ...... Form 10-403 Rev 06/15/88 · Cammy 0echsli ORIGINAL SUBMIT IN TRIPLICATE 13-09 Sundry Application Action Plan 06/10/01 Well History and Status Well 13-09 (PTD 181-158) is an injector that failed an MIT-IA on 04/25/01. It would consistently loose 250 psi/15 minutes for an average leak rate of .9 GPM @ 3000 psi. On 05/16/01, a MIT-T passed against a tubing tail plug to 2500 psi a~-~ a CMIT-TxlA passed to 2500 psi, indicating competent production casing. During the CMIT TxlA, the tubing pressure increased with the IA, indicating a one-way leak from the IA into the tubing. This sundry request is to allow for continued injection of water into Well 13-09. The following supports the request: - A CMIT-TxlA Passed on 05/16/01 to 2500 psi against a tubing plug, demonstrating competent production casing. - Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. - An annual IA leak rate test will be conducted to monitor the leak severity. - If the leak rate increases over 10 GPM, the AOGCC will be notified and the sundry updated to reflect new conditions. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Perform an annual IA leak rate test. 4. Perform a combination MIT Tubing x IA against a plug every 4 years. 5. Submit a monthly report of daily pressures and injection rate. 6. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. 7. Notify the AOGCC if the leak rate increases over .5 BPM. ']:REE = GRAY GEN 2 WELLHEAD= GRAY ACTUATOR= AXLESON KB. ELEV: 78' BF. ELEV = ,~ .. KOP = 2800, Max Angle = 47 @ 7700' Datum MD = 10588' Datum TV D= 8800' SS 13-09 2033' 4OTES: I---'~ 5-1/2"OTISRQMSSSV NIPPLE, ID:4.562" I I 13-3/8" CSG, 72#, L-80, ID = 12.347" I--"~ 2424' IMinimum ID = 3.725" @ 10256' 4 1/2" OTIS XN NIPPLE 10077' I 5-1/2" OTIS SLIDING SLV, ID = 4.562" 10135' ] 10154'1 I 5-1/2 " BOT PBRASSY I 5-1/2" TBG-PC, 17#, L-80, 0.0232 bpf , ID = 4.892" TOPOF 4-1/2" TBG-PC ITOP OF 7" LNR I'~ I 4 I/2"TBG, 12.6#, N-80, .0152 bpf, ID= 3.958" Id I 9-5/8" CSG, 47#, L-80/SOO-95, ID= 8.681" Id PERFORATION SUMMARY REF LOG: BHCS on 11/13/1981 ANGLEATTOP PEP, F: 30 @ 10664' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10664 - 10684 O 12/26/91 3-1/8" 4 10742- 10762 O 06/21/84 3-1/8" 8 10772- 10792 O 11/20/82 3-1/8" 4 10772- 10792 O 02/10/83 4" 4 10827- 10831 S 01/31/83 4" 4 10832 - 10836 S 01/28/83 4" 4 10851 - 10855 S 01/24/83 10164' 10164' 10164'I 10250' 10256' 10268' 10571' ~ 10268'! L I 1°276' I 10819'I 11278' ~ 11408' 11420' 9-5/8" X 5-1/2" BOT PACKER I 5-1/2 "X4-1/2"XO I 4-1/2" OTIS XN NIPPLE, ID = 3.725" 4-1/2" TUBING TAIL ELM TUBING TAIL 02/05/88 I I7'' BRIDGE PLUG I 29" SL DUMP BAILER 12/01/84 DATE REV BY COMMENTS DATE REV BY COMMENTS 11/19/81 ORIGINAL COMPLETION 11/20/00 SlS-JH CONVERTED TO CANVAS 01/29/01 SlS-LG REVISION 02/04/83 RWO 06/10/01 RN/tlh CORRECTIONS PRUDHOE BAY UNIT WELL: 13-09 PERMIT No: 181-158 APl No: 50-029-20671-00 SEC 13, T10N, R14E 2382.77 FEL 3095.89 FNL BP Exploration (Alaska) Injector Sundry Review Slow TxlA Communication: leak rate < 10 GPM Recommended Requirements: Monthly Report Annual MITIA/LLRT CMIT TxlA 4-years Re-submit sundry if leak rate becomes high enough to log Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 01-08 8/15/2000 300-198 1 GPM @ 2500 psi Monthly Report Annual MITINLLRT CMIT TxlA 4-years 11-29 02/11/98 398-035 0.1 GPM @ 2400 psi Monthly Report Annual CMIT TxlA 12-02 10/20/93 93-286 MITIA's now pass Annual MITIA 12-27 10/08/93 93-269 MITIA's now pass Annual MITIA 13-09 1 GPM @ 3000 psi In progress, submitted 06/11/01 13-18 08/15/00 300-200 4 GPM @ 1300 psi Monthly Report CMIT TxIA 2-years 14-14 08/15/00 300-199 .7 GPM @ 2500 psi Monthly Report LLRT 1-year CMIT TxIA 4-years P1-01 07/22/98 398-188 2.4 GPM @ 3000 psi Monthly Repod Annual CMIT TxlA P2-34 09/20/98 398-243 MITIA Pass, 3 days to Monthly Repod equalize Annual CMIT TxlA U-05 6 GPM @ 1550 psi In progress, submitted 06/11/01 Y-03 4 GPM @ 1750 psi In progress, submitted 03/19/01 Rapid T x IA Communication: Leak rate > 10 GPM Recommended Requirements: Monthly Report CMIT TxlA 2-years Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 03-11 05/21/99 399-084 1 BPM @ 2400 psi Monthly Report CMIT TxIA - 2 years Note: Sundry aplication action plan refers to an expiration date of 5/21/01 04-17 2.5 BPM @ 400 psi In progress, submitted 06/11/01 04-45 07/05/00 300-173 1 BPM @ 1300 psi Monthly Report CMIT-TxlA 1 year 13-15 06/16/99 '399-091 .8 BPM @ 2900 psi Monthly Repod CMIT TxlA 2-years S:\Wells GroUp\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/12/2001 Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 13-17 10/21/98 298-275 >1 BPM Monthly Report CMIT TxlA 1-year 13-20 04/23/97 397-078 >1 BPM Monthly Report CMIT TxlA 1-years 13-31 08/01/00 300-199 2 BPM @ 2325 psi Monthly Report CMIT TxlA 2-years 14-21 12/17/99 399-248 1 BPM @ 2500 psi Monthly Report CMIT TxlA 1-year LPC-02 12/15/99 399-247 ,> 1 BPM Monthly Report Annual MITOA to 1500 psi Annual LLR on IA M-13 .25 BPM @ 2500 psi In progress, submitted 06/11/01 P-14 02/10/00 300-038 2.6 BPM @ 1950 psi !Monthly Report Y-10 4/20/2000 300-103 1.5 BPM Monthly Report CMIT TxlA 2-years IA x OA communication Recommended Requirements: Monthly Report CMIT IAxOA 2-years IWell No. Date Approved Approval No. Leak Rate Current Requirements Comments 03-10 05/09/00 300-106 1 GPM @ 2125 psi Monthly Report MIT-T 2 years 04-09 06/05/00 300-145 Rapidly Equalizes Monthly Report CMIT IAxOA 2 years 04-13 10/26/88 8-808 Rapidly Equalizes None 11-10 06/09/89 9-490 Rapidly Equalizes MITIA Annually 12-23 07/11/00 300-174 Rapidly Equalizes ~ Monthly Report CMIT IAxOA to 2100 psi, 2 years Production Casing Leak Recommended Requirements: Monthly Report Annual MIT-OA MIT-T 4-years Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 01-09 09/27/99 399-185 .7 BPM @ 2000 psi Monthly Report MIT-T Annually CMIT IAxOA 2 years Max IA pressure 1000 psi A-31 01/27/00 300-008 .5 BPM @ 3000 psi Monthly Report S:\Wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/12/2001 Injector Sundry Review Slow TxlA Communication: leak rate < 10 GPM Recommended Requirements: Monthly Report Annual MITIA/LLRT CMIT TxIA 4-years Re-submit sundry if leal< rate becomes high enough to Icg Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 01-08 8/15/2000 300-198 1 GPM @ 2500 psi Monthly Report Annual MITIA/LLRT CMIT TxlA 4-years 11-29 02/11/98 398-035 0.1 GPM @ 2400 psi Monthly Report Annual CMIT TxlA i2-02 10/20/93 93-286 MITIA's now pass Annual MITIA 12-27 10/08/93 93-269 MITIA's now pass Annual MITIA 13-09 1 GPM @ 3000 psi In progress, submitted 06/11/01 13-18 08/15/00 300-200 4 GPM @ 1300 psi Monthly Report CMIT TxlA 2-years 14-14 08/15/00 300-199 .7 GPM @ 2500 psi Monthly Report LLRT 1-year CMIT TxlA 4-years P1-01 07/22/98 398-188 2.4 GPM @ 3000 psi Monthly Report Annual CMIT TxlA P2-34 09/20/98 398-243 MITIA Pass, 3 days to Monthly Report equalize Annual CMIT TxlA U-05 6 GPM @ 1550 psi In progress, submitted 06/11/01 Y-03 4 GPM @ 1750 psi In progress, submitted 03/19/01 Rapid T x IA Communication: Leak rate > 10 GPM Recommended Requirements: Monthly Report CMIT TxlA 2-years Well No. Date Approved Approval No. Leak Rate C,u.rrent Requirements comments 03-11 05/21/99 399-084 1 BPM @ 2400 psi Monthly Repod CMIT TxlA - 2 years Note: Sundry aplication action plan refers to an expiration date of 5/21/01 0z~-17 2.5 BPM @ .4q0 p.si In progress, submitted 06/11/01' 04-45 07/0~/00 ~00-173 1 BPM @ 1300 psi Monthly Report CMIT-TxlA 1 year 13-15 0~o/16/99 399-091 ,.8 BPM @ 2900 psi :Monthly Report i CMIT TxlA 2-years s:\wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Alas!fa Oii :_ Revised: 6/12/2001 Well No. I~ate Approved Approval Ro. ' Leak Rate Current Requirements Comments 13-17 10/21/98 298-275 >1 BPM Monthly Repod OMIT TxlA 1-year 13-20 04/23/97 397-078 >1 BPM Monthly Report OMIT TxlA 1-years '~3-31 08/01/00 300-199 2 BPM @ 2325 psi Monthly Report OMIT TxlA 2-years 14-21 12/17/99 399-248 I BPM @ 2500 psi Monthly Report OMIT TxlA 1-year LPC-02 12/15/99 399-247 > 1 BPM Monthly Report Annual MITOA to 1500 psi Annual LLR on IA M-13 .25 BPM @ 2500 psi In progress~ submitted 06/11/01 P-14 02/10/00 300-038 2.6 BPM @ 1950 psi Monthly Report Y-10 4/20/2000 300-103 1.5 BPM Monthly Report OMIT TxlA 2-years IA x OA communication Recommended ReqUirements: Monthly Report OMIT IAxOA 2-years Well No. Date Approved Approval No. Leak Rate Current Req'uirements Comments 03-10 05/09/00 300-106 1 GPM @ 2125 psi Monthly Report MIT-T 2 years 04-09 06/05/00 300-145 Rapidly Equalizes Monthly Report OMIT IAxOA 2 years 04-13 10/26/88 8-808 Rapidly Equalizes None 11-10 06/09/89 9-490 Rapidly Equalizes MITIA Annually 12-23 07/11/00 300-174 Rapidly Equalizes Monthly Report OMIT IAxOA to 2100 psi, 2 years Production Casing Leak Recommended Requirements: Monthly Report Annual MIT-OA MIT-T 4-years Well No. Date Appr.,oved Approval No. Leak Rate Curre,nt Requirements ~omments 01-09 09/27/99 399-185 .7 BPM. @ 2000 psi Monthly Report MIT-T Annually OMIT IAxOA 2 years Max IA pressure 1000 psi A-31 01/27/;~)0 300-008 .5 ~PM @ 3000 psi Monthly Repod S:\Wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/12/2001 Injector Sundry Review Slow TxlA Communication: leak rate < 10 GPM Recommended Requirements: Monthly Report Annual MITIA/LLRT CMIT TxlA 4-years Re-submit sundry if leak rate becomes high enough to log Well No. Date Approved Approval No. Leak Rate Current Requirements Comments 01-08 8/15/2000 300-198 ,1 GPM @ 2500 psi ~Monthly Report Annual MITINLLRT CMIT TxlA 4-years 11-29 02/11/98 398-035 0.1 GPM @ 2400 psi Monthly Report Annual CMIT TxlA 12-02 10/20/93 93-286 MITIA's now pass Annual MITIA 12-27 10/08/93 93-269 MITIA's now pass Annual MITIA 13-09 1 GPM @ 3000 psi In progress, submitted 06/11/01 13-18 08/15/00 300-200 4 GPM @ 1300 psi Monthly Repod CMIT TxlA 2-years 14-14 08/15/00 300-199 .7 GPM @ 2500 psi Monthly Report LLRT 1-year CMIT TxlA 4-years P1-01 07/22/98 398-188 2.4 GPM @ 3000 psi Monthly Report Annual CMIT TxlA P2-34 09/20/98 398-243 .MITIA Pass, 3 days to Monthly Report equalize Annual CMIT TxlA U-0~ 6 GPM @ 1550 psi In progress, submitted 06/11/01 Y-03 4 GPM @ 1750 psi In progress, submitted 03/19/01 Rapid T x IA Communication: Leak rate > 10 GPM Recommended Requirements: Monthly Report CMIT TxlA 2-years Well No. Date Approved Approval .No. Leak Rate Current Requirements Comments ~3-11 05/21/99 399-084 1 BISM @ 24~0 psi Monthly Report CMIT TxlA - 2 years Note: Sundry aplication action plan refers to an i expiration date of 5/21/01 04-17 2.5 B~M @ 400 p.si In progress~ submitted 06/11/01 04-45 07/b5)00 300-173 1 BPM @ 1300 psi Monthly Report CMIT-TxlA 1 year 13-1'5 06/16/99 :~99-091 .8 BPM @ 2900 psi Monthly Report CMIT TxlA 2-years S:\Wells Group\Well Integrity Eng\Sundries\lnjector Sundry Review.xls Revised: 6/12/2001 Weil No. Date Approved Approval No. Leak Rate Current-Requirements Comments 13-17 10/21/98 298-275 >1 BPM :Monthly Repod OMIT TxlA 1-year 13-20 04/23/97 ' 397-078 >1 BPM Monthly Report OMIT TxlA 1-years 1.3-31 08/01/00 300-199 !2 BPM @ 2325 psi Monthly Report OMIT TxlA 2-years 14-21 12/17/99 399-248 I1 BPM @ 2500 psi Monthly Report' OMIT TxlA 1-year LPC-02 12/15/99 399-247 > 1 BPM Monthly Report Annual MITOA to 1500 psi Annual LLR on IA M-13 .25 BPM @ 2500 psi In progress, submitted 06/11/01 P-14 02/10/00 300-038 2.6 BPM @ 1950 psi Monthly Report Y-10 4/20/2000 300-103 1.5 BPM Monthly Report OMIT TxlA 2-years IA x OA communication Recommended Requirements: Monthly Report CMIT IAxOA 2-years Weil No. Date App, r0ved Approva, I No. Leak Rate Current Requirements Comment~ 03-10 05/09/00 300-106 1 GPM @ 2125 psi Monthly Report MIT-T 2 years 04-0'9 06/05/00 300-145 Rapidly Equalizes Monthly Report OMIT IAxOA 2 years 04-13 10/26/88 8-808 Rapidly Equali;J'es None 11-10 06/09/89 9-490 Rapidly Equalizes MITIA Annually ' 12-23 07/11/00 300-174 Rapidly Equalizes Monthly Report OMIT IAxOA to 2100 psi, 2 years Production Casing Leak Recommended Requirements: Monthly Report Annual MIT-OA MIT-T 4-years Well No. Date APproved Appr. oval No. Leak ,Rate Current Requirements Comments 01-09 09/27/99 399-185 .7 BPM @ 2000 psi Monthly Report MIT-T Annually CMIT IAxOA 2 years Max IA pressure 1000 psi A-31 01/27/00 300-008 .5 BPM @ 3000 psi Monthly Rep°rt S;\Wells Group\Well IntegritY Eng\Sundries\lnjector Sundry Review?Is : Revised: 6112/2001 ARCO Alas~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-24-92 REFERENCE: ARCO CASED HOLE FINALS · ~l~12 ~')-.C"~ 12-29-91 ~/~-'// ~~32- 12-29-91 ~~ ?~-~/ 12-29-91 ~9_ ~ ~ 12-28-91 . ~~/// 12-23-91 ~~3 ~ - 12-31-91 ~~-6~ ~ ~-3-92 /~~~- 1~2 12-~91 Prod Profile Run 1, 5" Temp Survey & Tag Run Run, 1, 2" InJ Proffie Run 1, 5" Perf Breakdown/Temp/Spinner Run 1, 5" Perf Breakdown Run 1, 5" Leak Detect Run 1, 5" Prod Profile Run 1, 5" Leak Detect Run 1, 5" InJ Profile Run 1, 5" InJ Profile Run 1, 5" PITS Run 1, 5" Prod Profile/Gas Lift Run 1, 2"&5" Prod Profile Run 1, 2"&5" Leak Detect Run 1, 2'&5" Leak Detect Run 1, 2"&5" Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camc° Please sign and return the attached Cop~r as receipt of data. RECEIVED BY ........ Have A Nice Day! Sonya Wallace APPROVED ATO- 1529 Trans# 9201 # CENTRAL FILES # CHEVRON D&M ~ # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED FEB 0 3 7992 Alaska Oil & Gas C~ns C,~r~i,ss~ STATE OF ALASKA ALASKA {~ AND GAS CONSERVATION CO{" REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing ... Alter casing Repair well 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic 4. Location of well at surface 1290' FSL, 155' FWL, Sec. 13, T1 ON, R14E, UM At top of productive interval 2478' FSL, 2797' FEL, Sec. 24, T10N, R14E, UM At effective depth At total depth 2180' FNL, 2900' FWL, Sec. 24, T10N, R15E, UM Perforate X Other 6. Datum of elevation(DF or KB) 78 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-9 9. Permit number/approval number 8~-158 4/31 10. APl number 50 - 029-20671 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11420 feet Plugs(measured) 9613 feet Effective depth: measured 11278 feet true vertical 9487 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 80' 20" 300 sx PF '. 80' Sudace 2424' 13-3/8" 2400 sx Fondu 400 sx PermafroSt C 2424' Production 10571 9-5/8" 500 sx Class G Cmt 10571' Liner 1158' 7" 390 sx Class G Cmt 11408' True vertical depth 80' 2420' 8864' 9602' Perforation depth: measured 10664-10684', 10742-10762, 10772-10792 true vertical 8944-8961 ', 9011-9029, 9038-9056 Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 10164', 4-1/2", 12.64¢, N80 @ 10268' Packers and SSSV (type and measured depth) BeT packer @ 10154', Otis RQY SSSV @ 2033' 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) JAN 2 3[192 Treatment description including volumes used and final pressure ~1~ 0il & ~as Cens. cemmi{Siel Reoresentative Daily AveraQe Produ~i0n or Injection D~t~ ~ ..... ~- OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6800 0 690 Subsequent to operation 7150 0 69O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil~ Gas ~ Suspended Service, Water Injection.. 17. I hereby certify that the fore 'g(/9~;I is true and correct to the best of my knowledge. Signed ,/~'~'~u~ (-~' ~T'-"~'/,.-=~.~.------.__ Title Senior Engineer Form 10-404 Rev 06/15/88///// Date SUBMIT IN DUPLICATE WELL 13-09 SAG RIVER PERFORATING COMPLETED 12/26/91 1. Rigged up E-line unit and pressure tested lubricator. 2. RIH with perforating guns and tied in to Reference Log. . Perforated the Sag River interval 10664'-10684' (Ref. BHCS 11/13/81) at 4 SPF. 4. RD ELU and returned well to injection. RECEIVED JAN 2~ 2 $992 Alaska Oil & Sas Cons. Anchora~ 2 -i 1. ~400 PSI 7' W~LI.H$.~ CONN~CTOIq ~'~ 2. SO00 PSI WI~[I. INI: ~ (~kl~l,~l.[ SIZE:) 4. $000 PSi · 1/6" fLOW ~B[ II)ACX-Of'~ RECEIVED Sas Cons. Commisslen Anchorag8 ARCO ALASKA, INC F'. O. BOX i ANCHORAGE, ALASKA 2 DATE' t.-t 5-92 REFERENCE ' ARCO CASED HO~E F~L.S 2-29-9i CCL/F ERF~.-/' 2-29-91 F'FC-GR i '.-'-3i -9i:~ ~'.F. C-G R ~/~/ 2-26-9t ~CL/F'ERF // 2-26-91 CCL./K~Kr 2-26-9t CUL/'PERF ~ / 2-27-9t CCL/PERF 2-28-~i CCL/F'ERF -- RUN t, 5 · RUN i , 5 · RUN i, 5 · RUN t, 5 · RUN i, 5 · RUN t , 5' RUN i , 5 · RUN t , 5' RUN t, 5" PLEASE SIGN,AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. ATLAS ATLAS ATLAS Al'LAS A'fLA~ ~ILAS A[LAS ATLAS ATLAS R ECEIVEI) BY __~__~'.. HAVE A NICE DAY! SONYA WALLACE A TO- i 529 DISTRIBUTION , . CEIVED AP'F'ROVED'~'--v~ ~ ,I'A~ ~ ~ TRANS.$ 92~08 ....... 1992. Alaska Oil & Gas Cons. Commission Anchorage ~ CENTRAL FILES ,,. CHEVRON D & M ~: EXTENSION EXPLORATION ~ EXXON MARATHON .,,. MOBIL ,,- PHILLIPS F'B WEL. L FILES R & D ,,.