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181-014
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250910 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 213-26T 50283202040000 225038 6/14/2025 AK E-LINE CBL MPU C-21 50029207530000 182081 7/8/2025 AK E-LINE Caliper MPU M-62 50029237440000 223006 6/23/2025 READ Caliper Survey PBU 01-13A 50029202700100 225052 8/17/2025 BAKER MRPM PBU 01-30A 50029216060100 225050 8/7/2025 BAKER MRPM PBU 07-24A 50029209450100 225045 8/3/2025 BAKER MRPM PBU N-12 50029205570000 181014 8/5/2025 BAKER SPN PBU PSI-09 50029230950000 202124 7/17/2025 HALLIBURTON WFL-TMD3D Please include current contact information if different from above. T40860 T40861 T40862 T40863 194-080 T40864 T40865 T40866 T40867 PBU N-12 50029205570000 181014 8/5/2025 BAKER SPN Gavin Gluyas Digitally signed by Gavin Gluyas Date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y Samantha Carlisle at 3:19 pm, Apr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roperty Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU N-12 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 181-014 50-029-20557-00-00 Conductor Surface Intermediate Production Liner 77 2644 9208 1316 20" x 30" 13-3/8" 9-5/8" 7" 38 - 115 37 - 2681 35 - 9243 8744 - 10060 38 - 115 37 - 2681 35 - 8519 8085 - 9253 None 2670 4760 7020 5380 6870 8160 9487 - 9750 4-1/2" 12.6# 13Cr80 33 - 8791 8734 - 8972 Structural 4-1/2" Baker S-3 Perm Packer 8650 8650 8002 Stan Golis Sr. Area Operations Manager Wyatt Rivard wrivard@hilcorp.com 907.777.8547 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028282, 0028283 No SSSV Installed 33 - 8126 8002 N/A N/A 314 337 11047 22950 7420 5916 1996 1730 290 1096 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 10060 9253 9617 8852 9617, 9627, 9659, 9665 By Samantha Carlisle at 12:55 pm, Oct 19, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.19 12:15:28 -08'00' Stan Golis (880) RBDMS HEW 10/19/2021 10,070 MGR19OCT2021 SFD 10/20/2021 SFD 10/20/2021 9,270 DSR-10/19/21 ACTIVITY DATE SUMMARY 10/10/2021 ***WELL S/I ON ARRIVAL***(drift eline) DRIFTED 10' 3-3/8" DUMMY GUN(3.66" od) TO T/D @ 9593' SLM/9634' MD ***WELL LEFT S/I ON DEPARTURE**** 10/11/2021 T/I/O = 1940/1963/322. Temp = SI. TBG FL ( E-line request). ALP = 2100, SI @ CV. TBG FL @ 7656' (134' below sta#2 DMY, 116 bbls). SV, WV, SSV = C. MV = O. IA & OA = OTG. 08:00. 10/11/2021 ***WELL S/I ON ARRIVAL *** JOB SCOPE: PERFORATE DHD SHOT FLUID LEVEL @ 7656' RUN 3-1/8'' X 10' GEO RAZOR PERF GUN. 6-SPF 60 Deg PHASE CORRELATE BY BAKER RPM 3D LOG DATED 26-OCT-2018 TAG TOC @ 9631'. SHOOT ADDPERF'S FROM 9487' TO 9497'. CCL TO TOP SHOOT=9.7' CCL STOP DEPTH=9477.3' NO CHANGE IN TBG PRESSURE. ***JOB COMPLETE / TURN WELL OVER TO POP*** Daily Report of Well Operations PBU N-12 STATE OF ALASKA4.`;; "`t9 ALASKA OIL AND GAS CONSERVATION COMMISSION L `e..0 e... at '�" E: D REPORT OF SUNDRY WELL DPFRATInIdC 1. Operations Performed A re 6 2020 Abandon ❑ Plug Perforations M Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate R1 Other Stimulate ❑ Alter Casing ❑ ChangeA ❑ Plug for Rednll ❑ Perforate New =srr Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: e - 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 181-014 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20557-00-00 7 Property Designation (Lease Number): ADL 028283 8. Well Name and Number: PBU N-12 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. FieldlPools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10070 feet Plus 9617, 9627, 9 measuretl 9659, 9665 feet true vertical 9262 feet Junk measured None feet Effective Depth: measured 9617 feet Packer measured 8663 feet true vertical 8852 feet Packer true vertical 8014 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 77 20" x 30" 38-115 38-115 Surface 2644 13-3/8" 37-2681 37-2681 5380 2670 Intermediate 9208 9-5/8" 35-9243 35-8519 6870/8150 4760/5080 Production Liner 1316 7" 8744-10060 8085-9253 8160 7020 Perforation Depth: Measured depth: 9588-9750 feet True vertical depth: 8825-8972 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.0 13Cr80 33-8804 33-8138 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 6663 8014 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 98 2267 4653 1521 193 Subsequent to operation: 669 3942 6813 1724 235 14.Attachments (reguired per20 rine 25o70.25.071. a 25.293) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Wellman, Julie Contact Name: Wellman, Julie Authorized Title: Production Engineer Contact Email: Julle.WellmanCbp.com Authorized Signature:/—� Date: 1 Contact Phone: +1 9075644657 Form 10-404 Revised 04/2017 U��0, �� M6iwW_T N�k7 ';gD�$ JAN 0 7 2020 Submit Original Only 12/10/2019 **'WELL SHUT IN ON ARRIVAL*** MIRU HES ELINE UNIT 4863, DRIFT W/ 2.66"x21' DUMMY GUN TO 9630' ELMD. BEGIN PUMPING 1% KCL INTO WELL. ***JOB CONT ON 12/11/19 WSR*** ***JOB CONT FROM 12/10/19*** PERFORATE 9588'-9608'W/ 2.5"x20', 6 SPF, 60 DEGREE PHASING HSC LOADED W/ 2.5" MI SET HES 1.69" TTBP ME AT 9627'. LOG CORRELATED T HOLE COMPENSATED SONIC LOG DATED 29-MAY-1981. 