~" BF'X ~~ STATE OF ALASKA TEXACO * THE CORRECT AF'].~: F'OR I),S'~2-3i IS.,' 50-029-22228. STATE OF ALASKA ALASKA i,' _ AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIOI IS' Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Obher 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1290' FSL, 155' FWL, Sec 13, T10N, R14E, UM At top of productive interval 2478' FSL, 2797' FWL, Sec 24, T10N, R14E, UM At effective depth At total depth 2180' FSL, 2900' FWL, Sec 24, T10N, R14E, UM 5. Type of Well Development Exploratory Strafigraphic Service 6. Datum of elevation(DF or KB) 78 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-9i 9. Permit number/approval number 81-158 / 91-253 & 91-235 10. APl number 50 - 029-20671 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11420 feet 9613 feet Plugs(measured) Bridge Plug set @ 10820' MD. Effective depth: measured 10820 feet true vertical 9080 feet Junk(measured) Casing Length Size Cemented Measured depth Truevertlcal depth Conductor 80' 20" 300 Sx Permafrost 80' 80' Sudace 2346' 13-3/8" 2400 Sx Fondu & 400 Sx PFC 2424' 2420' Production 10493' 9-5/8" 500 Sx CIG 10571' 8860' Liner 1158' 7" 390 Sx CIG 11408' 9602' Perforation depth: measured 10742 - 10762'; 10772 - 10784'; 10784 - 10788'; 10788 - 10792' true vertical 9011 - 9029'; 9038 - 9049'; 9049 - 9052'; 9052 - 9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 10164' MD; 4-1/2", 12.6#, N-80, PCT tail @ 10268' MD. Packers and SSSV (type and measured depth)BOT Packer @ 10154' MD; Otis RQY SSSVF~I~0~.,;~., ~ n 13. Stimulation or cement squeeze summary ~'~ ~- ~,' ~'' ' ' -- - 14. Intervals treated(measured) see Attached DFc. C 2 4 ~{99~ Treatment description including volumes used and final pressure Alaska 0ii & Gas Cons. C0mm%sst0~ A. nnhnra~t~ Representative Daily Averaae Production or In!ection Dat~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 5000 - 380 Subsequent to operation 4000 350 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE RHL cc: SW, JWP. 13-09i DESCRIPTION OF WORK COMPLETED FILL CLEANOUT & XYLENE/ACID WASH 8/25/91: RIH & tagged bottom at 10783' MD. 8/26/91: A Fill Cleanout & Xylene/Acid wash were performed as follows: MIRU CT & PT equipment to 4000 psi. RIH w/CT mounted swirl nozzle, & performed a fill cleanout down to 10812' MD, to uncover the open perforation intervals located at: 10742 - 10762' MD (Z4) 10772 - 10784' MD (Z4) 10784 - 10788' MD (Z4) 10788 - 10792' MD (Z4) Ref. Log: BHCS 11/13/81. Jetted fill out of wellbore w/851 bbls of 1/2# Gelled Biozan, then pumped 35 bbls of 7.5% HCI w/Xylene, while reciprocating over the perforations (listed above). Switched back to pumping 1/2 # Gelled Biozan to displace acid into the formation, then pumped a total of 42,750 scf of Nitrogen down the tubing at 500 scl/min. Let pressure build up to 1400 psi, then bled off to tank quickly to surge the perforations. Waited for one hour, then resumed jetting 175 bbls of 1/2# Gelled Biozan, to repeat a fill cleanout down to 10804' MD. Displaced CT w/40 bbls of Meth Water. POOH. Rigged down. 8/27/91: RIH & tagged bottom at 10794' MD. Returned well to produced water injection & obtained a valid injection rate. RECEIVED Alaska Oil & Bas Cons. Commission Anchorage 1. Type of Request: ,-. STATE OF ALASKA APPLICAI-ION FOR SUNDRY APPROVA : 2. Name of Operator ARCO Alaska, Inc. Abandon Suspend Alter casing Repair well Change approved program Operation shutdown Plugging Pull tubing Vadance 5. Type of Well Development Exploratory Stratigraphic Service X 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1290' FSL, 155' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 2478' FSL, 2797' FEL, Sec. 24, T10N, R14E, UM At effective depth Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) RKB 78' feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-9 9. Permit number 8~-158 10. APl number 50 - 029-20671 11. Field/Pool Prudhoe Bay Oil Pool At total depth 2180' FNL, 2900' FWL, Sec. 24, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 11420 feet Plugs(measured) 9613 feet Effective depth: measured 11278 feet true vertical 9487' feet Junk(measured) None Casing Length Size Cemented Measured depth Structural 80' 20" 300 SX Permafrost 80' Conductor Su dace 2424' 13-3/8" 2400 sx ronda 2424' 400 sx Permafrost C Production 10471' 9-5/8" 500 sx Class G Cmt 10571' Liner 1158' 7" 390 sx Class G Cmt 11408' True vertical depth 80' 2420' 8860' 9602' Perforation depth: measured 10742-10762'; 10772-10792' true vertical 9011-9029'; 9038-9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 10164' Packers and SSSV (type and measured depth) BOT packer @ 10154'; Otis RQY SSSV @ 2033' 13. Attachments Description summary of proposal ,X Detailed operations program BOP sketch X 14. Estimated date for commencing operation December 1991 16. If proposal was verbally approved Oil , Gas Name of approver Date approved Service 17. I hereby certify that the ' is true and correct to the best of my knowledge. Signed ~~_ 6f,:~ Title Wellwork Coordinator ' FOR coMMIssION U~E ONLy Conditions of approval: No ~f~ommission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~(..c 4' 15. Status of well classification as: Suspended Injector Date Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Date //,~-~-~--.?'/ . Form 10-403 Rev 06/15/88 c: SW SUBMIT IN TRIPLICATE WELL 13-09 PERFORATING PROCEDURE . . 3, MIRU ELU and test lubricator. Perforate the Sag River interval 10666'-10682' MD, (Ref. BHCS 11/13/81) at 4 SPF. RD ELU. 4 3 2 CO,LID TIJBI[NG UNIT BOP 1. ~)00 PSi ?" I~LL~ COIa~CTOR rL, AhC~ 2. :~)O0.P$1 41/1&" PiPE ~ 4. ~ ~'4 t/~- ~ ~ s. ~ ~ 4 ~/~i- ST~r~ BOX 4 3 HII~LINE ~ EGUIPHEN? _ 1. ~K)O0 PSI ?" W[LLH~ ~N[CIOR t' 2. SO00 PSI WIR[LIN[ RAIDS (VARIABL[ S 3. SO00 PSI 4 1/6" LUBRICATOR 4. SO00 PSI 4 1/~" FLOW TUB[ PACK-C ,, _ STATE OF ALASKA APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Vadance Perforate Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service X 4. Location of well at surface 1290' FSL, 155' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 2478' FSL, 2797' FWL, Sec. 24, T10N, R14E, UM At effective depth At total depth 2180' FSL, 2900' FWL, Sec. 24, T10N, R14E, UM 6. Datum of elevation(DF or KB) 78 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-9i 9. Permit number 81-158 10. APl number 50 - 029-20671 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11420 feet 9613 feet Plugs(measured) Bridge Plug: 10820' MD Effective depth: measured 10820 feet true vertical 9080 feet Junk(measured) Casing Length Size Structural 80' 20" Surface 2346' 13-3/8" Production 10493' 9-5/8" Liner 1158' 7" Cemented Measured depth 300 sx Permafrost 80' 2400 sx Fondu & 2424' 400 sx Permafrost C 00sxc, ECEIVED 0 , 390 sx Cl G 1408' True vertical depth 80' 2420' 8860' 9602' Perforation depth: AU G 2 6 1991 measured 10742-10762'; 10772-10792' Alaska 0il & Gas Cons. C0mmisslen true vertical 9011-9029'; 9038-9056' Anch0rage~ Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 10164' MD; 4-1/2", 12.6#, N-80, PCT tail @ 10268' MD Packers and SSSV (type and measured depth) BOT packer @ 10154'; Otis RQY SSSV @ 2033' MD 13. Attachments Description summary of proposal X Detailed operations program 14. Estimated date for commencing operation September 1991 16. If proposal was verbally approved Name of approver Date approved Service Injector 17. I hereby,certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~"~ ~ ~ Title Sr. Area Operations Engineer FOR COMMI~-~ION LI~I= (3NLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- BOP sketch X 15. Status of well classification as: Oil Gas Suspended Date Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY L0.NN!E ~ SMITH I Approval No. q/ Returned Commissioner Date 743 RHL cc: SW, JWP SUBMIT IN TRIPLICATE Drill Site 13-09 Fill Cleanout/Stimulation The objective of this treatment is to get the lower perforations, which are covered with fill, to take miscible injectant alternating with produced water injectant. The following procedure will be used: * Mechanically jet tubing/liner with slick water and biozan gel · Jet bottom fill with gel; use acid/xylene as needed on hard fill · Squeeze acid/xylene through perfs to clean them and to avoid producing significant H2S. · Surge perfs with AL gas or nitrogen · Circulate surged material out of the hole · Fluid maximums are: - 900 bbls slick water - 300 bbls biozan gel - 30 bbls HC1/xylene t ECEIVED Al./6 2 6 1991 .Oil & Gas Cons. Commissien ~chorage 6 5 4 2 COILED TUBING UNIT BOP EGU ! PMENT 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING; BOX 2 RECEIVED AU G 2 6 1991 ,Oil,.& Gas Cons. commissien ~cltorage.' H]RELINE BOP EOUIPHENT I I II IIII I 1. 5000 PSI ?" WELLHEAD OONN£CIOR FLANGE 2. 5000 PSI WIRELIN£ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ALASKA( APPLICA STATE OF ALASKA _ AND GAS CONSERVATION C~¢ /IlSSION 0 'ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. Operation shutdown Re-enter suspended well Plugging ~ Time extension Stimulate X Pull tubing Vadance Perforate Other 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 1290' FSL, 155' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 2478' FSL, 2797' FWL, Sec. 24, T10N, R14E, UM At effective depth At total depth 2180' FSL, 2900' FWL, Sec. 24, T10N, R14E, UM 6. Datum of elevation(DF or KB) 78 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-9i 9. Permit number 81-158 10. APl number 50 - 029-20671 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11420 feet 9613 feet Plugs(measured) Bridge plug: 10820' MD Effective depth: measured true vertical Casing Length Conductor 80' Sudace 2346' 10820 feet 9080 feet Junk(measured) Size 20" 13-3/8" Production 10493' 9-5/8" Liner 1158' 7" Cemented Measured depth 300 sx Permafrost 80' 2400 sx Fondu & 2424' 400 sx Permafrost C o0sxc, 390 sx Cl G ~ I.~11408' True vertical depth 80' 2420' 8860' 9602' Perforation depth: o 1991 measured 10742-10762'; 10772-10792~1.,.~ true vertical 9011-9029'; 9038-9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT@ 10164' MD; 4-1/2", 12.6#, N-80, PCT tail @ 10268' MD Packers and SSSV (type and measured depth) BeT packer @ 10154' MD; Otis RQY SSSV @ 2033' MD 13. Attachments Description summary of proposal X 14. Estimated date for commencing operation August 1991 16. If proposal was verbally approved Name of approver Date approved Detailed operations program 15. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the f~.regoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer FOR COMMI.~ION LI.~E ONLY Conditions of approval: Notify Commission so representative may witness 'Location clearance Subsequent form required 10- BOP sketch X Approved Copy Reti~ne~ . Commissioner Approval Ne.p/.. Plug integrity BOP Test Mechanical Integrity Test Original Signed BY David W. Johnston Approved by order of the Commissioner suBMI-I~ IN '~RIpLICATE Form 10-403 Rev 06/15/88 731 RHL cc: SW (2), JWP Drill Sitel3-9i Zone 4 Selective Stimulation This selective stimulation is to increase injectivity into the lower portion of the Zone 4 interval. Stimulation will be accomplished as follows: 1. Jet out wellbore fill with slick water, and if needed, HC1/xylene. 2. Pickle wellbore with 2,100 gallons of 15% hydrochloric acid containing 10% dispersed xylene. 3. Stimulate Zone 4 interval with the following sequence: a. Ball out high perm zone with ball sealers b. 6,300 gallons water with 10% xylene and 1% oil-cutting surfactant c. 6,300 gallons 2% hydrogen peroxide d. 6,300 gallons 6% hydrochloric acid e. 2,500 gallons water with 1% foaming agent plus 210,000 SCF nitrogen for foam diversion f. 6,300 gallons water with 10% xylene and 1% oil-cutting surfactant g. 6,300 gallons 2% hydrogen peroxide h. 6,300 gallons 6% hydrochloric acid i. 13,650 gallons 1% potassium chloride water to flush 5 4 3 2 COILED TUBINt3 UNIT BOP EOU l PMEN7 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYD~ULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~X)O PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX HIREL INE BOP EOU! PHENT 1. 5000 PSI 7" WELLHEAD CONNECIOR IrLANGI 2. 5000 PSI WIRELINE RAUS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-GlrIr F'~O, BL]X t00:560 ANCHORA6E: ALASKA ~o~'i, ,_.. (.*:.. DATE' 5,/25/90 REF'E:RE:NCF' ARCO CASED HOLE FINALS R ' EIVED 4-i =~' 5--S-90 5 .- :2 _,':;:-. __.¢~ ";; t ~ ''~ '-' i ~ -- 89 :5'725 i '2- i 3-90 ~"" -"~ ~= i o ._ t :5 - 90 .,.' . ..&....' .~;o 6-t 8 '5-6-90 7.-~ i S 9-- :38 5 - 4 - i 2.-6 ~-.-?- o~.'; i :~-'.5 5-4-90 i '.~,-- 9 5 -. S .-' 9 <..';, i S,- i :~',:. '.5 -S .- o, ¢,... i :5.-29 5-5--90 i 4--,5 4.;--"~. <;'-'.~ 0 f '7-- i '~ ~' t 8'--7 5-4-90 I N.JIECT]:ON F'R(3F']: L. EE '¥EHF', G/R TVI) BHC. ACOU,, G/Fi: 'i-VD ]"VI) DLIAI_ INOUCTION 6,/'F;..' F'RODUCT I:ON I::'ROF' T_ LE P [":: R F' Fi:ECORD S'TA T I C TEMF' PUMP-IN "f' E:M P P F.: 0 D U C'1" :1:0 N F' R 0 F :I: I._ Ii/ I N J E C-I" I 0 N P R CI F ]: L. E F'ROD, PROF"' I LE F' R 6.1D U C T ]: 0 N F:' F.'. 0 F' I L. E P F;,' 0 D U C '¥ I 0 N F' F,'. 0 F' :1: I.. E LEAK DETEC'f'Z ON F'UMF'-IN T E'-MF' RUN i, 5" F:UN i, 5" RUN i.. RUN t , F;:UN t, 5" RUN i , 5 RUN i , RUN t, "",' F,'UN i, 5 RL.N i RUN t , RUN t , 5." RUN t, 5 RUN t , ">" .-~ ~,~ r.~.' tl RUM t , C A M C 0 C A H C 0 A 'r L.A .:.; A T I.' A .~ CAMCO i:CI..I C". A M C 0 CAliCO C' A H C 0 C A M C 0 C A M C 0 CAMCO C A ?'i C O C A M C 0 F'I...E:A..gE *"IC.N AND RETLJF:.N THE AT f'F.~CI--IED C'.OPY AS F'~E.,EIF'T .OF DATA I-]'.ECE I VI--D BY 14AVE A N]:CIF DAY! SAL..L.Y HOFFECKER A '1' [] - i .5 '29 'f'I;,'AN $:~ 90'200 !)ISTRIBUT]:ON ~ CENT'RAI_ FILES ,~'"'CHEVRON D & M ~I: EXTENSION EXF'LORATION JL ~ EXXON MARATHON · r MOBIL :~ F' H ! I._ L. :[ F' PB WELl_ R & D f,= B F:' :x: 'f'EXACO D A T E ' 2 - 'i 4 - 90 REFEF,'ENCE' AI;,'CO PRESSURE DATA J'-JA ~'i-23-89 BHF'--8'TATIC GRADIENT CAMCO 2-8 i i -3¢.'-89 81"tF ..... 'S'TATIC: (;-RAD rENT CAMCO S -. '7 i 2 '- 4 - 89 B H F .... ~' "[' A T ]: C [;. R A D Z E N T C A H C 0 S--i'(} i i-25-89 BHF'--iZ'FATIC C;.RF~DIIENT CAMCO -4-'* i.~_ i i .-24.-cjc;',. , DF-IF .... :':: T A'F'l'r'.~ ~, C;RAD ]: EN'i" I']AHCO_ 7-5 ~;2'7-89 BHF ..... ~"TA/El: C (;RADIIENT CAMCO i 7: -.;. =:'i i - 24--- a~ ..... v B H F .... ~.; T A T :t: C.. C~ R A D ]: E N T C A f.'~' C 0 'i :T~-'7' 'i 2-i 6-89 BHF ..... 3~TA'TZ(] C~I:;:AD:EtEN i' CAMCO · i 3:-22 t 2-i 6-89 BHF ..... S"['ATIC C~RADIE:NT C:AHCO ! 4-i S t 2--6--89 BHF ....;~:TA'TIC GF;:ADIEN'f' [SAMCO i4-27 t2-i7-89 BHF ....&'TATIC CfRADIENT C:A[~CO i 4-'-:~i t 2-4-89 BHP:--;~TAT.[C C~RADiENT CAM(SO t .4-S6 i 2-i 6-89 BHF ....6'TA'i'ZC Gi:::ADIENT CAHCO F'LEA£'E SIGN AND RETUF(N 'I'HE A'T'I'ACHF'D COPY A,~ RF. ZCEIF"f' OF DA"I"A~ RECE]:VIED BY i"IAVIE A NICE DAY! ;"'::AL. LY HOF'F['rCK r..i:R DISTRIBUTION AF'F:'ROVE:D ~ .... I'RAN,S':~- 90' S CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON HARATHON' '" MOBIL F' H :[ L L I F' 5' F'B WE:L_i_ FILES F;: & D BF'X ~'r A T [: 0 F' "f' Iii: X A C 0 Ai_A,~'K A ARCO Alaska, Inc. ~ Prudhoe Bay ,_,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 5, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: ~Approval No. 7-874 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 13-9)W1-3 WELLS2/29 ARCO Alaska, ~nc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ' STATE OF ALASKA I~." ALAS ,. OIL AND GAS CONSERVATION COM ._,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Alter Casing ] Other Stimulate .~ Plugging '-_-: Perforate - Pull tubing 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchoras;e, AK 99510 4. Location of well at surface 1290' FSL, 155' FWL, Sec. 13, T10N, R14E, UM At top of productive interval 2478' FSL, 2797' FWL, Sec. 24, T10N, R14E, UM At effective depth At total depth 2180' FSL, 2900' FWL, Sec. 24, T10N, R14E, UM 5. Datum elevation (DF or KB) 78' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 13-9i Feet 8. Approval number 7-874 9. APl number 5O-- 029-2067 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 80' Surface 2424' 11420 feet 9613 feet 11278 feet 9487 feet Size 20" 13-3/8" Production 1.0571 ' 9-5/8" Liner 1158 ' 7" Plugs (measured) Junk (measured) Cemented Measured depth 300 Sx Permafrost 2400 Sx Fondu 400 Sx Permafrost C 500 Sx Class G Cmt 390 Sx Class G Cmt ~ue Verticaldepth 80' 80' 2424' 2420' 10571' 8860' 11408' 9602' Perforation depth: measured 10742-10762'; 10772-10792' true vertical ; 10784-10788' 9011-9029'; 9038-9056'; 9049-9052' Tubing (size, grade and measured depth) 52" 17f~ L-80 @ 10164' 2 , Packers and SSSV (type and measured depth) BOT packer @ 10154'; Otis RQY SSSV @ 2033' 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Representative Daily Average Production or(Lnje~ct..!on' Da~'~. OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3370 590 Subsequent to operation 4990 586 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¢'~~~~ Title ~~, Form 10-,404 Rev. 12-1-85 ~ELLS/29 T. P. Allen, 263-4837 Submit in Duplicate DRILL SITE 13-9i (WATER INJECTOR) DESCRIPTION OF WORK PERFORMED Treatment: Selective mud acid stimulation Date: 1/2/88 Zone Treated: 4 1. Performed fill clean-out to 10800' MD. 2. Placed well back on injection and obtained injection capacity. Bo Rigged up pump truck and transports. Loaded acid transports. Tested acid concentration and iron content. Dispersed acid with 10% by volume of xylene. 4. Roll all acid compartments on transports. 5. Pumped the following fluids down the tubing: a. 2000 gals of 15% HC1 dispersed with 10% xylene b. 2000 gals of 12% HC1-3% HF dispersed with 10% xylene c. 2000 gals of 2% NH~CI~, water d. 750 gals of 2% NH~i water gelled with CMHEC and 750 lbs of benzoic acid flakes e. 2000 gals of 15% HC1 dispersed with 10% xylene f. 2100 gals of 12% HC1-3% HF dispersed with 10% xylene g. 2060 gals of 2% NH,C1 water h. 1000 gals of methanol 6. The well was placed on injection immediately. 7. Rigged down and released equipment. WELLS2/29 ARCO ALASKA, INC. 1 P,O, BOX t00~60 ANCHORAGE, AL.A£KA 995t0 DATE' REFERENCE' ARCO CASED HOLE FINAl... 2-7-88 2-4-88 NO T. ,~E/TEMF'-.~I IR'VFY SPINNER/IN...IECTION PROFII_F RIIN ?: ..5' RI.IN ~, 5' HAVE A NICE DAY! PEGGY BENNETT ATO-~529 F'L. EA~E ,~IGN AND RETURN THE ATTACHEI) CrIF'Y A.~ RECEIPT OF DATA., ~'~,',~ka 0il & ~:as Cons. Commis-Z,.::; TRAN$ ~88897 APPROVED DI~TRIBI. ITION CENTRAl_ FII...E~ CHEVRON ' D&M " EXTENSION EXPLORATION EXXON MARATHON MOBIl_ *,,- PHIl_LIPS F'B WELl... FII..E,? R & D '" ,,.~AF'C · ~,. . , . ) -.,.., .~.. ,.~.~,,.,;..., ~..~:..,,:.).:$TATE ' OF Al_ASK A ~-~' TEXACO ARCO Alaska, In( Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-9 Permit No. 81-158 Dear Mr. Chatterton: Attached is the Application for Sundry Approval performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp Attachment cc: standard Alaska Production Company J. Gruber, AT0-1478 P1 (DS 13-9)W1-3 detailing work to be RECEIVED NOV o 9 ]987 0il & Gas Cons. Anchorage WELLS2/29 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany AR3B--6132-C STATE Of ALASKA ALi,, .,A OIL AND GAS CONSERVATION CO~ IISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon .q Suspend 2; Operation Shutdown ~ Re-enter suspended well .22_. Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [~"'Pull tubing ~ Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 78' RKB feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 1290' FSL, 155' YWL, Sec. At top of productive interval 2478' FSL, 2797' FWL, Sec. At effective depth 13, T10N, R14E, UM 24, T10N, R14E, UM Attotaldepth 2180' FSL, 2900' FWL, Sec. 24, T10N, R14E, UM 7. Well number 13-9 8. Permit number 81-158 9. APl number 50-- 029-.296-7-~$ 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 11420 feet true vertical 9613 feet Effective depth: measured 11278 feet true vertical 9487 feet Casing Length Size Structural 80' 20" Surface 2424' 13-3/8" Production 10571 ' 9-5/8" Liner 1158' 7" Plugs (measured) Junk (measured) Cemented Measured depth 300 Sx Permafrost 2400 Sx Fondu 400 Sx Permafrost C 500 Sx Class G Cmt 390 Sx Class G Cmt 80' 2424' 10571' 11408' ~ue Verticaldepth 80' 2420' 8860' 9602' Perforation depth: measured 10742-10762'; 10772-10792' true vertical RECEIVED 9011-9029'; 9038-9056'; 9049-9052' Tubing (size, grade and measured depth) NOV0 9 ],987 5~" 17# L-80 @ 10164' ' ~ , , Alaska Oil & Gas Cons. CommissMr~ Packers and SSSV (type and measured depth) Anch0~age BOT packer @ 10154'; Otis RQY SSSV @ 2033' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation November 1987 14. If proposal was verbally'approved Name of approver Date approved 15. I hereb..~( certify that the foregoing is true and correct to the best of my knowledge /) ~~~~ Title Operations Engineering Manager Date /¢~'~ Signed Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI / W V/~.... ......... /~¢~~ by or der of Approved by "~' ~r'~ ' Commissioner the commission Date II/Icl 8 ~ Form 10-403 Rev 12-1-85 WELLS/29 P. V. Lantero, 263-4312 Submit in triplicat~,v Drill Site 13-9 Selective Stimulation Procedure 1. MI and RU CTU,N2 unit, and pump trucks. , , Perform a nitirified FCC below 10800' MD. FCC fluid should be a gelled water and all returned fluids should be pumped into a white elephant. H2S concentrations should be monitored throughout the FCC and the subsequent mud acid treatment. If hydrogen sulfide levels reach high levels, bleach should be added to the white elephant. RD and release CTU, pump truck and transports. Immediately following the FCC, put the well back on injection and obtain injection data overnight. 4. MI and RI transports and pump trucks. 5. Load 4000 gals of 15% HCI and 4000 gals of 12% HCI-3% HF acid. 6. Roll all acid compartments before pumping fluids downhole. 7. Pump the following fluids down the tubing: A. 2000 gals of 15% HCI dispersed with 10% xylene w/additives B. 2000 gals of 12% HCI-3% HF dispersed with 10% xylene w/additives C. 2000 gals of 2% NH4CI water w/additives D. 750 gals of 2% NH4CI water gelled to a viscosity of 100 cp with CMHEC and 750 lbs. of benzoic acid flakes. E. 2000 gals of 15% HCI dispersed with 10% xylene w/additives F. 2000 gals of 12% HCI-3 % HF dispersed with 10% xylene w/additives G 2500 gals of 2% NH4CI water w/additives I. 1000 gals of methanol 8. Put well back on injection immediately following the treatment. 9. RD and release pump truck and transports. RECEIVEO NOV o 9 ].987 Oil & Gas Cons. Commiss!0~'~ Anchorage '/ 5 4 2 1.5000 PSI 7" WeLL,DO GO~N[G~OIt 2.~ PSI 4 1/le~" PIPE IUdld$ 3.5OOO P.S~ 4 ~/a" t.n'DIUJ.;LtC: SUPS $. S000 PSI ~ 1/6" BLIND ItJAI$ 6. 5000 PSI 4 1/16" STUFFING BOX RE,CEIYED NOV o .~ ]987 Oil & Gas Cons. Commiss[~i.~i A~chorage COILEO TUSIN~ UNIT 8CIP E(XIIPME, NT I II ..-.~f data. T:, :_Z £ T F.: 13 U T £ ('-~ t-; ARCO Alaska, Inc P.O. Box t04)360 Anchorage, Alaska 995 ~ e DATE: March t t, t986 REFERENCE' ARCO Cased Hole Final DS t3-4 8-29-85 Prod. Logging Svc. Run t 5" DS t3-6 2-~6-86 Spinner Survey 5" DS t3-9 t2-t0-84 Engr. F'rod Logging Run ~ 5' D~ ~ 3-25 ~-22-86 ~p inner Run ~ 5' D~ ~ 3-25 ~-38-86 ~p inner 5" D~ ~3-30 ~-~5-86 CoL[ar and Perf. Run ~ 5" D~ ~4-7 ~8-3t-85 F'DK tQQ GR-CCL Run D~ ~5-~7 ~2-~9-85 CNL Mu[fi-~mce Ru,a D~ t5-t7 t8-~9-85 Epilog LAC Run F'lea~e ~ign and return the affached copy ax receip~ of dafa. HAVE I Irma C~r L i~n ~'-~-..:. :-. ~ AlO-t 429F ~ ......... TRAN~ ~86t98 DISTRIBUTION Centra I F Chew-on PB Wel D & M R &D Exten~ i on Exp Lorat io~ ~ Sohio Exxon Marathon ~ Texaco Mob i ~ DA DA $c h Camco Oti~ Go DA DA DA ARCO Alaska, I( Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, 1984 Reference: ARCO Cased Hole Finals f. D.S. 3-4j 6-24-84 D.S. 6-9 6-13-84 D.S. 11-1 ..... 6-15-84 D.S. 13-9 / 6-21-84 CCL/Perf Log Diff, Temp CH CNL CCL/Perf Log Run 1 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" GO e sign and return the attached copy as receipt of Kelly McFarland ATO-1429F Trans. 9284 DISTRIBUTION CheVron D&M Drilling Exp. Services Ex.t.. ExPloration Exxon Getty Marathon Phillips Prudhoe Bay Well Files R&D Carolyn Smith Sohio State of Alaska Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 July 9, 1984 Reference': ARCO Cased Hole Finals D.S. 3-12 5-27-84 D.S. 6-14 6-13-84 D.S. 13-9 5-18-84 D.S. 17-2 5-23-84 Collar/Perf Log CPL/TDT-M w/listing PLS/Tracer & Diff Temp Collar/Perf Log Run 1 5" GO 5" Sch Run 1 5" DA Run 1 5" GO sign and return the attached copy as receipt of data. Have a Nice Day! Kelly McFar land ATO- 1429F Trans. #247. DISTRIBUTION ~hevron ~ Mobil D & M Mobil E & P Drilling Phillips Exp. Services. Prudhoe Bay Well Files Ext. Exploration Exxon Carolyn Smith Catty. .$oh£o 'Marathon: State of Alaska ARCO Alaska, Inc{'" Prudh°e B~J:~ _ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 424S Donald F. Scheve Regional Operations Engineer February 29, 1984 Mr. C. V. Chatterton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 13-6 Permit No. 81-121 DS 13-9 Permit No. 81-158 DS 13-15 Permit No. 82-157 DS 13-16 Permit No. 82-148 DS 13-17 Permit No. 82-26 DS 13-18 Permit No. 82-35 DS 13-19 Permit No. 81-180 DS 13-20 Permit No. 82-9 DS 13-21 Permit No. 82-53 DS 13-22 Permit No. 82-77 DS 13-23A Permit No. 82-23 DS 13-24 Permit No. 82-65 DS 13-25 Permit No. 82-91 DS 13-32 Permit No. 82-123 In 1983, several Prudhoe Bay Unit producing wells were converted to injection as part of the Flow Station 3 Injection Project. By review of our records, we have found that intent sundry notices for these conversions were submitted, but no subsequent sundry notices were filed to confirm the conversions. Attached are subsequent sundry notices which provide formal notification of the completed injection well conversions. The dates of the first injection included for each well correspond with data previously submitted in the semiannual progress reports for the Flow Station 3 Injection Project. Very truly yours, D. F. Scheve DFS/RSS/STATE/lmi cc: Sohio Petroleum Company File 100.0 ARCO Alaska2, Inc, iS a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKa' ,ILAND GAS CONSERVATION C~' ~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [iIX× OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-158 / 3. Address 8. APl Number P.O. BOX 360, Anchorage, Alaska 99510 50- 029-20671 4. Location of Well 1290' FSL, 155' FWL, Sec. 13, T10N, R14E, OM (surf) 2478' FSL, 2797' FWL, Sec. 24, T10N, R14E, UM (top producin( 2180' FSL, 2900' FWL, Sec. 24, T10N, R14E, UM (TD) 5. Elevationinfeet(indicateKB, DF, etc.) 78' RKB 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number ~) D.S. 13-9 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION 'TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing St'imulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted DS 13-9 to a Water-Alternating-Gas Injection well. Injection has not yet been initiated. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 2 .~'/',~_-f~/~l--~~ Title Regional Engineer The space below for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date .................................... Form 10-403 Rev. 7-I-80 Submit "Intentions" in Triplicate and "Subsequent Reports" ir] Duplicate ARCO Alaska, Inc. ~, Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 29, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr' Chatterton' DS 13-6 Permit No. 81-12i ]!iDSi'l~:3-9 Permit No. 81-158 DS 13-19 Permit No. 81-180 DS 13-21 Permit No. 82-53 DS 13-24 Permit No. 82,65 DS 14-13 Permit No. 81-101 DS 14-14 Permit No. 81-102 Enclosed are the .Completion Reports for Work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lw Enclosures cc' SOhio Petroleum Co. A~aska Oil & Gas Cons. Anchorage · STATE OF ALASKA ~ ~,. ALASKA~ ,_AND GAS CONSERVATION C . ,VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICEX~X NAG Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-158 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 5o-029-20671 4. Location of well at surface 9. Unit or Lease Name 1290' FSL, 155' FWL, Sec. 13, TION, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2478' FSL, 2797' FWL, Sec. 24, TION, R14E, UM U.S. 13-9 At Total Depth 1 1, Field and Pool 2180' FSL, 2900' FWL, Sec. 24. TION. R14E. UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) t5. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 78' RKB ADL 28315 12' Date Spudded10/30/81 13. Date T.D, Reached 11/14/81 14' Date C°mpv Susp' °r Aband' I 15' Water Depth' if °ffsh°re I 16' N°' °f C°mpleti°ns ll/19/81 N/A feet MSL l 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11420'MD,9613'TVD 11278'MD,9487'TV )YES,i] NOl-1. 2033 feetMD 1800' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL/GR, CET, CCL/Temp.., Tracer-Temp. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE'WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 80' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surf 2424' 17-1/2" 2400 sx Fondu'& 400 .<;x Permafrost C 9-5/8" 47# L-80 ~ Surf 10571' 12-1/4" 50'0 sx Class G cmt S00-95 .... 7" 29# L-80 10250' 11408' 8-1/2" 390 sx Class G cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) pACKER SET (MD) ~_l/~,, !0268' 10154' 10772-10792' MD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9038-9056' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Ref' BHCS 11/13/81 10851 '-10855' lllO sx Cl'a.~s G . ~ 10832'-10836' 150 sx Class G lflR?7'-lflg31' lflfl ~ C. la~ g , 27 ..... PRODUCTION TEST Date First ProdUction I Method of Operation (Flowing, gas lift, etc.) WAG Inje<'torI N/A, ,,., Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE IGAS-01LRATIO N/A TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-EEL GAS-MCF WATER-EEL OIL GRAvITy-Apl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips. and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS NAME MEAS. DEPTH Top Sadlerochit 10735' 0/W Contact 10837' Base Sadlerochit 11362' 31, LIST OF ATTACHMENTS FORMATION TESTS TRUE VERT. DEPTH 9005' 9095' 9562' Include interval tested, pressure data, ali fluids recovered arid gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ..... Title Engineer __ 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 '[he 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 rnultiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Wa'ter In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 'ARCO Alaska, Inc._~" Post Office E, 60 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1983 Mr. C. V. Chatterton Commi ssi oner State of Al~iska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for February on these drill sites' 1-25 1E-18 7-20 1E-19 7-21 1G-5 12-15 1G-6 12-16 1Y-12 12-17 1Y-13 13-2A 1Y-14 15-3. 1Y-15 CIRI Wolf Lake Well #1 Ravik State #1 A1 so enclosed are well completion reports for' 1-24 ' 1E-21 2-8 . 1E-22 7-18 1F-1 7-19 1G-7 12-18 WSW-iO 13-9 WSW-11 1E-20 Tract Well 24-11-14 We also 'are including subsequent Sundry Reports for 2-8, 7-18, 12-18, and 13-9. ARCO Alaska, Inc. Is a subsidiary ol AllanticRIchfieldCompany _ ' . STATE OF ALASKA ALASKA,~'~ . AND GAS CONSERVATION C(~ ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~}X WAG Injector . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-158 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20671 4. Location of well at surface 9. Unit or Lease Name 1290' FSL, 155' FWL, Sec. 13, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2478' FSL, 2797' FWL, Sec. 24, T10N, R14E, UN 13-9 At Total Depth 11. Field and Pool 2180' FSL, 2900' FWL, Sec. 24, T10N, R14E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Prudhoe Bay 0i l Pool 78' RKBI ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 10/30/81 11/14/81 11/19/81I N/A feet MSL 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I 21.Thickness of Permafrost 11420'MD,9613'TVD 11278'MD,9487'TVD YES [] NO [] 2033 feet MD 1800' (Approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL/GR, CET, CCL/Temp., Tracer-Temp. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 80' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surf 2424' 17-1/2" 2400 sx Fondu & 400 sx Permafrost C 9-5/8" 47# L-80 & Surf 10571' 12-1/4" 500 sx Class G cmt S00-95 7" 29# L-80 10250' 11408' 8-1/2" 390 sx Class G cmt 24. Perforations open to Production (MD+TVD of Top and BottOm and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A 5-1/2" 10268 ' 10154 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 10851"-10855' 100 sx Class G 10832'-10836' 150 sx Class G ' 10827'-10831' 100 sx Class G 27. N/A PRODUCTION TEST ......... Date First Production J Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OIL RATIO TEST PERIOD , Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. '"~ i7~' '"~' ii~:.~ :',;' ~ '~' None · ~'~R 1 5 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GRU2/WC10 29. 30. GEOLOGIC MARKERS NAME Top Sadlerochit O/W Contact Base Sadlerochit MEAS. DEPTH 10735' 10837' 11362' 31. LIST OF ATTACHMENTS FORMATION TESTS TRUE VERT. DEPTH 9005' 9095' 9562' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best o'f my knowledge Si§ned .... Title ^rea Drilling [ngr. 