12/11/2019 ***JOB CONT ON 12/12/19 WSR*** ***JOB CONT FROM 12/11/19 WSR*** (eline - dump bail cement) COMPLETED THREE 2" X 40' CEMENT DUMP BAILER RUNS, PLACING CEMENT ON TOP OF HES TTBP AT 9627' ELMD. (16 GALS) ESTIMATED TO AT 9,617'. ***WELL SHUT IN ON DE A TURE, AT REQUEST OF WELLS GROUP, NOTIFIED DSO NOT 12/12/2019 ITO POP THE WELL FOR 72 HRS*** 9-98' CSG, 47M, L-80 HYD 563, D = 8.681' I 13-3/8" CSG, 729 L-80, ID = 12.347' 2680' Minimum ID = 3.725" @ 8779' 4-1/2" HES XN NIPPLE I TOP OF 7" LNR I 4-12' TBG, 12.611, 13CR-80 VAMTOP, .0152 bpf, D = 3.958' 9-5/8' CSG, 47#, L-80 BUTT, D = 8.881' PBTD 6.184' N-12 SAFETY NOTES: "'4-12" CHROME TBC*" GAS I FT MAMIRR C 5T PERFORATION SUMMARY ND DEV TYPE VLV REF LOG: SWS-BHCS ON 0529/81 POR! DATE ANGLE AT TOP PERF: 25° @ 9588' 3391 Note: Rebrto Production DB for Nstodcal perfdata MMG DOME SIZE SPF INTERVAL NS z DATE 2-12' 6 9588 -9608 O 1 2/1 12 01 9 3-318' 6 9631-9646 C 0126/10 3-3/8' 6 9670-9690 C 0320/09 3-1/8' 4 9678-9700 C 0320/09 3318' 6 9684 - 9700 C 11/09/08 3-318" 6 9713 - 9730 C 11/09/08 33/8' 12 9713-9750 C 01/13/96 PBTD 6.184' N-12 SAFETY NOTES: "'4-12" CHROME TBC*" GAS I FT MAMIRR C 5T MD ND DEV TYPE VLV LATCJ-I POR! DATE 4 3391 3385 14 MMG DOME RK 16 08/03/08 3 6024 5715 33 MMG SO RK 20 08/03/08 2 7522 7009 26 MMG DMY RK 0 07/02/08 1 8558 7927 28 MMG OW RK 0 07/02/08 HES X NP, D=3.813' X 4-12" BKR S-3 PKR HESX NP, D=3.813' HES XN NP. D = 3.72 TTBP PLUG DUMP BAILED CMT (10/27/18) 7" POSISET PLUG (1026/18) DATE REV BY COMMENTS DATE REV BY COMMENTS 06/0281 ORIGINAL COMPLETION 04/04/12 RLW/JMD PERF DATE CORRECTION 071MB N4ES RWO 04/18/18 JW/JMD PERF SYMBOL CORRECTION 1020108 PJC DRAWING CORRECTIONS 11/06/18 BTN/JMD SETPOSISETPLUG/CMT 1121/08 TFARLH PERFS (11109108) 01/0220 BTN/JMD SET PLUG&CMT(12/12/19) 0329109 JKD/PJC PERFS 0320/09 02/03/10 JEDIPJC PERFS (0126/10) PRUDHOE BAY UNIT WELL: N-12 PERMIT No: 1810140 API No: 50-02320557-00 BP Exploration (Alaska) • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,April 29, 2018 1:13 PM To: Regg,James B (DOA) Cc: Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information Subject: UNDER EVALUATION: Producer N-12 (PTD# 1810140) sustained OA casing pressure above NOL external-email: 0 Mr. Regg, Producer N-12 (PTD#1810140) was made Under Evaluation recently to put on production and monitor the success of a Well Lock downsqueeze performed on the OA.The well was brought online on 04/26/18. On 04/28/18 the OA pressure rapidly increased to 1850 psi.The well was shut in and annuli pressures bled down.The well will remain shut in until a Town Engineer can evaluate if another repair option can be executed before the well is secured with a plug. Please respond with any questions. Andrew Ogg SCANNED Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 From: AK, GWO ell Integrity Engineer Sent: Tuesday, Apr 4, 2018 3:27 PM To: AK, OPS EOC Specia' s; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC •, Lead; AK, OPS Prod Controllers; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad •a, 'K, OPS WELL PADS; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES •: East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Bergene, Matthew; Frankenburg, Amy; Drau• ••n, Austin; 'Regg, James B(DOA) (jim.regg@alaska.gov)' Cc: AK, GWO Completions Well Integrity; AK, G b /HD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Informatio , 'K, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; '•bent, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, L. A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; 'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Producer N-12 (PTD# 1810140) POP to ..onitor OA pressure post Well Lock down squeeze All, Producer N-12 (PTD#1810140)was made Not Operable on 02/20/18 for having unmanagea• - bleeds to keep OA pressure below NOL.On 4/08/18 Special Projects performed a Well Lock down squeeze on the • The Well Lock has had sufficient