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' IVlethod o'f 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 13-9 WORKOVER HISTORY Accepted rig @ 1600 hrs, 01/18/83. Pulled BPV. Circ. diesel cap off ann & rev. circ. bottoms up. Set BPV. ND tree. NU BOPE & tstd - ok. Unseat hgr. Pulled tubing. Tagged PBR @ 10179' DPM; rotated out K-anchor. Pumped 90 bbls Bridgesal pill w/lO ppg spacer in front & back; bullheaded 20 bbls to top of perfs. POH w/K-anchor. Tagged pkr @ 10197' DPM & milled on it. POH w/pkr & 4-1/2" tailpipe. Ran CET f/11234'-10160' (showed cmt "void" f/10742'-10900'). Perf'd 10851'-10855' w/4 spf. Set EZ drill cmt ret. @ 10830'. Stabbed into cmt retainer; pumped 10 bbls H20, & 100 ..... sx Class G cmt. Unsting from retainer & POH. Ran CET log. Drld cmt retainer. Washed to 11000'. Ran CET log f/ 11150'-10200". Perf'd 10832'-10836' w/4 spf. Set EZ Drill @ 10820'. Pumped 150 sx Class G cmt. Drld cmt & retainer. Ran CBL f/11004'-10595'. Perf'd 10788'-10792' w/4 spf. Ran static temp. log f/10200'-11011'. Ran Dynamic temp. log f/10200'-11011'. Perf'd 10827'-10831' w/4 spf. Set EZ Drill retainer @ 10815'. Pumped 100 sx Class G - squeezed. Tstd csg & perfs. Drld retainer and cmt. Perf'd ~Q7841..-10788_' w/4 spf. Ran CCL/temp. log f/10200'-11000'. Ran CBL -- f/10300'-11000'. Ran Tracer-temp. log. Set EZSV @ 10820'. TIH; tagged EZSV bridge plug @ 10827' (DPM). Disp well with clean brine. Ran 5-1/2" completion assy w/tail @ 10268' and pkr @ 10154'. Nipple for SSSV @ 2033'. Tstd packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi. Dropped ball & set packer. Disp tbg to diesel and backflowed 30 bbls into annulus. Set SSSV and tstd - ok. Closed SSSV. Secured well and released rig @ 2400 hrs, 02/05/83. GRU2/WH2 ARCO Alaska, Inc. {~ Post Office B~ ,60 Anchorage, Alaska 99510 TelePhone 907 277 5637 March 15, 1983 Mr. C. V. Chatterton Commissioner State of A16ska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for February on these drill sites' 1-25 1E-18 7-20 1E-19 7-21 1G-5 12-15 1G-6 12-16 1Y-12 12-17 1¥-13 13-2A 1Y-14 15-3 1Y-15 CIRI Wolf Lake Well Ravik State #1 #1 Also enclosed are we ll completion reports for: 1-24 1E-21 2-8 . 1E-22 7-18 1F-1 7-19 1G-7 12-18 WSW-IO 13-9 WSW-11 1E-20 Tract Well 24-11-14 We also are including subsequent Sundry Reports for 2-8, 7-18, 12-18, and 13-9. ARCO Alaska, Inc. Is a subsidiary of AllantlcRichfieldCompany STATE OF ALASKA '~ ALASKA ,L AND GAS CONSERVATION CO,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IZ]X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-158 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20671 4. Location of Well Surface: 1290' FSL, 155' FWL,'Sec. 13, T10N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 67 ' RKB 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-9 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon []. Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made ~[ Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached Workover History. 14. I hereby cer~fy that the foregoing is true an~d correct to the best of my knowledge. Signed ~~ The space below for Commission use Title Area Dri 1 1 ing Engineer Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU2/SN7 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc, ill Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 March 11, 1983 Reference: Arco Cased Hole Finals D.S. 1-24 ~'1-19-83 EPL 1-18-83 CBL/VD D.S. 1-25j 2-13-83 CBL/VD ~,_~D.S.i~/ 2-17 -- 11-27-82 CNL/GR/MSN %1~ D.S. 2-20' 1-27-83 Perforating Record D.S. 3-15~ 12-9-82 CNL/GR/MSN --~-D.S. 6-11 11-29-82 CNL/GR/MSN D.S. 12-12' 2223-83 Temperature Survey D.S. 12-17'-1-28-83 Temperature Log D.S.~ 13-2A~'2-7-83 CBL/VD 1-29-83 ~Tubing Puncher Record D.S. 13-9/ 1-24-83 CEL 1-~.7-83 1-30-83 1-?-83 2-3-83 1-28-83 1-28-83 CET CBL/VDL & Waveforms Temperature Log EPL CCL & Perf Record CET D.S. 14-15,/ 12-15-82' CNL/GR/MSN D.S.. 16-13~/12-10/11-82 CNL/GR/MSN Run 1 2" & 5" Sc Run 1 5" Sch Run 1 5" Sch Run 2 5" DA Run 1 5" Sch Run 2 5" DA Run 2 5" DA Run 1 5" Camco Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch Run 1 5" S c h Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch Run 3 5" Sch Run 2 5" DA Run 2 5" DA P~~lease sign and return the attached copy as receipt of data. ~Kelly McFarland AFA-403 Trans. 9 207 NORTH GEOLOGY R & D' DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION EX'XON MOB I L GETTy D & M STATE' OF ALAS~ DALLAS ARCO Alaska, Inc Post Office BI' 60 Anchorage.~ ,a 99510 Telephone 907 277 5637 February 23, Reference: 1983 Arco Cased Hole Finals D.S. 7-15 D.S. 13-9 D. S. 13-13 11-14-82 Run 1 ACBL/VDL/Signature "2-2-83 CBL Run 1 2-1-83 Temperature Log Run 1 11-28-82 ACBL/VDL/Signature Run 1 1! 1! !! DA GO GO DA Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 159 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D & M .,,'v S TAT ~~AL-~'~ ~.~~//~,· .=.. -_.~ CAROL I NE ASM~ A~':thora~e ,, A,"~ C O Alaska, Post Office, ., 360 Anchorage, Alaska 99510 .Telephone 907 277 5637 February 10, 1983 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s's i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for January on these drill sites' 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-iO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well. #1 Ravik State #1 AlSo enclosed are well completion reports for: 2-11 1E-23 7-17 1F-2 12-19 1F-3 13-11 1G-8 13-21 WSW-8 13-24 WSW-9 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey, is received. We also are including subsequent Sundry Reports for 1-24A, 2-11, 13-21 (3 reports), and 13-24. ARco Alaska. Inc. is a subsidiary o! AtlanlicRichlieldCornp~ny STATE OF ALASKA , · ALASKA(' C AND GAS CONSERVATION C(~' ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation :~] Name of operator 7. Permit No. ARCO Alaska, Inc. 81-158 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 5o-029-20671 4. Location of Well at surface 1290' FSL, 155' FWL, Sec. 13, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 67' RKB 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 13-9 11. Field and Pool Prudhoe Bay Field Prl!dhne Bay ~li! Pool For the Month of January ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig @ 1600 hfs, 01/18/83. Pulled tbg. Rotated out K-anchor. Pumped pill. Milled on & recovered pkr w/4-1/2" tai]pipe. Ran log. Squeezed cmt (3' times). Testing csg & perfs as of 01/31/83. SEE WORKOVER HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run CET f/11,234'-10,160' CET f/11,150'-10,200' Temp log f/10,200'-11,011' CBL f/11004'-10595' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED~~ TITLE Area Drilling Engineer NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 Submit in duplicate Rev. 7-1-80 13-9 WORKOVER HISTORY Accepted rig @ 1600 hrs, 01/18/83. Pulled BPV. Circ. diesel cap off ann & rev. circ. bottoms up. Set BPV. ND tree. NU BOPE & tstd - ok. Unseat hgr. Pulled tubing. Tagged PBR @ 10179' DPM; rotated out K-anchor. Pumped 90 bbls Bridgesal pill w/lO ppg spacer in front & back; bullheaded 20 bbls to top of perfs. POH w/K-anchor. Tagged pkr @ 10197' DPM & milled on it. POH w/pkr & 4-1/2" tailpipe. Ran CET f/11234'-10160' (showed cmt "void" f/10742'-10900'). Perf'd 10851'-10855' w/4 spf. Set EZ drill cmt ret. @ 10830'. Stabbed into cmt retainer; pumped 10 bbls H20, & I0~ $× Class G cmt. Unsting from retainer & POH. Ran CET log. Drld cmt retainer. Washed to 11000'. Ran CET log f/ 11150'-10200'. Perf'd 10832'-10836' w/4 spf. Set EZ Drill @ 10820'. pumped 150 sx Class G cmt. Drld cmt & retainer. Ran CBL f/11004'-10595'. Perf'd 10788'-10792' w/4 spf. Ran static temp. log f/10200'-11011'. Ran Dynamic temp. log f/10200'-11011'. Perf'd 10827'-10831' w/4 spf. Set EZ Drill retainer @ 10815'. Pumped 100 sx Class G - squeezed. Testing csg & perfs as of 01/31/83. GRU2/WH2 AJast(~ Oil'& Gas Co~s, Comm~'ssi'or, ARCO Alaska, Inc.~q Post Office I~ J60 Anchorage. Alaska 99510 Telephone 907 277 5637 January 31, 1983 Reference: Arco Cased Hole Finals D.S. 13-9L .... 11-21-82 PLS/Diff Temp D.S. 13-24~''' 1-7-83 PLS/Temperature · D,s. 15-12~ 11-27-82 PLS/Production D.S. 15-15~,,~''' 11-25-82 PLS/Production Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 1 5" DA P/lease sign and return the attaChed copy as receipt of data. Kelly McFarland AFA-403 Trans. ~ 103 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M , ~k~,?,- ,'"' ~zT,,' ', '1', ~-~.~ ,. ~, A~.~.~, ...... ,,.,.~,: ~ ~ .~ Al~Sk~ O[t & G2s Go~s. Gommissien ARCO Alaska. Inc. is a Subslciiary of AtlanticRichfieldComDan,,, ARCO Alaska, Inc. ~ Post Office B~'~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 7, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 13-9 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose repairing the well to reduce the production of water. Since we estimate starting this work on January 21, 1983, your prompt approval will be appreciated. Sincerely, ., ~.....~ ? ,./',~ .:..:~n/< .:/ / ,>,~ ..- M. A. Major Area Drilling Engineer MAM/JG' 1 lm Enclosures GRU1/L25 3 AN 0 7 19B3 A~Sk~ Oit & G~s Cons. ccmmission A~ch0~age ARCO Alaska, Inc. is a subsidiary o! AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-158 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20671 4. Location of Well Surface: 1290' FSL & 155' FWL, Sec. 13, T10N, R14E, UN Bottom Hole: 2180' FSL & 2900' FWL, Sec. 24, TION, R14E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 13-9 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 67' RKB I ADL 28315 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [~)( Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-I 70). ARCO Alaska, Inc. proposes to repair this well to reduce the production of water. The 5-1/2" completion string will be pulled, the packer milled and the water channel cement squeezed. The well will be recompleted with the original 5-1/2" plastic-coated tubing and the necessary provisions for subsurface safety equipment. A 13-5/8", 5000 psi, RSRRA BOP stack will be used on well work performed by the workover rig. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon completion of the job. Approximate start date: January 21, 1983 Subsequent Work Bepmied o~ Foz~ No,/~- ff ~3 Dated ......... / J AN 0 '7 1983 Alaska 0il & Gas Cons. O0mrnissi0n Anchorage 14. I hereby cec.tify that th~foregoing is true and correct to the best of my knowledge. '"~ .... ~;' ~' y' .... Area Dri l 1 ing Engi neet Signed ~-~. ,,, "..~;/ ' Title The space below for Commission use Date Conditions of Approval, if any: ORiG;~IAL SIGNED BY LONNIE C. SMITlt Approved by. COMMISSIONER Approved Copy Returned ,,/,- By Order of the Commission Date Form 10-403 Rev. 7-1-80 (:RU1/SN12 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay E'[, .veering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: D.S. 13-9 D.S. 13-21 Permit No. 81-158 Permit No. 82-53 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, DFS/TKKW/lmi Attachments cc: Sohio Petroleum RECEIVED DEC2 9 Alaska 0il & Gas Cons. C0mmissioD Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanllcRIchfleldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []XX OTHER [] a. ~(~ ~aska, Inc. 81-158 Na f p r tor. 7. Permit No. 8. APl Number 3. Ad~)re.s~). BOX 360, Anchorage, Alaska 99510 50- 029-20671 4. Location of Well 1290' FSL, 155' FWL, Sec. 13, TION, R14E, UM (surf) 2478' FSL, 2797' FWL, Sec. 24, TION, R14E, UM (top producin( 2180' FSL, 2900' FWL, Sec. 24, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 78' RKB I ADL 28315 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number ) U.S. 13-9 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations F~X Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 11/20/82. RU perforating unit, pressure tested surface equipment. RIH with gun #1, shot 10772-10792' MD, 4 spf (20' Ref: CNL 11/23/81), flowed to tank for clean-up, monitored rate and took shakeouts. Samples indicated up to 76% water-cut in produced oil. A temperature log was run and indicated a channel in the cement from the perforations to the oil/water contact. Perforation operations were suspended and Well 13-9 was shut-in. 14. I hereby,,,certify that the foregoing is true and correct to the best of my knowledge. Signed ..... Title Regi onal The space below for Commission use Engineer Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date .............................. Form 10-403 Rev. 7-1-80 S~bmit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay~' 3ineering Post Office B~.. 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 22, 1982 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatte'rton: Re- D,S. 13-6 Permit No. 81-121 D.S. 13-9 Permit No. 81-158 D.S. 13-15 Permit No. 82-157 D.S..13-16 Permit No. 82-148 D.S. 13-19 Permit No. 81-180 D.S. 13-21 Permit No. 82-53 D.S. 13-22 Permit No. 82-77 D.S. 13-23A Permit No. 82-23 D,S. 13-24 Permit No. 82-65 D.S. 13-25 Permit No. 82-91 D.S. 13-32 Permit No. 82-123 Attached are "Notice of Intention" Sundry Notices work proposed on the above-mentioned wells. Very truly yours, D, F, $cheve DFS/TKKW/lmi. Attachments cc' Sohio Petroleum RE£EJVED ,Alaska Oil & Gas Cons, Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ('" STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION CO ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~X OTHER [] 2. Na o~f~Op.er_ator 7. Permit No. ~[:0 Alaska, Inc. 81-158 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50- 029-20671 4. Location of Well 1290' FSL, 155' 2478' FSL, 2797' FWL, Sec. 13, TION, R14E, UM (surf) FWL, Sec. 24, TION, R14E, UM (top producin( 2180' FSL, 2900' FWL, Sec. 24, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 78' RKB I ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 12. 10. Well Number ) D.S. 13-9 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other FX]X Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed o'r Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to convert this well to Water-Alternating-Gas Injection service. Injection will be into the. Sadlerochit; surface piping and instrumentation have been installed as necessary for injection. A downhole safety valve will remain in service in this well following the initiation of injection. A non-freezing fluid was left in all uncemented annuli within the permafrost interval. Su~sequ~t Wor~k l~eported on Form No. ~ Da~ed 5~_]~~ 14. I hereby ~,ertify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Engineer / /- Conditions of Approval, if any: Approved by, Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska', Inc '( Post Office l,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 8, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Re: D. S. 13-18- Permit No. 82-35 D. S. 13-20 - Permit No. 82-9 D. S. 13-17- Permit No. 82-26 D. S. 13-24- Permit No. 82-65 D. S. 13-25 - Permit No. 82-91 D. S. 13-9 -Permit No. 81-158 D. S. 13-21 -Permit No. 82-53 Attached are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS'MAM'mlc Attachments cc' Sohio Petroleum Co. , NOV 0 9 Alaska 0il & Gas Cons, ARCO Alaska. Inc. is a subsidi, ary of AllantlcRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-158 3. Address 8. APl Number P.O. Box 360 Anchoraqe, AK 99510 5o-029-20671 4. Location of Well 1290' FSL, 155' FWL, Sec. 2478' FSL, 2797' FW[, Sec. 2180' FSL, 2900' FWL, Sec. 13, TION, R14E, UM (Surf) 24, TION, R14E, UM (Top Producing) 24, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) RKB 78' 6. Lease Designation and Serial No. ADL 2831 5 9. Unit or Lease Name Dv,,,NI~,A ~ IIn-~+ 10. Well ~umber D.S. 1 3-9 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand in this Prudhoe Bay Unit'well. Upon perforating, the well' will be flowed to a tank for clean-up and evaluation. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at 'the conclusion of the perforating and clean-up operation. Proposed perforation intervals' 10742' - 10762' MD 10772' - 10792' MD Ref: BHCS ll-81 Sub,sequent W, or]:,~cgortecl on Form No/~~Datec~/~---/ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~ _~_,/ll~~_.~'~'~__..--~ TitleRegional Operations Engineer The space below for Commission use Date // Conditions of Approval, if any: Approved by COMMISSIONER Approved c',.':: ~, [~,e, turne, d By Order of /~/ra the Commission Date ..................................... ' Form 10-403 , Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box ~ Anchorage, Alaska 99510 Telephone 907 277 5637 SAMPLE TRANSMITTAL SHIPPED TO' STATE OF ALASKA Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anch.,Ak. 99501 Attn: William VanAlen OPERATOR' ARCO SAMPLE TYPE: Core chip samples SAMPLES SENT: 9500 - 9558 at 1' intervals 9560 -9919, at 1' intervals DATE' June 3,1982 NAME' D.S. 13-19 NUMBER OF' BOXES' 1S ARCO ALASKA, INC. P.O. BOX 360 ANCHORAGE, ALASKA 99510 ATTN' R. L. BROOKS DATE' ARCO Alaska, Inc.( Post Ofi'icet.;~x 360 Anchot'age, Al~ska 99510 Telc!)hone ,.;u, 277 5637 May 11, 1982 Mr. C.' V. Chatterton Commissioner StaLe of Alaska Alaska Oil & Gas Conservat'ion Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are revised completion reports and gyroscopic surveys for the Following wells: DS 13-6 '13-9":" DS 14-13 DS 15-11 DS 16-1 The original completion reports .indicated that certain items would be submitted at a later date. These items are now included in the attached completion reports. Sincerely, P.A. VanDusen ~/~ District Drilling Engineer PAV:JG/llm Enclosures 6RUS/AZ3 ~Jaska 0il & Gas Cons. Co~miss/ot~ AnC.horage STATE OF ALASKA ALASK. ~(' "AND GAS CONSERVATION 'l' ,ISSlO~I R I G IN A [ WELL COMPLETI .,I I OR RECOMPLETIOh, ..,:PORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-158 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20671 4. Location of well at surface 9. Unit or Lease Name 1290' FSL, 155' FWL, Sec. 13, TION, R14E, UN 1L©CATI©~SI Prudhoe Bay Unit At Top Producing Interval VERIFIED ] 10. Well Number 2478' FSL, 2797' FWL, Sec. 24, TION, R14E, UN ,Sur~. ~ -~ 13-9 At Total Depth'[B.H. E. -t 11. Field and Pool 2180' FSL, 2900' FWL, See. 24, T10N, R14E, UM' Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe 0il Pool 78' RKB ADL 28315 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 10/30/81 11/14/81 11/19/81I N/A feetMSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11420'MD,9613'TVD 11278'MD,9487'TVD YES:J~ NOr-1I 2122' feetMD 1800' (approximate) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal~ CBL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20" 94# H-40 Surf 80' 32" 300sx Permafrost 13-3/8" 72# L-80 Surf 2424' 17-1/2" 2400sx Foundu & 400 sx Rermafrost C ~-5/8" 47# L-80 & ,Surf 10571' 12-1/Zd' 500sx Class G emt 500-95 7" 29# L-80 10250' 11408' 8-1/2" 390sx Class g cmt 24. Rerforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A. 4-1/2" 10271 ' 10204' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED : N/A. .... 27. PRODUCTION TEST Date First Production Method of Operation (Flowing; gas lift, etc.) N/A. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TESTPERIOD II~ Flow Tubing Casing Pressure : CALCULATED.~ OIL:BBL GAS-MCF WATER-BBL OILGRAVITY-API (ocr"r) Press. 24-HOUR RATE 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' MAY' Form 10-407 GRU4/B28/29/30 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE. SIDE 29. GEOLOGIC MARKERS NAME Top Sadlecochit O/W Contact Base Sadlerochit MEAS. DEPTH 10735' 108)7' 11362' TRUE VERT. DEPTH 9005' 9095' 9562' 30. 31. LIST OF ATTACHMENTS G y r o s c o _p_?.._ S_u_ r___v_e_y...._.. (_ 2___c___o.p. i e s ) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge FORMATION TESTS Sig ned_~..~ Include intbrval tested, pressure data, all fluids recovered and gravity, GOR,and time of each phase. N/A. Title /~r'e¢ D_r']_g= .~::~p, 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 o'f Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO ALASKA, .I'NC, ~ .... DS"I-3¥:-WE;21Z-NO ;-'-9-G~S- 2;OB-NO'~'--'AO PRU][;HOE BAY, NORTH SI_OPE, Al. ASEA GMS, 0-10800 kiD,, SURVEYOR; D F'.FFFERKORN .DATE RUN; OAHE'RA--NO-;--3'I-Tg~-GYRO NOI ·-628 5'-"90 DEG. A/U NO; 1562 FORESIGHT ;-':N- 5,'.~ '-W ......... ; _. . . 0 · ,~ :" i~ COMF'UTATION :~I'(L;U ALASKA~ INC. ..... 98 ].J, WELL NO: 9' GMS : ' JOB NoJ AO38~G040.6 :.RUDHOE-BA yF-;--NOI:;:TH-~SI: 0 p E,--- AL,ASKA · , .. . : : . TRUE- ~EAsuREIT-DRI'F~;RI FT ...... COURSE VERTICAI:-'VERTI CAI.' .... SUBSEA ......R-"E-C:TT--A--N-G--U'L--A--R---C-L:-O-S-- [1' R DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVrl C 0 0 R D I N A: T E S DISTANCE DIRE FEET 'D M D M FEET FEET FEET" FEEl' , ': FEET :0. 0 0 0 0 O. 0.00 0.00 -78.00 0.00 100.::::; 0 : 0 0 0 100. :100,00 0,00 22.00 0.00 ---200-.':~'-0-'-0 ....... 0'---0 ............. 100;- .....200 :-00 .............. 0',' O0-: ...... 12-2; O0 .......... 0 ;-00 300.::': 0 0 0 0 ]00, ~00.00 0.00 222.00 0.00' 400.:: 0 PAGE NO. 0 0 0 100. 400.00 0.00 322.00 :: oo.:i:i: o o o o 600, :::' 0 0 0 0 -~700~70'~-0 ......... 0 ...... 0 8oo.::: o o o o 900.:::' 0 15~S 87- 0 100, 100. 100. .... ]00. 100. FEET D 0.00 ' 0.00:::i. ':~:::: 0.00 '-E CTI M o. Oo: o.oo o o 0.00 : .'" 0.00 0 0 0;00 .: 0~-00 ............. 0"0 0.00" . 0.00 0 0 0 0 0.00 r, · 0.00 O'vO0 ., 0.00 ' " . 0.22 E 500.00 0.00 422,00 0,00 ' 600,00 0,00 5'22,00 0.00 700.00 .......... 0~:00 ....... '622"~00: ....... ~'-::'0.00 800.00' '0.'00 '722.00 0.00 900.00 0.13 822.00 O.O:l. S 1000, i:0 0 0 0 1100o.!:' 0 '15 S 13 0 E .... J'200; ..... 0-I5"S'"20 .... O-E 1300. 0 30 S 14 0 E :1400o ,:'::0 30 S 11 _0 E ON :lO0,. '1000,00 ........ ¢,. 0,25 922,00 0,02 S 0,43 E :100~:!!'-:':i!-:1:100.001:~,'i~"~:::~*0;:,':4(~:;,?,:1:022~;:00::":~ 0,23 8 :'!'~::':~ 0,:48 E ]500.' 0 15 S B 0 E 100, 1499.99 2.93 1421'./99~?r?:A/v:-:2;:78~VS 1.10 E 1600. 0 15 S 19_ 0 E 100, 1599..99 3.34 15~1,~ .99 3 1700';-~,-0--15 - S ..... 2 ..... O-'E .... 100, '~6¢9~99 ............3;73 .....1621-,'99 ........... ~800, ~ O 30 S 12 0 E 4.32 ~721.99 4,29 S 1.30 E 1900. ~ ~ O' 45 S 38 0 E 5.40 1821.98 5,27 S ~,76 E :: 5.74 S 2.48 E ri SE I) G VERIT' /100F' 0.00 0.00 0.00-" 0.00 100. :1799.99 100, 1899.98 :l. O0. :1999.98 :: · 2000. ;, :0 15 S 76 0 E 6.17 :1921.98 2100.:::'-:::0:~0 S 89 , 0 E .... ...... o ........ 2300.:: 0 30 S 46 0 E 2400.!::::i0:45 S 34 0 E 100, 2~99.96 ?°70 2500':~::1::-;4:45 N 72 0 E 100, 2499,82 13,19 2421,82 2600, 8 0 N 74 0 E 100. 2599,19 16.11 2521,17' ~ Y 0~9-'1-5- S-Y 6-~-0 -- E ..... 100 · ..... 26~8 ;-06 ........2D~- 80 2620 :-06 2800, hi::10'15 $ 42 0 E :lO0. 27'9'6,61 38,70 2718,61 1.5 8 52.:_: .0 E 100. 2894.68 57.54 2816.68 0.00 0,00 0 0 0,00 0 0 0;00 ............. 0 .... 0 0,00 0 0 0,22 S 87 0 E 6.43 0.54 S 64 6 E: 0 ~-89 .... S --4~,.. o,~'~ E 1.51 S 31 58 E: 2.35 S 24 5] E 2.99 S 2:l 3] E :3.41 S ':-20 3 E -:-'--3-i-84 .... S .... 18' 35 E i 4,48 ' S 16 54 E 5.56 S 1El 29 E 6.25 S 23 23 100. 2099.97 6.59 202i,9'7 5.82 $ :: 3,13 E ' ' '6.61 S 28 1~ 100~ 2199'~77 ................. 7'~'~4 ..... 212I'~97 ................... 6'~-42:'8 ...... :"~";~'~'98"':E'''~'~ ...... 7'~'54 ....... B' 31'38 100. 2299.96 8.62 2221.96 7.33 S 4.54 E 8.62S 31. 44 , 8,17 S 5,24 E ..9,70 S 32 40 . 9,62 S 9.46:E 13.50 S 44 31 6.38 S 20.08 E 21.07 S 79~ ~°3 6"~--~2- 8--~34w90 - EZ-------35-r43----8'- 80 .... S 73 21 $ 66 11 ._ E E E E: E . E E E" E E .. 0.00'-- 0. O0 0.25 0.25 O. OZy-' O. 25 0,03 ........... 14.71 S 28.00 S 0,02 0,04 0.26· 0.37 0,~7 0,26 ~ '7~ 0.38 0.28 4.60 3.26 4i'61 5,76 .............. 49.21 IE:: . 63,46 51,36 '69,36 OS 13, WELL NO; 9 GHS ¢'RUDHOE--BAY'~-NORTH~ SLOPE',-- ALASKA JOB NO: A038280406 ~ COMF'UIAI'I UN PAGE T I ME DATE '-14. O,-.. ,.. 3'" ~'--~',,3 ~- MA sP'" 8~.'~ ........ flEASURED-'DRIFT~ ...... DR-IFT ........ COURSE DEPTH ANGLE DIRECTION LENGTH FEET" D H' D- M FEEl' FEET 3000, 15 45 S 50 0 E 3100,: 19 0 S 47 0 E ~ 200 ~-22-~ 0--S--4-3 ----O---E .... 3300, 25 15 S 37 0 E 3400, !: 27 45 S :S~ 0 E : :3500, 31 45 S :34 0 E , ~600, 35 45 S 34 0 E ..... ~700 ~----S 9--15----S---:~ 4 ...... O- E .... 3800. 40 0 S 34 0 E 3900,' 40 1.5 S ~;4 ' 0 E : 4000,: 41 ~0 $ 33 0 E 4100,: 40 15 S ~4 0 E -' 4200--~-~40-~ 15- S ~ -'-0 E 4300, 40 0 S ;'~4 0 E 4400, 40 O,S 33.4 0 E 4500,~ ':'.40 : 0 S 34 0 E 4600, 40 0 S 34 0 E ..... 4700-r---40-:1.5- S-' '34 .... 0 - E .... 4800, 40 15 S :34 0 E .: 4900. 40 0 S 34 0 E : 5000, 40 0 S ~4 0 E ~' ' 40 15 S 34 0 E .,100. --5200~ -40-:1'o---.-'-34 ..... O-"E' 5:300, 40 30 S ~2 0 E 5400°": : 40 45 S 32 0 E :~ · I'RUE VERTICAI.-VERTICAI.: .... SUBSEA .... R- E='C--T-A-N--G-U-L--A-R ....... C-L:'-O-'8"U R E DI::-F'TH SECTION TVD C 0 0 R D I N A l' E S DISTANCE DIRECTI 5500, 41. 15 S 32 0 E 100, 4984,~.~ 1557,18 4906,31 1.~6~,27 $ 917,59 E ~1560,54 S 5600, '.41' 45 S 3~ 0 E 100, 5059,20 162~,44 4981,20' 1~18,15 :---5700'i-~42---0-S--33- ~-0- E ........ 100 ~ 51 S3-v66 ....... 1-690-i-18 ..... 5055 ,-66 .....j 374-~-i-S-8-~-989~'55 '-E~1-69B"~-~6 ..... S' 5800,~::~: 42 15 S 3~ 0 E 100 52'07,8~ ]757 25 -J 9 8~ 1470,~9 S J026,08 E 1760,35 S 5900'~'::42:'g0:8:~3 0 E 100, 5281~71 1824,64 5203,71 1486~91 8 1062,7~ E 1827~68 ~ . . . . oo S 82,25 E 92,92 S JO0. 299J,70 80,45 2913,70 100, ~087,J2 109,11 3009,i2 63,00 S 104,61'E 122,12 S ~6.",'--31 ~'62 ......... 88"~-05'-S ....... t'29-'~-66'-E ...... --~56'~'7~ ....S JO0+' -~180,'62 .... 143 S 02 ~.00, lO0, ~00. 100, 1OO,-- ~00. 100. ~272,05 183,73 3194,05 lJ9004 S 155,66 E 195,96 S ~361,54 228,29 :3283,54 155,58 S 18:1 ,24.E 2~8.86 S : _. ~448,~4 277,89 3~70,~4 196,95 S 208,63 E 286,90 S 46 ~5~1,47 ~,41 ~45~,47 24~,00 S ' 2~9,69 E 34~,~2 S 44 ~687,82 '4'57,99 - ~609,82 ~46,~7 S ~09,~9 E 464,~9 S 41 ~764,28 522.41 3686.28 ~99,76 S 345,42 E '. 528,~2 S 40 .100, 38.39 90 ...... - ..... 587,8:3 3761,90 454,3;.¢ S ,-f8],..,4 E 100. ..~91o.~1::::..,:~ 6~,~::~..~6...~-:_:~.83·7,.~ !::<-,::: ,~08,89 S: .: ,-4:1.7.66 E 100' :4()68,;~0 782 ,.28 :.? ~9.90 , 30 ~..616,51r-?S N88~89 E 100, 4221,51 910.78 414~,/51/?O/A/Z23v. O~NS 560,78 E 100. 4298.1J 975.03 4220.11 776,;~8 S 596,72 E 100, 100. 100, 9]5.06 S 979.21 S 4~74,58 :10:39,45 .... 4296'~58 .... 829"~-81-"S .......632~'76-E'--104:3~,4 .... S 4450,90 1104,0~ 4372,90 883,:38 S 668,89 E ].108,05' S · ..,.7.S6 1168.44 4449 ~6 9:36.81 S 704.9~ E 1172.40 S 100, 4603.97 12~,69 ~,,~>~.97 990.09 S 740.88 E :12~6,60 S ~6 48 ~00, 4680.43 1297,11 4602.43 J043,52 S 776,91 E 1300,97 S 36 40 JO0,- 4756'i'76 ...... J56'1'~-69 ..... 4678¢76 ...... 1097i09---S 100, 4832,94 1426,46 4754,94 JJ51,41 S 848,~2 E 1430,18 S :36 23 o . % 84 J206.63 S 882o83.E 1495.11 100 4908 84 149J.~7 4830. : . . · ............. ~5 52 35:39 S7 48 37 SS --37 20 :37 8 36 58 62 17 58 56 --55-"49 52 ~6 49 21 :39 47 50 : 593,28 S 40 658,:34 S :39 722,64" S 38 786,8~ S S8 850,93 S 38 .. E E 0.25 E E J.~2 E' 0,25 E 0,50 E 0,8~ 'E 0,'25 .... E 0.25 E 0,25 FEET" FEET FEEl' : FEET D M qRO0 ALASKA, !Ne.,, )S 13, WELL NO; 9 GMS PRUDHOE'-'BAY'~" NORTH SLOPE, AI.ASKA' ,JOB NO! A038200406 TRUE 1[ASURE'I:-I-[IRIFT: ........[IRIFT ": - COUR,.>E'° ·V .F..R'I' ' ICAI. 'VE'RTICAI. DEPTH ANGLE DIRECTION I..ENGTH DEPTH SECTION . FEEl' D M D H FEET FEEl' FEET- ·.' COHF'IlTATION TINE DATE .1-4T0 21-2 ~.-23= M.A R-- 82 SUB,SEA ' R E' C'~T'A 'N"'E~'"U':"[.'-'A~'R .......... C"L'"O S'U R E I'VI? C-[) (3 R D I N A l'-E S DISTANCE DYRECI':r FEET FEEl' FEET D H 6000, 42 ].5 $ 33 0 E 100· 5355·58 1.892 04 5277 ,8 1543· · . ·~ 44 S 1099·50 E 1895.02 6100o" 42 45 S 3J 0 El 100, 5429 ~1 1959·59 5351 31 1600 10 S .... 6-200,.-?--4-2--~5-S~"55 ....... 0 E ....... ~.00¥ 550J-~04 ......2027'~14 .... 5425'~04 ......1656'~-7~-S .... I'2735-09~'-E-~2030T02 · '~ 21 . 32 S 1209·12 E' 2097 O1 6~00 42 0 S 32 0 E 100, 5577,20 ~,094· 5499 20 ~713. · 6400.: .42 15 S 32 0 E 100. 5651·37 2161.28 5575,37 ~770.21 S ' ]244·67 E. 2163,98 .................. : ................. ; .: -'35 .1. (3 35 1~ 55 7 6500,~ 42 ]5 S 32 0 E 100. 5725·39 2228,52 5647.39 1827,23 S 1280·~0 E 2231·12 S ~5 6600·. 42 0 S ~2 0 E 100 5799 56 2295·~ _ , · ~;9 572!.56 1884 11S 1315.84 E 2298·11 S ~4 "~6700l~4'2-~0--S"-~2 ...... O'E ....... JO0, 5873188 6800, 41 30 S 32 0 E 100. 5948·48 2429,0~ ,,=870.48 1997,~2 S 1386,58 E ,.~4~1·44 ,R ~4 6900~ '41 45 S 32' 0 E ~00, 6025,23 2495·51 5945.25 2055.65 S 1421,78 E 2497°79 S ~4 0 E 0 E 0 ['." 0 E 0 E 0 0 0 'E 0 E 0 E E E 7000,: :42 ]0 S 32 7100. 43 O:S 32 '"7200'~'44 ....... 0'-S'~2~ 7300, 44 30 S ~ 7400. 45 1~ S ~4 : 7500· 46 0 S 34 7600, 47 0 S ~4 "7700,-77'47 .....0'S'34'- 7800, ' 46 15 S 34 7900. 4~ ~0 ~ ~4 100, .... 6097 ~0 ~.,~x~ 59 6019·40 2.1.1.0,~3 S ]457.53 E 2564.7~ S ~ ~ 2¥%37:~ ~ . . 100. ':6170.83:::~..6~0:7477;v6092:i8~??~168,10':S '::149,~.30 E. 2832.60 S J 00. 6455,80 2911.06 6377:.:80.::'(~/2403',:42~vS 1646.18 E 100 6524.65 2~8J,56 6446 6~ 2465 ="~ · . .,~,.~ S ~686.74 E 100, 100. 100 · 6592.83 6661·5J 673J.13 1. 56 5.1 46 42 34 SE) 34 30 2771.11 S 34 27 .2841.65 S 34 25 2913,1~ S 34 25 2985.66 S S4 24 3056.67 ' 6514.83 "' 2524 ,-1'8 ' S .... .1 727'.-64 -~IE ..... 3058 ~'80-' Si"34 23 31.29·32 6,583.5J 2584 44 S : 1768.28 E ,31,31,48 S 34 .,..~ 3201o07 , ~' 1~ '~ <' ~6c, 3..,.643,95 S 1808,42 E 3203.26. ,., 34 ~..">':'... 8600. 41 ~0 8700~--40 8800. 100. 6801o ..... 100, ~872~8~ ~42~11 100. 6944~79 '~4.1..1~52 100, 7017,02 3480,65 100. 7089·71 ,3549,32 67...3,,,5 70 ,83 8 1848. ~ ~ ]4 E `3274,28 S ~4 6794,85 2760,94 S ' 1887,3~ E ~344,37.,~' J4 21 E 6939,02 2875,84 S ~'764,(:)4 ~' 348'> ,,,, 97 7011.7] 9934,08 S 2001,~3 E 35~Jl.59 S J4 18 [:: 100. 7163.29 3617.03 7085.29 2991.82 S:~2036.61 E:; 3619.22 ' ,,, 2;4 :l'::' 100. 7237.90 ,~683.60 7159.90 3048.90 8 2070.91 E ~685.71 S 34 11 100, 7313,65 '3748 86 ...... '> :' =; . ............. . '7~.3,.~.6,.~ 3104 85 8 2104~52-~E ..... -3750,88 'S 34 8 100 ..... 7390,54 3812 80 7312.54 3159.07 S 2]58.4] E ~814.78 c,> 34 6 100, 74~8.52 ~875.~ 7S~O,~,,. ~211.8~ S 2172.04 E 'J877,J4 S J4 4 .:: . .':: :: N 0, 3 _ I)OGI...E~ ON ,. EVERIT' D G/100F' E 0,25 E 0,50 E 0,5o --- E O, 72 E: 0.25 e o oo E 25 E O, O0--- E 0.50 E: O. 25 b. 0,75 E 0.50 E E E 1,0~ 0.86 1.03 0.75 J,O0 0.00- 0,75- 0.75 0. dO :l. O0 ()J~ 2,1~ 0,25 . , - 1o42 0.50 .1,37 1,63 -~RCO AI,ASKA, INC, ' - ' COMF'IITATION PAGE NO, 4 DS 13, ~WELL NO,* 9 GMS ,JOB NO,+ AO38280406 TIME · DATE - I - 4 ~°'-. 0~ ~ -+-~>, ~ -' ~- ~S ' - MAR' - F, RUDHOE--BAYs-NORTH-SLOPE~,- ALASKA TRUE DOGLEG MEAsURED--DR-IPT ..... DR-I PT ....... COURSE VERT-I CAI,-- VER]'I CAI~ ..... SUBSEA .... R- E DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C-0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT FEET 9000,' S7 0 S 33 0 E 100, 9100. .36:45 S SS 0 E 100, ---9200:-W-S-6 .... 0'-S'"'34 ..... O-'E- -- 100. 9300, ~ 35 15 S 33 0 E 100. 9400, 34 0 S 32 0 E 1.00. 9500' ~33 15 S 31 0 E 100, 9600' 33 0 S 32 0 E 100. 9700~,"33 ..... 0"-S--29'- 0 E 1(>(>, 9800. 32 :0 S 2'8 0 E 100o 9900, 31 0 S 25 0 E 100. D M D' M FEET FEET FEET FEET F'E:ET ' FEET ~ 74 E 3938.20 S 34 7547,86 '3936,27 7469,86 3263.20 S ~.~04, 7627.85 ~996.27 7549,85 3313.53 S ~_,~>o~? 43 E 3998.19 S 34 7708.36' --4055,56 .... 7630,36-' 3362.98-S ...... 2270'~-t'6--E ...... 4057--~.50 ...... S' 34 7789.65 41J3,79 7711.65 3411 55 S ~ o 31 E. 4115,74 S 34 ~ ~ 84 E 4172.54 S 34 7871.94 4170.61 7793.94 3459.47 S ~:33~, . 7955.20 ~.,~,a">~s,98 7877,20 ,.X.::;n/,,..,,~.69 S 236J,77 E . 4227.86 S 33 58 8038.95 4280.62 7960.95 3553,28 S 2390.32 E 4282,46 S 33 6 81.22 ~ 82 -- 4~35,05 ..... 8044-~ 82 -: ---~600,-'20--S~241-7'-,-96-E~-4336'* 82 .... S--.33 5~ 8207,16 4388,66 8129.16 3647.42 S 2443,60 E 4390.31 S SS 49 8292.42 4440,64 8214,42 3694,17 S 2466,91 E :' 4442.13 S 33 44 : 10000.: 31 0 S 24 0 10100, 31 J5 S 24 0 E 10200', .....32 .... O"S ~.4" 0 E 10300, 32 0 S ~.~ 0 E 10400.~ 32 0 S 25 0 E ~ . 10500, 32 0 S 24 0 E 100, 8~78.14.~,,_a491,68 8300,14 3741,~4 S 2488,27 E 100.;' :!:: ;8463 , 74!~!'ii;~i~4542,,837,;:::8385~,,~:74~,,?,3788 , 26 S 2509,29 E 89' - 4094 ,:72; ::' 8470,89 ::~ 38~6:.~1:~7-~::S~?~':o~0 * 6~. 'E 100 *: ' :: :' ~633 , 69 4647,-.23:~:~ 8555',69 .3884~ 1 00 J O0, 880~. 30 47,J~. 3J- ~'~ 872a~.,,.~ ,:O;~()L398.0,.'.63N'S 2596.96 E 4492,98 S 33 38 4543,95 S 33 31 4595°67. S.33 4648.03 S 33 19 4700,47 S 33 1.3 4752,86 S 33 7 1.0600. 32 0 S 24 0 E 100. 10700, ...... 28'-'30-S'"19 .... O"E: -'JO0, 10800, 28 0 S 18 0 E 100, 10900, 28 15 S 17 0 E 100, : 11000, 27 15 S 19 0 E 100. 11100, 27 0 S 19 0 E 100. 1-1200:~--27 ..... 0-S-20 .... O E .... JO0. 8888.1.1 4804.75 8810,11 4029.04 S 261.8 8974,48 '4854.22 .... 8896,48 ..... 4075.89-S ..... 2636 9062,57 4900.20 8984.57 41.20.78 S 2651 9150.76 4945.78 9072.76 '4165.73 S 2666 .52 E 4805.19 S 33 1 ~97'"'E ..... 4854','54"'S-'32 54 ,99 E 4900,39 S 32 46 ,16 E. 4945,88 S 32 37 '"'"' 95 S 32 29 9239,26 4990,9;I. 9161,26 4210,01 S 2680,o,., E 4990, 9328.26 5035.29 9250,26 4253,12 8 2695,39 E 5035.30 ~ 32 22 ~ m' ~'~ ~ ~.- ~" ' 94 t ?,'36 .......5079~'56 ..... 9-2;39, DG/iOOF E 1.17 E 0.25 E 0.96 - E O. 95 E 1.37 E o __93 E 30 E t.63 -- E I , 14 E J .86 _ . E 0.52 E O. 25 E O, 7~ E O. 53 E O, O0 _ E: O, O0 E E 0,69. E 0,53 E' 1,37 E 0.25 E 0,.45 . : PROJECTED TO:-TD ~ 9613,38 5177.17 95~5.38 11420. :!27 0 S 20 0 E ~,~0. , : 4~89,77 S 2744.71 · : E 5177.21. S 32 1 E FINAL CLOSURE - DIRECTION; ,~ 32 DEGS 0 HINS 57 SECS E ::" :: DISTANCE; 51 77,21 FEEl' · 0,00 ARCO Al. ASEA, INC DS"-J;3','-WELE "NO ~ PRUDHOE BAY, NORTH SLOF'E, AI.ASKA GMS, 0-10800 MD, SURVEYOR~ D F'EFFERKORN DAI'E RUN; O~-MAR'82 C-~-M E R~A--~ 0-~'"~'~ ~ 5-~0 DEG. A/U NO; ~5~2 FORESIGHT-; .... N"-55--W .......................................... ~RCO ALASKA, INE:. .*;S 1:3, .WELl-~NO; 9 GMS ,]OB NO; A0:3821~0406 >RUDHO~BAY~NORTH'--SCOPE ~--~A;~ASKA~ - ·, · ......... MARKER" TRUE SUBSEA ~ ....... ' OOD~ ....... ' ..... MEAStJRED'~ VERTICAI~ ...... H[~-TVD .....VERI'ICAL-: R"'E-'C~-T-A-N-B-'II-L~A-"R ........ NAME DEPTH DEF'TEI DIFF DEPTH C 0 0 R D I N A T E'~ FEEl' FEEl' FEET FEEl' FEET ,=~ · TOF' OF SAFJLEROCHIT DIE/WATER CDNTACT F'BTD' BASE OF SADLEROCHIT TD ~ · !-i'~ COMPUTATION PAGE NO. , '. TIME- DATE i-4-..0 8-tO 9---2.3 =M A R.-_-. 82 C'-L'O S U R E ....... DISTANCE IjIRECTION FEET Ir, M 51 E .10 E ....... 5 E 1 E 10735.00 9005.3'1 1729.7 8927.31 4091.60 S 2642.23 E 4870.58 S ]0837.00 9095.20 ]74J.8 9017.20 4137.41S 2657.23 E 4917.22 11278.00 ...... 9486~86 .... 1-79]-~-1 .... 9408,86 ...... 4329~.1-9--~-2722~-66---E:~--:' 51'14.17'-S ]1362.00 956J.70 1800.3 9483,70 4365.03 S 2735,70. 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Office B~" '50 Anchorage. ,',t',~a 99510 Telephone 907 277 5637 March 29, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA D.S.14-13 3/3/82- D.S.13-9 3/1/82 D.S.14-29 2/27/82 Gyroscopic Multi-Shot Gyroscopic Multi-Shot Single-Shot Jon No. AO382G0405 Job No. AO382G0406 Job No. AO282D0268 Please sign and return the attached copy as receipt of data. Mary F. Kell±s North Engineer£ng Transmittal #70 · DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA Eastman / 1 Whipstock l~~ A PETROLANE COMPANY SUB-SUrFACE DIRECTiONAl. SURVEY ARCO ALASKA, INC. COMPANY DS 13, Well Number: 9 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER A0382G0406 SURVEY BY D Pefferkorn TYPE OF SURVEY Gyro Hulti Sho:h DATE 01-Mar-82 ~ -'f ~',, ,t, OFFICE Alaska ARCO AI_ASKA, IN~, : DS- 1B'~--WEISL- NO; 9-GMS .................................... JOB - NO F'RUDHOE BAY, NORTH SLOPE, ALASKA GMS, 0-10800 MD, SURVEYOR: D F'DFFERKORN DATE RUN~ O]-~AR-82 CAMERA'~ N0~-S17~ ......... GYRO-NO ~ -628 ........................................................................................ 5-90 DEG, A/U NO: 1562 FORESIGHT~ N 55-'W VERTICAl_ SECTION CALCULATED::!N PLANE:~OF-:PROPOSAi, ........ '.;::,BIRECTIONl...;:S..-42 :DEG, 15 M!N, E RECORX; OF .SURVEY I RADI~.tS OF CURVAT~.;RE METHOD DS J. 3~ WELL Nf_;~ 9 GMS _ JOB NO~ AO382GO._406 I~RUDHOE BAY, NORTH ~I'_OPE, AL.ASI<A ............. :' -;" TIME DATE ; 0..°..: 23 2S-MAR-82 TRUE ~E'ASURED:DRIFT ~'DRIFT .... COURSE-VERTICAlS-VERTICAl.' SUBSEA- R E C l' A N G U L A R C L 0 S U lq: E ' DOGL-EG- DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEEl' FEET O, 0 0 0 0 Oo 0,00 0,00 -78.00 0,00 0.00 100, 0 0 0 0 100, ~00,00 0o00 22,00 0,00 0,00 ........ 200~ ........ 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O0 1: :100o lJO0,O0::: - - 100o :L200,00' 0'88_. :: 1122'00 . 100~ J~O0,O0 !00~ 1S99,99 i00. ]499,99 ]00~ 1599,99 100. J699,99 100o J799,99 100. 1899~98 1.51':1222.00 2'~ ~s21,99 2,9~ 1421.99 S~S4 ]521.99 S.7S I621.99 4.S2 1721~99 5.40 1821.98 0.02 S 0.4S E 0.2S S 0.48 E 0.65 S 0.61E 1.28 S 0.80 E 2.13 S 0.99 E o 78 S 3.64 S 4°29 S 5.27 S 100o ]999,98 6,17 J921°98 5.74 S t00° 2099,97 6,59 2021.97 5,82 S ~00~ 2199.97 - 7~54- -2121-.97 6.42 S 100~ 2299.96 8.62 2221.96 7.SS S ]00, 2~99o96 9,70 2321,96 8,17 S !00. 2499.82 13.19 2421.82 1.00, 2599~19 16.11 2521.19 !00o 2698.06 2~.80 2620.06 J00o 2796.61 S8.70 2718o61 100~ 2894.68 57.54 2816.68 9.62 S 6.38 S 6~12 S 14o71 S 28~00 S 1.10 E 1,17 E' 1.22 E 1.30 E 1.76 E 2.48 E 3.13 E 3.96 E 4.54 E 5.24 E FEET D M DG/IOOFT _ 0 o O0 0 0 O. O0 0.00 0 0 0.00 0,00 0 0 0,00 0.00 0 0 0.00 0.00 0 0 0.00 0.00 0 0 0.00 0 0 0,00 0 0 0,00 0 0 0.22 S 87 0 E ~.43 S 87 0 E 0.54 S 64 6 E 0°89 S 42 55 E 1.51 S ~1 58 E 2.~5 S 24 5~ E 0-00 ( 0 0.00 0~00 0.25 0.25 0.25 0,03 0°25 0.03 2.99 S 2J 3] E 3o4] S 20 3 E 3.84 S 18 35 E 4.48 S 16 54 E 5.56 S 18 29 E 6.25 S 23 23 E 6.61 S 28 15 E 7.54 S 31 38 E 8.62 S 3]. 44 E 9.70 S ~2 40 E 0.25 0.02 0.04 0.26 0.~7 0.o7 0.26 0.75 0,38 0,28 9.46 E 13.50 S 44 31 E 4.60 20.08 E 21.07 S 72 23 E 3.26 34.90 E 35.43 S 80 3 E 4.61 49o21E 51.36 S 73 ~1E 5.76 63.46 E 69°36 S 66 11 E 2,79 ~B. iS, WELL. NO: 9 GN.S ..lOB NO~ AOS82G0.~.06 . TIME [;ATE ~RUDHOE-BAY'~ NORTH SL:OPE', ALASKA .1.4~02~23 '23-MAR-82 TRUE 4EASURED'DRIFT .... DRIFT .... COURSE-'VERTICAL-VERTICAL SUBSEA R-E-C~-T A-N-'G-U-L A'R- C-"L '0 S U R E '- DOGLEG- DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION TV[; C 0 0 R D I N A T E S DISI'ANCE DIRECTION SEVERITY FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100FT ~000~ 15 45 S 50 0 E ~00, 299],70 80,45 291~,70 4~,22 S 82,25 E 3100. 19 0 S 47 0 E 100. ~087.~2 109,11 3009.12 6S,00 S 104.61 E '-S200. ~'-22 SO S 4S' O'-'E' - J00~--S180,62 .... 't-4~65' S102.62 .... 88~05 S .... 129~66 'E ~300, 25 15 S 37 0 E 100, S272+05 187,7S S194005 lj9,04 S 155,66 E 3400, 27 4~ S ~S 0 E 100, SS61,54 228,29 S28~,54 155. ,58 S 18~,24 E oo~v0 S1 45 S ~4 0 E ]00, ~448,~4 277,89 ~70,~4 196,95 S 208,6S E W600, S5 45 S ~4 0 E 100, ~5S1,47 ~S~,41 ~45S,47 24~,00 S 2~9,69 E 92,92 S 62 17 E 1~?~_,1~_ S 58 56 E ]56,7S S 55 49 E 195.96 S 52 S6 E 2S8.86 S 49 21 E 286,90 S 46 S9 E ~4J,S2 S 44 S6 E -- ~700~'- S9 !5 S S4 0 E ..... 100~ S610~80 'S94~25 --S5S2~80 29S~46'~' -27S-,72 E 401,'S0 S 4S 0 E S800. 40 0 S S4 0 E ]00. ~687,82 457,99 ~609.82 S46.SS S S09.S9 E 4640S9 S 41 47 E S900, 40 15 S S4 0 E I00, S764,28 522,41 S686,28 S99,76 S S45,42 E 528,S2 S 40 50 E 4000. 41 S0 S SS 0 E J000~_.S8S9.90 . 587.8S ~761,90 454oSS S S8J~54 E 59S.28 S 40 J E 4100~ 40 15 8 ~4 0 E 100~:: S915,51 65S0:26 :~8S7~51 508,89 S 417,66 E 658,S4 S S9 2S E --4200~ 40 15 S ~S 0 E 1000: ::S99J,8S: .~?.17,85 ~9tS,8~ 562°77 S 45~,S2 E 722,64 S-S8'5J E 4300, 40 0 S S4 0 E 100, 4068,S0 782°28 , S990,30 616,51 S 488,89 E 786,83 S 38 25 E 4400° 40 0 S S4 0 E ~00o: i14144,90 846,5~ 4066,90 669~80 S 524,84 E 85009S S ~8 5 E ..... ~ 09 4500, aO 0 ~ S4 0 E 100~ 4221,51 910,78 414~0~ 7.:.~, S 560578 E 9J5,06 S S7 48 E 46000 40~ 0 ~s S~ 0 ~_ 100, 4298~1~ 975,0S 4~20_ ~1~_ 776,~8 S 596,72 E 979,~1~ S S7 SS E 4700-. 40 t5 ~ ~4 0 E 100 4~74~o8 J0S9 45 4296,58 829,81 S 6~2 76 E 104~ ~4 S S7 20 E 4800, 40 15 $ -~4 0 E 1000 4450.90 1104,0S 4S72~90 88S.S8 S 668.89 E J108.05 S S7 8 E ~900 40 0 ~ ¥~ 0 ~ 100. 4~o7 ~6 1168,44 4449 36 9S6 81S 704 93 E 1172.40 S S6 ..~8 ~ 5000. 40 0 ~ S4 0 E 100. 4603.97 12S2.69 4525.97 990.09 S 740~88 E ~2S6.60 S 36 48 E 5!00. 40 15 S ~4 0 E ~00~ 4680.4S 1297~11 4602~4S ~04S.52 S 776.91E 1S00o97 S 36 40 E - ~5200~, 40 ~5 $ ~4 0 E --~00. 4756,76-- ~S61~69 4678.76 1097,09 S 8:(S,04. E ~S65.52 S S6 S~ E 5S00o 40 30 S S°~ ..... 0 ~ t00. 48S2,94 1426~46 4754~94 ~51.41S 848.S2 E 14S0.18 S S6 23 E 5400, 40 4~ S ._~ 0 E 100 4908,84 149~57 48S0,84 ~206~6S S 882,8~ E 1495,11 S S6 ~ F 550o 4~ ~ S ~2 0 E 100, 4984,~ 1557,18 490~ ~1 1~6~,~7 S ~17,59 E ~560,54 S S6 ~ E 5600~ 41 45 S ~S 0 E 100, 5059,20 162S,44 4981,20 ~18,15 S 95S~9 E 1626,68 S S5 52 E 5700, 42 0 S S~ 0 E 100, ~51SS~66 t690~18 5055~66 ~S7-4,tS S 989,55 E 169S,S6 S S5 46 E 5800~ 42 ~5 S ~¥ 0 E 100, 5207~8S ~757,25 5~29,8S t4S0~9 S ~026~08 E 1760,S5 S S5 S9 E 5900, 42 S0 S ¥S 0 E 100, 528~,71 1824~64 520S~7~ 1486,91 S 1062~79 E 1827,68 S ~5 S~ E S.5S 3.77 ~.67 3.07 4~Q3 4 0 S,50 0,75 0,25 ~.41 0~65 0.69 0°00 0.00 0.00 0,25 0.00 0,25 .~.. 0,25 0~00 0,25 0~50 0,8S 0°25 0,25 . ~.~.~S I3.- WELL NO~ 9 GMS F'RUDHOE BAY'"NORTH ~SLOPE' ALASKA ,JOB NO[ A()382G0406 DATE 02: 23..o'z' M A R' 82~. ' TRUE MEASURED DRIFT -[;RIFT .... COURSE'VERTICAl_ VERTICAl. DEPTH ANGLE DIRECTION LENGTH PEPTH SECTION FEET D H D H FEET FEET FEET SUBSEA R E C T A N-G U L A R C L 0 S U R E - DOGLEG TVD C 0 0 R D I N A T E S DISTANCE BIRECTION SEVERITY FEET FEET FEET D M P.G/100FT . ~ _ . 6000, 42 15 S 33 0 E 100, 5~55,58 i892.04 5277,58 1543,44 6100, 42 45 S 33 0 E 100~ 5429,~t 1~59,59 5351~31 1600,10 ~200; .... 4'2'15 S-33 -O-E -'-~00; .... 550~04 ..... 2027;14 ' 5425~04~ 1656~76 6300. 42 0 S 32 0 E 100, 5577~20 2094~21 5499,20 ~713032 6400, 42 15 S ~2 0 E 100. 5651,37 2161~28 5573.37 ~770,21 S 1099,50 S 1136,29 S ~73,09 S 1209,12 S ~244o67 6500, 42 ~5 6600, 42 0 ~6700; -42 0 6800, 41S0 6900° 41 45 R ~2 0 E 100, 5725,G9 2228~52 ~ - .,647,39 1827~2~ S S 39~ 0 E 100. 5799~56 2295,~9 5721,56 188~,11. S 'S G2 0 E -J00~' 587~88--2~62~50 -'5795,88 J940~85 S S G2 0 E 100~ 5948°48 2429,09 5870,48 1997~2 S S ~2 0 E ~00, 6023,23 249505t 5945025 205~65 S 1280,30 1~15°84 1386o58 1421,78 7000, 42 30 S 32 0 E 7100o 4~ 0 S 32 0 E 7200;--44 0 S ~2 0 ~ 7300° 44 30 S ~3 0 E 7400, 45 15 S ~4 0 E 7500, 46 0 S ~4 0 E 7600. 47 0 S 34 0 E ' 7700, 47 0 S ~4 0 E 7800. 46 !5 S ~4 0 E 7900. 45 30 S ~4 0 E ~00, .... 6097,40.~i?..~2562,59 6019,40 100, 6170°83'~--2630,47' 6092°83 100, 6243°37 ~2699,~0 6165o37 2226 100o ~63~5,00 2769,08 ~6237o00 2285 100, 6385,86 2839,62 6~07o86 2344 2110~53 S 2168~10 S · 47 S ~3S S ~16 S ~ 1 6455,80 ~9~1 06 6524,63 2983,56 6592~83 G056o67 6661o5~ ~129,32 673~.13 S201,07 ~00. 6377o80 2403 100, 6446~63 246~ !00~ 6514,8~ 2524 100o 6583.5~ 2584 100. 6653o13 264~ ~55 S · z8 S · 44 S .95 S ]457,33 t49~030 1529077 ~567.27 ~606,21 1646o18 ~686.74 ~727,64 1768~28 1808o42 E 1895.02 S 35 28 E 0°25 E 1962,52 S 35 23 E 0.50 E 2030~02 ~S S5-18 E ' 0,50 E 2097001 S 35 13 E 0°72 E 2163°98 S 35 7 E 0,25 E 2231,12 S 35 ]~ E 0-z)0 E 2298,11 S ~4 56 E ( ~5 E 2364°93 S-'34'5~ E 0o00 E 2431,44 S 34 46 E 0°50 E 2497°79 S 34 42 E 0°25 . E 2564,79 S 34 38 E 0.75 E 2632,60 S 34 33 E 0,50 E 2701,37 S S4 30 E 1,00 E 2771,11 S 34 27 E 0,86 E 2841065 S 34 25 E E 2913,13 S 34 25 E 0,75 E 2985,66 S 34 24 E ~.00 E 3058,80 S 34 23 E 0.00 E 3131,48 S 34 23 E 0.75 E 3203.26 S 34 22 E 0t~7=5 8000. 45 0 S 34 0 E 8100, 44 0 S 34 0 E ' -8200~ 44" 0 S-~35 0 E 8300, 43 30 S 32 0 E 8400, 43 15 S~.~.~ 0 E 8500° 42 0 S S1 0 E 8600° 41 S0 S ~1 0 E -' 8700~ 40 0 S 31 ' 0 E 8800, 39 30 S 33 0 E 8900~ 38 0 S 32 0 E 100, 6801,53 3272.05 6723,53 100° 6872,85 3342,11 6794,85 100~ 6944°'79 ...... S'41],52 6866°79 100, 7017,02 3480,65 6939,02 100, 7089o71 3549,32 7011,7~ °70~ 83 2760,94 2818o!9 2875°84 2934°08 100o 7163,29 3617,03 7085~29 299I~82 100, 7237,90 3683°60 7159.90 S048o90 100o 7313,65 3748.86 7235,65 St04085 100~ 7~90.54 38~2°80 7312o54 3~59.07 100° 7468°52 3875~39 7390,52 3211~86 t848o~4 !.887,33 1926,67 ~964o84 ~001 ~S 2036,61 2070o91 E 3274,28 S 34 22 E 0,30 E 3344,37 S 34 21 E 1,00 E 3413,83 S-34 22 E 0,69 E 3482.97 S 34 21 E 2.13 E ~551,59 S 34 18 E 0.25 _ . _ E 3619,22 S 34 15 E 1,42 E 3685,71 S 34 1! E 0,50 °88 S 34 8 E 1.50 .78 S 34 6 E ~.37 ,34 S 34 4 E 1,63 . 2104,52 E 3750 2J38~4~ E 3814 2t72004 E 3877 _ DS 13, WELL. NO~ 9 GMS JOB NO~ AO382G0406. TIME DATE PRUDHOE-BAY~--NORTH ~LOF'E-~--AI_-ASKA 14;02;23 -23-MAR-82 TRUE MEASURED [;RIFT ...... DRIFT ....... COLIRSE--VERT-iCAL-VERTICAi,-SUBSEA R E C-T A-N-G-U--L-A R · -C-L 0-S U-R-E .... DOGL-EG- DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE D~RECTION SEVERIT~ FEET D H D M FEET FEET FEET FEET FEET FEET D 9000, 37 0 S ~3 0 E 100, 7547,86 ~9~6,27 7469,86 ~263020 S 2204,74 E 3938°20 S 34 ~ E 9100~ ~6 45 S ~ 0 E 100~ 7627,85 ~9&,27 7549,85 ~313,53 S 2237,43 E 3998,19 S ~4 2 E - ~ ' ~ ~200~ ..... ~ .... 0S-34 ...... O'"-E ......~00Y----7908~6 ..... 40~.~.6 '7630,36 3362',~8'S ~.~70,16-E --4057~50 S 34--.1 E 9300, ~5 15 S 33 0 E 100, 7789,65 41~3,79 7711,65 3411,55 S 2302~31 E 4~15,74 S 34 i E ?400, 34 0 S 32 0 E 100, ~7871,~4 4170,61 7793,94 3459,47 S 2332,84 E 4172,54 S 34 0 E 9500, 33 15 S 31 0 E 100, 7955,20 4225,98 7877,20 ~506,69 S 236~,77 E 4227,86 S 33 58 E 9600, 33 0 S 32 0 E ~00, 8038,~5 4280,62 7960,95 3553,28 S 2~90,32 E 4282,46 S 33 56. E - ~ ~ 4335 05 8044 82 9700, -33 O S 29--OE ...... 100~---81~.~8~ .... , , ~600~20-S-~241~7~96--E 4~6~-82 -S-~3 53 E 9800, 32 0 S 28 0 E 100, 8207,16 4388,66 8129,16 ~647,42 S 2443,60 E 43~0,31 S 33 4~ E ~900, 31 0 S 25 0 E 100, 8292,42 4440,64 8214,42 ~694,17 S 24&6,Yl E 4442,13 S 33 44 E 10000, 31 0 S 24 0 E 100, .... 8378,14 _44~1,68 8~00,14 3741,04 S 2488,27 E 44~2,98 S 33 38 E 10100, 31 ~5 S 24 0 E 100~Y~:~8463,74: 4542~8~ 8385~74 ~788,26 $ 2509,29 E 4543,~5 S 33 ~1 E -t0200.,---~2 O~S 24 .....O-E ~00~?~::8548,8911~45~4'93 8470,8~ 383&~1'7 S'Z;~2530,62 E 45~5,-67 S 33 25 E 10300 32 0 S 25 0 E 100~;~8633 6~ 4647,23 8555~69 3884 ~,? S 2552,59 E 4~48 03 S 33 19 E ~0400, 32 0 S ~ 0 E 100°~:!~:~18718050 469~,80 8640,50 3~32,41 S"' 2574,~9 E 4700,47 S 33 13 E 10500 32 0 S 24 0 E ~00, 8803,30 4752°~] 8725,30 ~80,63 S 2596,96 E 47.,~,8~ S 33 7 E 10600~ 32 0 S 24 0 E ]00, 8888,11 4804,75 8810,1i 4029,04 S 2618,52 E 4805,19 S SS i E 10700° 28 ~0 S 19 O-E ~-~00', ..... 8974,48 '4854,22 8896,48 4075°89 S .2636,97 E 4854,54 S S2 54 E 10800~ 28 0 S 18 0 E 100, 9062,57 4900,20 8984,57 4!20~78 S 2651,99 E 4900,39 S S2 46 E 10900~ 28 15 S 17 0 E 100, 9150076 4945,78 9072~76 4165~73 S 2666,16 E 4945,88 S S2 37 E 11000, 27 15 S 19 0 E 100~ 9239°26 4990,9t 9161~26 4210,01 S 2680,55 E 4990,95 S ~2 29 E 11100, _.?~ 0 S 19 0 F-_ 100, 9328,26 ~o~,M^~ 29 9250,26 4253. ~1~ S 2695~39 E 50~5·S0 S S2 ~.~ E 11200· 27' 0 S 20- O~E -]00', ..... 941~,~'6' 5079,56 9~39,36 4295~92-S --27~'0,55 E 50~9°56 S S2 15 E BG/100FT 1·17 0,25 0~96- 1,37 C ,0 1,63 1,14 ]o86 0,52 0,25 0,75 0,00 0,69 0~53 -~. 0,25 0,45 F'ROJEC'TED TO TD 11420, 27 0 S 20 0 E ~..~0o 9613,38 5177,1.7 9~:35,38.., 4389,77 S '744,71~. E ~,177,°-1~_ S 32 1 E (.)0 FiNAl_ CLOSURE - DIRECTION; S 32 DEGS 0 MiNS 5;7 SECS E DISTANCE; 5177~21 FEET ARCO At. ASEA, iNC~ PRUDHOE BAY, NORTH SLOPE, Al. ASEA GMS, 0-10800 MD, SURVEYOR; D PEFFERKORN DATE RUN; O~-MAR-82 5-90 DEGo A?i~ ~0~ ~5~2 - FORESIGHT~ N 55-W ............................... DS 1S, WELL NO: 9 GMS PRUDHOE--BA Y-,--- NO R T H SCOF'E-~---AI:~SKA .................. JOB NO~ AOS82G04.06 TIME DATE ,. .......... ~ .........: ......................... 1'4-~ 08 ,+'09 .....2~MAR=-'82 ............ MARKER- TRUE SLiBSEA ~--'~- ...... --CODE--- ME-ASURE-D .... VERTIC. Ai~- - MD-TVD - VERTICAl_--- R--E---'C--T-.A-N -'G -U L-- A R ...... C---L 0 S- U-'R E--: ......... NAME DEF'TH DEF'TH DIFF DEF'TH C 0 0 R' D I N A T E S DISTANCE DIRECTION FEET FEET FEET FEET FEET FEET D M TOP OF SADLEROCHIT 10735,00 9005,S1 1729,7 8927,S~.. '4091~60 S ,.~64~,2S E 4870,58 S 32 51 E OIL/WATER CONTACT ]08~7 O0 9095 20 J74a 8 9017 20 41~7 41 S .;6.~7, E 4917,22 PBTD ................................... i-i2-78~-00 ...... 9486~8~ ..... 1-79J-J1 - 9408J86 ...... 4S29~-1-9-S-2722,66- E'- 5114~-17 S-~2- 10-E .... BASE OF SADLEROCHIT 11S62~00 956J~70 1800~S 948~,70 4S65,0~ S 27S5,70 E 5151,46 S ~2 5 E TD 11420,00 961S~8 !806~6 95S5~8 4~89~77 S 2744,71 E 5177~21 S ~2 I E ................................................... 't ~T,~ .0_,! 'FILFISK-' .... APE I RO~'~,'~E CO~Zf~"INY Harch 23, 1982 ARCO ALASKA, INC. P.O. Box 360 Anchorage, Alaska 99503 Well Number: 13-9 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Gyro Multi Shot Date: 01-Mar-82 Method of Computation: Radius of Curvature Surveyor: D Pefferkorn Job Number: A0382G0406 Attn: Bob Hines Dear Mr. Hines, We are enclosing 'the original and sixteen copies of the Gyro Multi Shot Survey run on the above mentioned well. To date, the following distribution has been accomplished: A. ~. copy telecopied to E/W North Slope office for delivery to ARCO field representives. B. 16 copies delivered to drilling for in-house distribution. C. 3 copies for E/W permanent well files. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. Sincerely, District O~eratio~s Manager ST/bb cc: fi].e enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO ~laska, Inc North Slo~' i:;~ric:t Post Office .,5~c,x 3GC, Anchorage. Telepl'~one 907 277 5637 Jerry A. Rochon District Operations Engineer March 16, 1982 Mr. C. D. Chat Chatterton State of Alaska. Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Subject. D.S. 4-11 Permit No. 78-6 D.S. 4-14 Permit No. 78-36 D.S. 11-1 Permit No. 81-123 D.S. 11-2 Permit No. 81-128 D.S. 11-3 Permit No. 81-147 D.S. 11-5 Permit No. 81-155 D.S. 11-6 Permit No. 81-161 D.S. 12-4A Permit No. 81-187 D.S. 12-7A Permit No. 81-175 D.S. 12-8B Permit No. 81-167 D.S. 12-13 Permit No. 81-87 D.S. 13-5 Permit No. 81-103 D.S. 13-7 Permit No. 81-129 D.S. 13-8 Permit No. 81-148 D.S, 13-9 Permit No. 81-158 D.S. 13-10 Permit No. 81-165 D.S. 13-12 Permit No. 81-142 D.S. 13-19 Permit No. 81-180 D.S, 14-12 Permit No. 81-109 D.S, 14-13 Permit No. 81-101 D.S. 14-26 Permit No. 81-110 D.S. 12-14 Permit No. 81-138 Enclosed are .our Sundry Notices detailing the work to be done on the above mentioned well. Very~truly yours, . ,; .t.'~' j . ..:-~ '-: "' z L.,.'..'"~..-.-. - ..... O. A. Rochon JAR' TKKW :ml c Enclosure A!~l<a Oi! & {.~:.~, Ct}ns. Anchorage ARCO Alaska, Inc, is a subsidiary of AtlanlicFlichfiehJC.mpany A( STATE OF ALASKA ~'(0 ALASK ~,ILAND GAS CONSERVATION C ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-158 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50_029-20671 4. Location of Well 1290'FSL,155'FWL,Sec 13,T10N,R14E,UM (surface) 2250'FSL,2200'FEL,Sec 24,T10N,R14E,UM (TD-taken from single shot directional survey-gyro not available at this time) 5. Elevation in feet (indicate KB, DF, etc.) RKB 78 ' 12. I 6. Lease Designation and Serial No. ADL 28315 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-9 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate r-~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. 14. I hereby cer,~fy that the foregoing i/s,'~t'ue and correct to the best of my knowledge. /) Signed b--/~ ~/'~- /-'~';~"~'~. ~'~'~ ,-~----~ Title T~ '; ~ -I- The space~.I/o~N or Commission use Conditions'~6f Approval, i~'-~ny~ ,, Approved by__ Approved '?opy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate . ARCO~Alaska, Inc. , Post Office Be{' lO Anchorage, AlasKa 90510 Telephone 907 27'7 5637 December 22, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS ll-3, DS 12-8B, DS 12-14, DS 13-9, DS 13-10, DS 14-12, DS 15-13, DS 14-13, lA-9, lA-10, B-9GI, B-IOGI Dear Sir- Enclosed please find the following' 1. 'Monthly Reports for drill site 13-10, 14-12, B-IOGI. 2. Well Completion Reports for drill sites 11-3, 12-14, 13-9, 14 13, 15-13. . Completion Gyroscopic Surveys for drill sites 12-8B, 15-13, lA-9, lA-10 and B-9GI. Sincerely, P. A. VanDusen District Drilling Engineer PAV'GA'ltc RECEIVED 198t Alaska 0it & Gas Cons. Commissi0r~ Anchorage ARC() Alaska. Inc. is a subsidiary of AtlanlicRichliehJConlp;~ny " STATE OF ALASKA ~( ~ ALASKA U'- AND GAS CONSERVATION CO.,,.,MlSSlON ~f WELL COMla'LETION OR RECOMI LETION REIn'CRT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-158 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50- 029-20671 4. Location of well at surface 9. Unit or Lease Name 1290' FSL, 155' FWL, Sec. 13, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number To Be Submitted. 13-9 ' At Total Depth 11. Field and Pool To Be Submitted. Prudhoe Bay Field '5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Pl~dJ~oe 0il Pool 78' RKB ADL 28315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I15. Water Depth, if offshore 116. No. of Completions 10/30/81 11/14/81 11/19/81 feet MSL 1 17. Total Depth (MD+'TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11420' MD 11278 ! MD YES,~ NO [] 2122 ! feet MD 1800' (approx. 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf. 80' 3'2" 300 ~x Permafrost z,, 2400 sx Fondu & 400 sx Permafrost ", 13,3/8" 72# L-80 Surf. 2424' 9-5/8" 47# L-80/ Surf, '10571' 12J" ...500 sx Class "G" amt. S00-95 ',,, ' ~" $90 Sx class "G" cmt ,, 7" 29# L-80 10250 ' 11408 ' 8~. . 24. Perforations open to Production (MD+TVD of Top and Bottom and . 25. TUBING RECORD interval,, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ~" 10271 ' 10204" · , , ' 26. ACID, FRACTURE, CEMENT SQUEEZE, E'ILC,' -. To Be Submitted. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A · , , ,, ,, , 27. PRODUCTION TEST . Date F.irst P.roduct on I Method of Operation (Flowing, gas lift, etc.) N/A N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE [GAS-OILRATIO TEST PERIOD ~ I , Flow.Tubing Casing P~essure . CALCULATED OI:L-BBL GAS-M'CF WATER-BBL OIL GRAVITY-APl (cDr'r) Press... . 24-HOUR RATE :. " 28. ' cORE DATA. . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , .,,, :' . . ., ,, ,.,,, , ,, DE~,..,~'.~ 1581 Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME TO BE GEOLOGIC MARKERS MEAS. DEPTH SUBMIT TRUE VERT. DEPTH rED FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certifv that the foregoing is true a,~orrect t~ the best of my knowledge 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 !,. 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 DS 13-9 Drilling History NU 20" Riser. Spudded well @ 1800 hrs, 10/30/81. Drld 17½" hole to 2440'. Ran 59 jts 13-3/8" 72#/ft L-80 csg w/shoe @ 2424' Cmtd 13-3/8" csg w/2400sx Fondu and 400sx Permafrost "C". ND 20" riser. I~stld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Drld FC & cmt. Tstd csg to 2000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW- ok. Drld 12¼" hole to 10,581'. Ran 255 jts 9-5/8" 47#/ft L-80 S00-95 csg w/shoe @ 10,571' Cmtd 9-5/8" csg w/5OOsx Class "G" cmt. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 2000 psi - ok. Drld FC & cmt. Tstd csg to 2000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok.. Drld 8½" hole to ll,420'TD. Ran DIL/SP/BHCS/GR and FDC/CNL/GR/Cal. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbl H20, 300sx Permafrost "C" and 120 bbl Arctic Pack. Ran 29 jts 7" 29#/ft L-80 liner from 10,250' to 11,408'. Cmtd 7" l~ner w/390sx Class "G" cmt. Drld cmt to 11,278' PBTD. Ran GR/CBL. Tstd lnr lap to 2000 psi - ok. Displaced well to NaC1/NaBr. Ran 4½" completion assy w/tail @ 10,272" & pkr @ 10,204'. Tstd tbg hanger & packoff to 5000 psi - ok. Displaced well to diesel. Dropped ball & set Pkr. Tstd tbg to 3000 psi & ann to 200 psi - ok. Tstd tbg to 200 psi & ann to 3500 psi - ok. Closed SSSV @ 2122' MD. Instld tree cap & tstd to 5000 psi - ok. Secured well & released r. ig @ 2000 hrs, 11/19/81. j · , PRUDHO~ DRY, NORTH 'SLOPE, RLRSKh: -7' ERSTMRN"'14~J I ?STO~K;-i' I NC. , '~ ..... ? ........ i ' .... '.---..'.-7.."[ '77"7' ..... ! ..... t .... "t t -- ~ .... ~ i .............. i . . ' DRIFT_'.z/ ..... RSSEMBLI'ES~_ ~" B: ANGLE BUILD RSSEI'BL' ~ ~ ' CL..._7 3/4 DYNR DRILL_ ' .... D: RNGLE BUILD RSSEMBL' ; . E: PRCKED HOLE RSSEMBL' F~ PRCKED HOLE RSSEMBLT, i ' ~ ... G: PRCKED HOLE/SLIGHT ] ....... RNGLE BUILD RSSEMBLY -" H: FLICKED HOLE fl$SEMBLT ' ~'', Suggested form to be insert~ in each "Active" weI1 folder to d~.eck. for timely complianCe with our regulations. ..... Ol~rator; W-ell Niune and Reports and Materials to be received by: /~-1 ~ Date Required Date Received Remarks ~ .Ccmp lotion Re~rt Yes /~_ ~ .--_ ~/ /~~--. well. History Yes' · , . . : : · · , ,' . , ,: ' . ., ] , , Core msc~tion ' Dire~ional, ==ey. ' 7~" PI Drill S{~Test. Re~s .. . ~ X~ . ,. . - . ' '~ -a ARCO Oil and Gay 'mpany North Ala sk'~, ' '~-',"~ Post Office Box Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer December 10, 1981 Reference: ARCO Cased Hole Finals D.So13-9 11/23/81 CNL/GR/MS Run 1 5" .. lease sign and return the attached copy as receipt of data Mary F. Kellis North Engineering Transmittal # 810 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG, MANAGER D&M GEOLOGY S~ATE OF ALASKA ARCO Oil and Gas Company ~s ;3 Division et AtlanticRichfielclCompan¥ EXXON MOBIL GETTY PHILLIPS '~ S0H 0.,-.'" /' -'q' -.,.,, ,,Pr: lvcr, Alaska 0il & ~as Cons. C0mmissg. Anchorage ARCO Oil and Gas Company North Alask~~'' 'strict Anchoraee. A!~;ska 99510 Telephone -307 ,"'77 5637 derry A. Rochon District Cpera~,ions Engineer December 4, 1981 Reference: ARCO' Cased Hole Finals D.S.3-18 11/7/81 CNL Run 4 5" D.S.13-9 11/13/81 CNL Run 1 5" Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #797 DISTRIBUTION NORTH GEOLOGY DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA 'EXXON MOBIL GETTY PHILLI,PS SOHIO MARATHON CHEVRON ,ARCO Oil ,3'3d ~.;~s Ccr~pany *s ,~ ,.)~v~¢,on ol Atla~tt,cRichfleld'Company Oil and Ga '" ARCO ~ ,mpany North Alaska Distric'~ Post Office 8ox 330 Anchorage. Alaska 39510 Telephcne 907 277 5637 Jerry A. Rochon District Opera~,ions Engineer December 4, 1981 Reference:.ARCO Open Hole Finals DoSo13-9 11/13/81 FDC D.S.13-9 11/13/81 FDC/CNL D.S.13-9 11/13/81 BHCS D.S.13-9 i1/13/81 DIL/SFL D.S.13-9 ........ 11/14/81 ~. Cyberlook D.S.13-9 11/13/81 Profile Caliper Run 1 Run 1 Run 1 Run 1 .,..Run 1 Run 1 1! 2" & 5" 1! 5" .Please sign and return the attached copy as receipt of data. .~. Mary F. Kellis North Engineering Transmittal #796 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO O~l 3nd G,)s Comp,tr~y :S a D;',is~on of Atlant,cRlchtieidCompan¥ ARCO Oil and Gas Cornpany North Al,'~skf~ "~isirict Post Office~ , 356 Anci~orage. Alaska ~g51.0 Telephone 907 2.77 ,~$S7 Jerry A. Rochon District Opera,,ions Engineer De.c. ember 3, 198~. Reference: ARCO DIRECTIONAL SURVEY DATA D.S.11-2 ~ 10/6/81 .D.S.13-S ~/ 11/5/81 D.s.i4-16o// 9/~/81 Gyroscopic Gyroscopic Gyroscopic Job No. A1081GO052 Job No. Al181GO097 Job Moo A981GO014 D.S.13-9 L/ ril/i3/81 Single-Shot D.S.14-13~/I' 11/12/81 Single-Shot Job No. A1081DO088 Job No. A1081DO074 Please sign'an'd return the attached copy as receipt of data.. Ma'ry F. Kellis North Engineering Transmittal #'793 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA Company ,~ a Dlwl$,On o' ,',lla¢)hcR~chfleh3Compan¥ ARCO Oil Gas EXXON MOBIL GETTY MARATHON DECO 8 1981- CHEVRON AlaskaOil & Gas Cons. Commission Anchbrage Eastman/ Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ~RCO ALASK~ I~'~C. COMPANY DS 13, Well 5?umber: 9 WELL NAME Prudhoe Bav, !qorth Slope, Alaska LOCATION JOB NUMBER A1081D0088 SURVEY BY D Prescott TYPE OF SURVEY Directional Single Shot ~:~ ~ {~i ~'i i~'~, i,,ii::i: ~i~ ,' ,~ .. ~.., OFFICE Alaska DATE 13-Nov-81 0-302 ARCO ALASKA, INC, [iS 1~, WELl. NO~ 9 BSS F'RUI)HOE BAY, NORTH SLOPE:, ALASKA DSS, 0-'11417 ~-tD, DRIL. LER: D F'RESCOTT RIG.; ROWAN 26 ~_IECLINATION~ 30 1/2 DEGo EAST · VERTICAL SECTION CAI. CULATE[;~';IN PLANE:~.OF'-' PROPOSAL RE:CORD OF SURVEY .................... RADIUS OF CURVATURE METHOD "~RCO AL. ASKA, IN~:. :IS 13, WELL NO~ 9 DSS ;'RUI)HOE BAY, NORTH SLOPE, ALASKA JOB NO.* A1081DO088 F';:;GE NO . I TRUE iI:']ASURED DRIFT DRIFT L-:,OURSE VE'RTICAL VERTICAL suBsEA R E;'-C T A N G U L"A'R i" -C' L. 0 S U R E; .r~OG[...E~ DEF'TH ANGLE I)IRE:C'I'ION LE:NGTH Z[JEF'TH SECTION TVO C 0 0 R I) I N A T E: S DISTANCE DIRE:CTION SEVERIT'~ F E E T ZI ti D M F E E: T F E E T F' E E 1' F' E E T F' E E T F' F E T D i"l D G / 100 I:-- 1 ~ ............. O. 0 0 0 0 O. 0,00 ' 2440. I 0 S 42 0 E 2440. 2439.88 ~ ~. ' 250 ~:507. 1 0 S 61 30 E 02. 1.87 2679. 9 30 N 74 SO E 177. 2677.96 2741, 10 15 S 79 0 E 62. 2739.04 0.00 -78.00 · -:u. 97 ~361.88 ...91.9'9 .::"' 42 S. ,.,c; 7 S1 · 87 2599.96 37.14 2661.04 2834, 10 45 S 44 30 E 2927, 13 45 S 55 0 E . 3019. 15 30 S 53 0 E 3135 20 0 S ~") · . ,..,,:. 0 E 3286. 24 45 S 44 SO E 93. 2830.49 51.67 2752.49 93. 2921.36 70.46 ~.~°843,36 . . . 92. 3010.37 92.03 2 X~ 116. 3120.82 125.20 3042.82 151. 3260.41 .,180,40 S182.41.~ 0.00 15.82 S 16.48 S 18.27 S 17.86 S ~c~ 4'9 52.14 73.66 S 111.90 S 0.00 0.00 0 0 0.00 14.,-.. '~ 4 E ,_'.~ 1 · 2! 8S 4 '2 0 E 0 · 0 '1 15.09 E: 22,34 S 42 28 E: 0.55 30.77 E 35.79 S 59 18 E 4,98 41.30 E: 45.00 S 66 37 E; 7.3~; 56,01E 71,04 E 89,84 E 117,88 E 160,72 E 61.65 S 65 18 E 80.80 S 61 53 E 103.87 .... S 59 52 E 159.01 S 58 0 E 195.84 S 55 9 E 4 1.98 3.89 3.66 3446. 28 30 S 38 0 E: 3621. 36 0 S 37 30 E: 4.1.52. 40 15 S 37 SO E 4611. 40 15 S 38 0 E 5138. 40 30 S 37 30 El: 5954. 42 45 S 37 0 E 6808. 42 0 S 34 SO E 7833. 44 30 S 35 0 E: 7984. 45 30 S 35 0 E 8578. 41 45 S 33 30 E 160. 3;403,42-,'...~::,1.17 3325,42 165 77 S 207,97 E 265 95 S 51 27 E; ::~ :'=' 32 ="'~ ' - 239 55 S :~65 10 E 357 30 S 47 54 E; 175. ;:'.;~ 3,..,.,1. 344.06 ~;' '3;.473,32 531o';.:i:3968,94 L;670'44.;' 3890'94!"; 499.58~S- -464,62 E 682.24 S 42 55 E 4~,,9. .~ 4819.27 c',:,6,.,,64~ 4241,27 734.07. S 646.19 E 977.97 S 41 21 E : ; .; . ~., ~.,, 5"~7,..- .": 4720.7,5 1.7,05,44,; .:4642,7517100;:.$,99 S 8,.,,~.19 E 1318,84 ,_.q40 ,_,.,a:' E ,. , 796. ,,,_15 73 1832 13 5237,73''~ 'i~24 84 S 1175.20 E: 1846.96 S 39 31 E 874. 5961.39 ,._._"4"-'0 . 03,.,,8o3.39 190-°.85,, S 1~:'].9.32,: E 2434.99 S ~8 36 E 525. 6343.76 2779.38 6265.76 -.'"198.39. S 17-o4.34',. El 2793.97 ,.R 38 7 E 601. 6768.72. 3203.8':'~. 6690.72 ,.o,=;a~,.50 S lq'68.09, E S'~,,.18.,39 S 37 4~.'.-' E 644. 7234.R1~ 3647.80 71~".81,.,~., 2915.69 S ,..~:~18~. .10 E 3661.91 S 37 17 E . ...... · .. 2.96 4.29 0.80 0.07 0.08 0.29 0.21 0.48 0.17 0.~_, 8911. 38 0 S 31 30 E 9516. 33 0 S 30 0 E 10423. 3n~ 0 S '~4,. 0 E 1~,..,.1. 3a~ 15 S 73,. 0 E 11417. 27 0 S 19 30 E 333. 7490.32 3861.24 7412.32 3093.71 S 2332.79 E 3874.65 S 37 1 605. 7982.71 4212.33 7904.71 3395.53 S 2512.35 E 4223,93 S 36 30 E --~ -~ 907. 8747.65 4697 .....38 8669.65 ~8~9,54 R ~.~733.49 E 4705.04 S ~ 31 E 158. 8881.46 4780.42 8803.46 3906.59 S 2767.00 El 4787.25 S 35 19 E 836. 9607.92 5185.88 9529.92 4291.55 S 2916.70 E 5188.89 S 34 12 E .... . . 1 · 19 0.37 0.37 0.66 FINAL CLOSURE - DIRECTION~ DISTANCE S.34 OEGS 12 MINS 5 SECS E 5188,89 FEET ~RCO ALASKA, INC, i,c.'; 13, WELL NO; 9 DSS :'RUI)HOE BAY, NORTH SLOPE, AI..ASKA [l',,z T CHARI" S I:,.E.I...~,IE[ lqATA FILE JOB MOl AlO81BO088 ;URVEY FILE t4UHBER 190 DEF'TH 0,00 2440,00 3059~00 3346,00 3709,00 6014,00 6888,00 7681,00 ~576,00 10581,00 BOTTOH HOI. E ASSEMBLY VALUES USED FOR DEF'TH ARE MD DESCRIF'TION ANGLE BUILD ASSEMBLY 7 3/4 DYNA DRILL PACKED HOLE/SLIGHT ANGLE PACKED HOLE ASSENBL. Y .... PACKED HOLE ASSEHBLY PACKED HOLE ASSENBLY I';RILLING DAYS V~.~I...LEo L oE;] FOR DEF'TH ARE MD DAY DEPTH 1 6 7 8- 9 ].0 11 1S 14 15 0,00 2400,00 2400,C0 2502,00 S~8 ~,: 6,00 5138,00 6808,00 7333,00 8 ~ .~78,00 8911,00 9516,00 1058].,00 10581,00 1058].,00 11417,00 WE.'.IGHT ON BlT WFIGHT IS GIVEN F'ER 1000 F'OLINDS VALLIES USE:D FOR DEF'TH ARE MD DEPTH WEIGHT 0,00 2440,00 3059,00 3346,00 3709,00 6014,00 6888,00 7681,00 9576~00 10581,00 0,00 55,00 15,00 60,00 65,00 65,00 65,00 65,00 65,00 45,00 REVOLUTIONS F'ER MINUTE V¢~L. LIES USED FOR DEF'I'H ARE HD ]EJEF'TH R,F',H, 0.00 2440,00 3059.00 S346.00 3709,00 6014,00 6888,00 7'681,00 9576.00 :1.058].,00 0.00 100,00 0,00 100,00 140,00 140.00 140,00 140,00 J. 15,00 115,00 '-- RRCO RLRSKR, INC. iT:. :i :: ''? :.7':' --.--HORI:ZONTRL--~ROJECTION ..... DS 13, NELL NO: 9 DSS ' .... ~ ...... ~'. ~CRLE l1 IN. := 500'FEET p_RUDHOE 5RY, NORTH SLOPE, RLRSKR i ............ ! .... 13EP.TH .INDICRTOR:...HD - --'- 'i-: ":'.',!-:-.~ i'-'::--:-'t :.' .... i''~''''' t':- :';w'.--: ..... ~ ....... . .... i .... I WHIPSTOCK, INC. i' ~: I ;'1';.].1 L''i:;;'. ' ;..~i: '.; . , I , STRTION: i ~ " DEPTH 1141'/ HD.; TVo 4291 55 ERST 2916.69' · ''' [ '' CLOSURE5188.88S 34i12 5 E ' · !: ...... L'_! ,t- I ~"':: i ' ARCO ALASKA, INC, : ........ ~BUDHOE BAY, NORTH SLOPE; RLRSKR ...~ . ~ ...... '' ' SCALE. . :! IN. =..lO00 FEET· ......... .~ ............. ~ .............. .... i--.~.i-'::':i":'-'::- t'":':":'f:.' ..... :':'"": ' ~ 'i'.' ........... ........ ERSTHRN WHIPSTOCK; INC. ' ...... 1 ......... ~. ,, ..... ~.., ..., .... , -~-. :::! ~ '"..l .... .j:':'j' 'k': .i · :: i.~: i:.:-.-' ~ "",--'i :-:FT:-TT'7'-t .':. !i:'!': i;--':']. ::' '!. _i[i-;! "'t:'-:":' ~: :--F F.'--.:?!.:. : :-'.':'_"..:'.:,. :_ ---:: :1':-'-:::-~.:..: :.. :--I.-.: ;.i.i: ~.-t-i:i:::.i. P-:.-= .... ~:i:.t-:.::::-.q-: :%.-. :-:'~;-!-7-;'..-x.--F.~: · ':u'":::"t ::::7[: '.::.:~ i']":"t':'::,..::l:::.::::Ff-::.-:::: ::::':Ff?::.:F::t:':':.:.t':;'::::t'?~i:?:':::_:-t::_:'::!':'.:::.~:_-:.:::,. .-. '_~.....L_LB__..ZL. _O-.4..' ...... : '.', ~: .7';' .2 -".':" ~': 1.: ;"' , ' 7 .... ; .... ;..LL--_ ' .~ ....~.'-~_L~__ :' ' - ': ;':'; :, ~'.: .: .: '. _. :' ;' -;.:..: .'. ;TL':;'__'-_ :::L::;:' .-;::;':::~'_.2t_%"'_' :':; :;::Lt'..:' ;-;:;'..: .:·':;.:. t' i; .:' :'._- :': ·; :': ?..;_'-.'.L .: :..: :':,: · · [ .... ', ..... i .... :..;-: ...... ;.-: ....... : ............... Z_: .............. ~ .......... i ......... ': ........ looo ...... --~ ......... ,-"-: ": -" :: ': ......... : ...... . ': ·. ..... ,-_u_-' '.J ..... ::~-_.t ........ :_._ -.:-::.:i-~:~:?::''::-' t-":-.: :--:...--._¢~:~i.~:?"-':. ::-F.':'..?--''- .:::.:?--.-.i~F:i"i'-'i'i:'i~ :'-:" :'..'--:.--~: :.'-.'['.:. :~: '-..;:.; :-":_-:.:.t~ .-:.._*:-:-,-, .'-::,~ .:-:__~-:_-.*,:,:'_: '.-'-:.: ..... ::;-;:~: t:::':;.,i- ' :.'::--i:: ~¢~,,"::!::!-?.: ~'.-.'.'..:=! :.-~'?,.'~':I..': :=.i,::: .... ~ ' :",! I: .: :.:'F:-::'i.':-~': I.: ~.: i: ;i :. ....................... ~ ......... :..i..: '": t:' ] ............ · I 2834 9000 · . L;': 10000 ,. November 17, 1981 ARCO ALASKA, INC. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: DS 13-9 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Directional Single Shot Date: 13-Nov-81 Method of Computation: Radius of Curvature Surveyor: D Prescott Job Number: A1081D0088 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Directional Single Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, District Directional Drilling Coordinator RJ/bb cc: file enclosure Directional Drillers/Sub-Surface $,:~rveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO Oil and Gas( .... mpany . .+,. No~.n Alaska C, is~ric~ ;:ost O;[ice Box 3fO Anchoraoe. Aisska 99510 ,. Teieohcne 907 277 5~37 Jerry A. Rochon ~istrict Opera~ions Engineer December 3, 1981 Reference: ARCO CASED HOLE FINAL D.S.13-9 11/17/81 ACBL/VDL Run 1 5" Please sign and return one..of the attached copies as receipt of data. Mary F'o Kellis North Engineering Transmittal #792 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER O&M GEOLOGY STATE OF ALASKA GaS Co:' )arty ~s a O~,'~s~on O! Attar~ticRIdhf,~:idCompany EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company North Alaska' 'strict Post Oflice L,_,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 20, 1981 Reference: ARCO M~NETIC TAPES & LISTINGS D.S. 11-3 11/15/81 Tape #62314 D. S.9-4 °z/ 10/18/81 Tape #62241 p.s.9-5 11/8/81 · D.S.13-9~ 11/13/81 Tape #62307 Tape #62311 Please sign and return the attached copy as receipt'of data. Mary ?, Kellis North Engineering Transmittal #762 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON ,STATEOF ALASKA :,~ CHEVRON ARCO Oil ancl Gas Company is a IDiws,(~n o~ AtlanhcR~chlielelCompany ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton//~ Chairman Thru: Lonnie C. Smith Commissioner Bobby Fost er-~,.~ Petroleum Inspector November 3, 1981 Witness BOPE Test on ARCO's DS 13-9 Sec. 13, T10N, R14E UM Permit #81-158 ~g....nday November~2,__ 198! - The BOPE test began at 11:30 a.m. and was completed at 3:30 p.m. As the attached BOPE inspection report shows there were two failures. ~;o flanges leaked. These were tightened and tested. In. summary I witnessed the BOPE test on ARCO's DS 13-9. O&G #4 4/80 STATE c)[: AI,ASKA AIJ~SKA OIL & GAS CO;;t~ERVA'rIO;I COt,[IlSSION B.O.P.E. Inspection Report Inspecto Operator I.->'. 1'3 Well ~ ~ ~o~a~o.: Sec Drilling Contractor W. ell S~gn_. General Housekeeping Rese rye' pi t · . . ~/~'. ,' BOPE St.ack Annular Preventer 'Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve. ' 1Test~,~OPressure ACCUtlULATOR SYSTEH ~2~ ~..,~ '(D ps ig Full Charge Pressure ....~ ~ressure After Closure / ~?~ psig 2'00 ps ig Above Precharge A'ttained: min~:'.~': Full Charge Pressure Attained: '~ min~ ~ ' , ~ ,~ , Cont.rols: Haster, Remote~~ B:l_i:ds switch / Kelly and FlOor Safety Valves Upper Kelly. / Lower Kelly / Bal 1 Type / Inside BOP / Test Pressure - Test Pres sure ,_3 --" · Test Pressure Test Pres sure ~'~.b~ NO. Valves /-5' ~IN°' fl'anges ,f~ I ~ Adjustable Chokes / ~' I ....... '~ j~.,~:~u~c~,~ o~r~? ~,o~ FailUres ~- Test Time >' hrs. Choke ManifoldLF c~ Test Pressure ! Kill Line Valves Check Valve Test Results: Repai~-or Replacement of failed equipment to be made within . Inspector/Commission office notified. ~c~ ~<Ze ,..:~ ~J::. ~ .... ~' ' t ~'' ~' '; ' l ..... /'?o.5 / / days and Distribution orig'] - AO&GCC cc - Operator cc - Supervisor Inspector · ~ t" "~,' i/ ' . I October 23, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Prudhoe BaY Unit DS 13-9 ARCO Alaska, Inc. Permit No. 81-158 Sur. Loc.: 1290'FSL, 155'FWL, Sec 13, TION, R14E, Bottomhole Loc.: 2215'FSL, 2385'FEL, Sec 24, TiON, R14E, UM. Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the above referenced well. Well samples.amd a mud log are mot required. A. continuous directional survey, is required as per 20 AAC 25,050(b)(5). If available, a tape containing the digitized log information shall be submitted .on all logs for copying except exper~imentai logs, velocity survey.s and dipmeter surveys. Many rivers in Alaska and their drainage systems' have been classified as important for the spawning or migration of anadromous fish. Operations in these areas .are subJe, c~ to AS 16.50.870 and the regulations promulgated thereunder (Ti. tlc 5, Alaska Administrative Code.). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department .of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and 'by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Prudhoe Bay Unit DS 13-9 -2- October 23, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this, office adequate advance notification so that we may have a witness present. Very truly yours., Hoyl M. ttamilton~Y OR~gER 0}': "fi.liE C,.,~.~t,.~3olON Chairman of Alaska Oil & Gas Conservation Commission Enclosure cc: Department of Fish & Game,: Habitat Section w/o encl. Department of Environmental Conservation w/o/e, ncl. HRH~be ARCO Alaska, Inc Post Office iii 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 16, 1981 Mr. Hoyl e Hami 1 ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 13-9 Permit to Drill Dear Sir: Enclosed please find our applicat'ion for Permit to Drill DS 13-9 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore, a proximity plat showing the subject wellbore's position to the nearest well drilled, and a sketch and description of the BOP equipment and testing procedure, including anticipated pressures. As we anticipate spudding this well on or around October 26, 1981, your prompt review of this application would be greatly appreciated. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/JBK:lb Enclosures ,q~C(~ Atask~, ~r~c. is e subsidiary o~ AHanticRichfieldCompany "¢' STATE OF ALASKA ALASKA(..,IL AND GAS CONSERVATION C ,,,MISSION ' PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENTOILX[] SINGLEZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360 Anch..o_.._r_._a_Qe, Alaska 99510 4. Location of well at surface ~ _F ~, C J V ~)ffnit or lease name 1290'FSL, 155'FWL, SEC. 13, TION, R14E, U.M. Prudhoe Bay Unit _10. Well number At top of proposed producing interval OCT 20 I9~ DS 13-9 2665'FSL, 2660'FEL, SEC. 24, TION, R14E, U.,M.. At total depth~Ska 0i~ & (~s O0r/s, (~ 11. Field and pool 2215'FSL, 2385'FEL, SEC. 24, TION, RI4E, U.M. Anc.~ora~ '°~r~~e Bay Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Prudhoe 0i 1 Pool 78' RKBI ADL 28315 12. Bond information (see 20 AAC 25.025) TvpeStatewide Surety and/or number Fed. Ins. Co. 8080-26-27Am°unt $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed l½ NW of Deadhorse, A~[i~es 2215 feet well 1300' SW DS 13-7 feet 16, Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date ll406~TMD 9635'TVD feet 2560 October 26, 1981 19. If deviated (see 20 AAC'25.050) 12o. Anticipated pressures40nopsig@ - Surface KICK OFF POINT2500feet. MAXIMUM HOLE ANGLE 40 oI (see 20 AAC 25.035 (c) (2) 4696 psig@ 96.'~.1~ ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30 20 94 H-40 PEB R-3 0 I 0 llO I lqO 250 PFII tn Surf. ._ ]_72~ __ _1_3_ 2u~. 72 L-80 Bu'tt, R-3 0 ~ ' ~ 0 .24001 2400 2300sx. Fo~du~40_.0_s_~_.?_F 12~ 9'"5/8 47 L-80'$ Butt. R-3 0 ' 0 104601 8902 250sx G- 1st Stage I ' 9 5/8 47 ~00 95 Butt. R-3 ~ I 300sx. PFII 2nd Stag~ 8½ 7 29 L-80 Butt. R-3 10160 ~, 8669 1140611 9635 750sx. Class G cmt. 22, Describe proposed prograph: ~RCO Alaska, Inc. proposes to directionally drill this well to ll,406'MD (9635'TVD) to pro- Juce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi qSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be .press- Ire tested each week thereafter. A string of 5½" 17# L-80 tubing, packer & necessary }rovisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the ~adlerochit. The downhole safety valve will be tested and installed upon conclusion of job. ~OTE' Permafrost base at DS 13 is'1850'TVD. ~Bottom hole pressure based on virgin reservoir pressure. Surface pressure calculated with ]nexpanded gas bubble at surface including temperature effects. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED .~__~ '~~ TITLE District Drilling Eng. DATE The space below for Commission use CONDITIONS OF APPROVAL Samples required 1--Mud log required Directional Survey required APl number i-lYES ~O OYES .~.~0 .~ES r-INO 50_ O ~_ Z~G -~) Permit number Approval date ~/l-'/~"~ SEE COVER LETTER FOR OTHER REQUIREMENTS ~0/23 / 81 - . APPROVED BY COMMISSIONER DATE _C~_.tO__~:w' 2~: 1 bY order of the Commission ¸II ' Form 10-401 Submit in triplicate Rev. 7-1-80 I, . , .... J:~JR CO _.~ KA.,.'~I~ N C.- .......... I ....................... t ~ ........................ t ! ......... ! ..... i ......i ........... '.. '-'DS I8,~ NELL~NO: ~ PROPOSED ! .... ~ .... I .... ~'' ~ ...... i"' ~'' :: PRUDHOE BRY,~ NORTH 'SLOPE. RLR~R: ......... ; 00 .... '3533 3706 ~ L ...... L-, ~377 .. 13-5/8" STACK DIAGRAM Accumulator Caoacit¥ Test RNNULRR PREVENTER BL I ND" RRMS · e e e Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed wi th charging pump of f. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi ; remaining, pressure.) PIPE RRHS ) SPOOL · e 13-5/8" BOP Stack Test Fill BOP stack and manifold with a non- freezing liquid. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. · Close annular preventer and chokes and bypass valves on manifold. PIPE RRHS ~6~,- Maximum Anticipated Bottom Hole Pressure, psi. z4000- Maximum Pressure to which BOP's could be subjected. Calculated by allowing a gas bubble e In each of the following tests, first hold a .250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. · Increase pressure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe '-rams. Increase pressure to 5000 psi & hold for -at least 3 minutes. Bleed pressure to zero. 7. Cl'ose valves directly upstream of chokes & open chokes. Increase press, to 5000 psi & hold for at .least 3 min. Bleed pressure to zero. 8. Open top 'set of pipe rams then close bottom set of-pipe rams. Increase press, to 5000 psi below the bottom set of pipe rams & hold for at least 3 minutes. .9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. ll. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. at reservoir pressure to 14. Test Kelly cocks and inside BOP to 5000 psi rise w/o expa~nding but with Koomey pump. cooling to 80VF,~~ V~O ' ~ 15. Check operation of De Gasser. OCT~o'O I~8] 1_6. Record test information on Blowout preventer 'N~kao/l&~a~Oons. Co~rn test form. Sign and send to Drilling Super. ;qnchorage i~.~ Perform complete BOPE test once a week and functional operate BOPE daily. ...... " EREBY CERTIFY THAT -I AM ~~',//"-""'~(;;-,~.,,r... '"'! / .( .... '"'Io')PERLYPRACTIcEREGISTEREDLAND SURVEY ANDiNGLICENSEDiN '~ . THE STATE OF ALASKA AND THAT , L THIS PLA]' REPRESE~ITS AN AS- ~ " '~' %~ \ BUILT SURVEY MADE BY ME, AND ',~.. DATE: ,.././/I}-."- .:, ' 2" ' '-' .,. ' Z ,- \ . t..r'.r.. '-'.~." ~...? ..~: \ ,. ,:_- ....... '..,.~ ,..:~ ~ \ ' .,.::,:.-... , ~' ,g, .:., . -D ~ ',, '"":' .. ' .... ' ..,,~ __~__~ ~.--~'-'"'- '~" " .::"~:,.",i',, -"' ..?- '~'l~;~O, ----'~~~'10' ..._____~~~. X' ' - -~0~1~ . ', .. · . 14 :24 (-rlo., D.S. ]3 CONDUCTORS ~;-]O F.. Y = 5,9.3] ,829.06 g. Y = 5,93] ,~7~.~,z~ .... x = 68,7,276.57 x = 687, 359. ~,A LAT = 700]3'07.065'' LAT = 700]3'03.60]'' LONG = ]~8°29'20.?~7" LONG = ]~,°,°29']g, . .092" 6. Y 5 93] 712..29 9 Y 5,931,3(~].37 = ~ ~ . = :,i.~., x = 6,~7 3o~, o~, x =6~7,387.57 LAT- 7o°]3'0:5 9]oi' LAT = 7oO]3 O2.L~39,, LONG = ]b, 8°2~)'20. ]3~" LONg = ]~2'°29' ]7.cj0]'' :~ ~.~ ;.,.~ ~,.~ · ,.... x = 687,33].97 x = 687,z+] F. 7] LAT = .7o°]3'o~ 755" LAT = 70°]3'O] 290" LONG- ]~8o29,]9.~07,, LONG = ]~,8o29,]7.228', .~. i i ii iii i i iii II _ ii 12~lbL Z?IT~ I:::z2 ~ WD/~L~ ~--- ~O LOOATION A&'f~ClILT · I iii I AllanlicRichliel'dCompan¥ ~ DATE. DRAWING No- NORTH AMERICAN PRODUCING DIVISION io.~Z.~o ALASKA DISTRtCT-PRUDHOE BAY' i i ...... i iL i i I L i CHECK LIST FOR NEW WELL PER>IITS Company ~P~&",,.~ Lease & Well No. f~ ~ · ITEM APPROVE DATE (1) Fee (2) hoc~~.'~ .//2 thru 8) (3) Admin ~ thru (4) ~asgd~jP-~ ~ 1~2 thru %21 thru 24) (6) 2~ 3. 4. 5. 6. 7. 8. 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 1'9. 20. 21. 22. 23. 24. 25. YES NO Is the permit fee attached .......................................... ~_ Is well to be located in a defined pool ............................ .~ ~ Is well located proper distance from property line .................. /~ Is well located proper distance from other wells .. Is ~ufficient undedicated acreage available in this pool ........... [f2~-~_~ Is well to be deviated and is well bore plat included ... i~ Is operator the only affected party ................... Can permit be approved before ten-day wait .... ~_ Does operator have a bond in force .................................. (~jz~_ / Is a conservation order needed ........................................ · Is administrative approval needed ................................... -- Is conductor string provided .................................... .. '"~ 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 .................... '~27~ ' Will surface casing protect fresh 'water zones ........ , ....... Will all casing give adequate sa.fety 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 ............ ' ~q/ , Is adequate well bore separation proposed .......................... ~- Is a diverter system required .......................... ' .......... ~ ____ ~ '~-~ oO,/ Are necessary diagrams of diverter and BOP equipment attached ...... Does BOPE have sufficient pressure rating - Test to ~-~>c>O psig Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. ~LJgrZ~~/~2'C--~ Additional require~nents ............................................. ~_ REMARKS Additional Remarks: Geol?~7: Engineering: HWK LCS ~ ,~.. BEW WVA ~,:>?i,,'!? J KTJ.~RAD JAL ~-_- / /' rev: 03/10/81 INITIAL GEO. UNIT tON/OFF POOL CLASS STATUS AREA NO.I 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 APPE .N. DIX~ ., No Special'effort has been made to chronologically organize this category of information. LVP O09.Hob VERIFICA'riO~; blS'I'i:~G PAGE ,, R ~; C O, P, ,L',: T¥ P g 0 47 '~ * UbiIT TYP~ CATE SIZE CODE 000 000 026 065 000 000 008 065 000 000 012 (}65 000 000 003 065 000 000 003 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 004 065 U t41 T T ~'P ~; C A T E S I Z ~ C 0 O E 000 000 007 065 DIb kd'i ~1, [,GGGED 11406 FiY. 2350 ,~ t. 1,3.38 I;,i. t~ 2424 !.7,25 I ~',!. LIGNO- : 9.7 41 =1,1 6.6 )viL 2.37 ~' gO 2.54 ,9 78 F 2.?3 ~ 80 ~' .98l,, t~ 203 ~ bV~ 0.')9.1.{05 YERIF'iCATiOi',~ blS'ili~'G PAGk 3 TYPE SIZE 0 ~ P ':t,' Y F REPR CODE 66 FiLE N 0. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Si 1 6O · 11 N 0 PROCFiS.,5 0 0 0 () 0 0 () 0 0 0 0 0 0 0 0 0 0 0 0 SAMPL~ 1 ! 1 1 1 I 1 1 1 1 1 ! 1 REPR CODE ~8 ,, o A":i: DEPT SP ii, 443.000 -999.250 -999,250 Ri'lOB -999. 250 'NRAT -999. 250 -999.250 -99~.250 -999.250 -999.250 -999.250 ';~! 0 3'75 (,:; R -999. 250 73.i88 -999.250 -99'J. 250 -999.250 469 0 0 0 l L F' C N 6 i bi,,) G~ -999.250 88.625 -999.250-999.250 4.676 91.938 ........ DEPi' SP GR SI.::' G~ DEP 'ii' SP GR NPN i SP GR D E P T DEP%' Gk D a P I' Ge -41.0s3 20.990 -999. 250 i1200.O00 -69. 500 :26. ~ 07 37.3:1.2 -999. 250 1.tOOO.OOu SFbi; -73.250 GR 22. 070 Rhd~3 -"'999.250 NRA'"f 700 . 000 -18. 125 29.346 1. I a. 125 20,,703 1, 05 (,~ 0. (i 00 o' .... p, ,,.,..,r i,J' '-',,~. 12 . 43 ~ GR ;, i S Ti N G 2.201 2.740 13. $ 4 t 45.969 2, .i8 ~.'. 2.16. i -999.25O 34,.7~1 2.35'7 2.54':,9 -999.250 5.348 19.203 2.318 Z.564 -999.250 il.766 19.938 2.359 2.207 -99'9.250 /5 . 4,55 25.703 2.283 2.6,0q~ -999. 250 11,617 24,922 :2, '260 2.499 2. 770 ~.539 93.563 2.590 2.531 2.475 3.500 0. i, 50 51.250 i') f 9k HO i £, OT l b M DRBO I L ?, D '27 3 ,.,~. U -99q. 250 19.164 72.750 '~. 003 400 (,. 0 00 -999.250 4.059 0.002 3365.000 -99.,,.250 2.4(t4 87.750 -O.005 317%.000 '99~.250 5.336 72,375 0.012 3510,000 -997,250 2.285 85.750 29"14.00G -999.250 1, (,,~. ~} 41 89. 375 -0.0 () F, 8 ~!:. 000 37.53i 7.434 2366.000 11!.875 ! 97.375 0.040 0 9,00 (? 97,563 2 000. (} 0 (.! 55.1 8 [; C A I., I P C H L I .~.~ [) f" fl i't h IL t3 CAI, I l L, CALl ['"' C t',! L C A 1,, i FCNh I b D CADI FCNh CALl 1 b P C il, L I F'C I.,:,~ L, I L D CAL:I ~'CNb i L G P~GE 6,617 i06~.000 ~0.086 37,906 8.797 1846.000 3.727 26.094 8.75~ 13~4 000 2.102 22.391 8.578 1294.000 4,727 24,344 8,453 1532.000 1.938 29,359 8.648 1170,000 11.898 24,781 8 969 7.324 103.250 10,383 966,000 1.658 87,750 12,266 597,000 7.14 ~ 50. 188 GR NPh Z ,.S? GR SP GR NFL 1 D E i::'~ SP N P DEP'i' NP~i GR NPhZ DEPT SP NPF~ i N P H I D E I;' T SP OEP?' SP DEPT SP NPh ~.. -999. 250 RH()D 10e, O0. C) Ou S "qq9 2,',60 -999. 250 -~99,250 4.5,26~ NRAT 10300.000 SFLU -999.25(; dR -999. 250 RHOE. -999. 250 51.758 () 200,0,00 S F [., u -999.25O GR 999,250 RHOt3 ~ 999.25 u ~ k A'r 49,7 0 '1 ~,'~ ~,: ,A '~," 000.000 8 F L, U -999,250 G~," -999,250 }~ b{ !r'] J;3 999 2~'0 N'RAT 9900.000 $ [.," L, U -999 ,, 250 -~99. 250 P, HOb -999. 250 fq b',, A T 43.99% 97' 00.000 $ F ~,~ U -' 999,250 6 R -999. 250 [4NOB ',-999.25() NRAT 4~. 38b ?~RAT 9600.0 O' (',! S F L '!,,~ -999.25U -999.250 -"¢9'9.250 -999.250 -999.25(,, ' 99':,,t:. 2~0 3.8 ,"i; 7 -q99.2~0 -999.250 -99~.250 -999.25(? 4.242 -999.250 -999.25U -999.250 -999.250 %,129' -999,25(i -999'250 -99~ 250 ~.~ ~,: -999,25C? ~.332 -999,, :250 -9'~'9. 250 -999. 250 -999.250 4,. C) 5 t ,g ,q lbiv, DRHO C R I L ? 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