time to cure.The well is now classified as UNDER EVALUATION to monitor the succes if the down squeeze. Plan forward: 1. Operations: Put on production 2. DHD: Monitor outer annuls pressure 1 i • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, April 24, 2018 3:27 PM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W; AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOp5ProdEOCTL; Bergene, Matthew; Frankenburg,Amy; Draughon,Austin; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A;Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer N-12 (PTD# 1810140) POP to monitor OA pressure post Well Lock down squeeze external-email: 0 All, Producer N-12 (PTD#1810140)was made Not Operable on 02/20/18 for having unmanageable bleeds to keep OA pressure below NOL. On 4/08/18 Special Projects performed a Well Lock down squeeze on the OA.The Well Lock has had sufficient time to cure.The well is now classified as UNDER EVALUATION to monitor the success of the down squeeze. Plan forward: 1. Operations: Put on production 2. DHD: Monitor outer annuls pressure 3. Well Integrity Engineer:Additional diagnostics as needed Please respond with any questions. Andrew Ogg r p� Well Integrity Engineer SCANNEQ ., BP Global Wells Organization-Alaska Office:907-659-8110 From: AK, • Well Integrity Engineer Sent: Tuesday, ary 20, 2018 3:02 PM To: AK, GWO Well Integr •ineer; AK, OPS EOC Specialists; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 "- _-. Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad MN; Ak, Ops West Area IL; AK, RES GPB East We = ngr; AK, RES GPB West Wells Opt Engr; Bergene, Matthew; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Inte• • AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, : • A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewit , :eau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; 'chris.wallace@alaska.g• 'K, GWO Well Integrity • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, February 20, 2018 3:02 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad MN;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J; Wallace, Chris D (DOA);AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Producer N-12 (PTD# 1810140) Unmanageable OA repressurization when online All, Producer N-12 (PTD# 1810140)was made under evaluation on 1/23/18 for having sustained outer annulus casing pressure above NOL. Attempts to bleed the annulus while the well was online resulted in rapid repressurization. At this time the well is reclassified as Not Operable and will remain shut. The engineering team is currently evaluating the well for an OA down squeeze repair. Work Completed: 1. Wellhead—Sting into IC test void and record pressure.—Done 1/25/18-IC void pressure was below IA&OA pressure 2. DHD—Obtain IA and OA gas samples.—Done 1/24/18—IA and OA gas sample were dissimilar 3. DHD—Bleed IA pressure to 1,000psi and monitor OA response.—Done 1/24/18—OA repressurized 1,220psi in 24 hours Please respond with any questions, CAM ) ' ,' Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO 8, OF Thr • • 4„Vs. //j, sA THE STATE Alaska Oil and Gas ofLAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF \T:'Q' Main: 907.279.1433 ALAS'" Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Interventions and Integrity Engineer sCANNED r*P, 16' E"_118 BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU N-12 Permit to Drill Number: 181-014 Sundry Number: 318-048 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Wei/ Cathy P. Foerster Commissioner it— DATED this J4 of February, 2018. R r nS LL FEB - 1018 IF iL W STATE OF ALASKA 5 LASKA OIL AND GAS CONSERVATION COMMI N FEB 0 APPLICATION FOR SUNDRY APPROV S Z�'20 AAC 25.280 #2v"'S SZ` acz,0 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 ` Alin[ Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA WellLock Squeeze 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 181-014 . • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-20557-00-00 • 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU N-12 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028282&028283 ' PRUDHOE BAY,PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10070 s 9262 10010 9208 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 38-118 38-118 0 0 Surface 2647 13-3/8" 37-2684 37-2684 5380 2670 Intermediate 9212 9-5/8" 35-9247 35-8523 6870/8150 4760/5080 Production Liner 1316 7"29#L-80 8744-10060 8085-9253 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9631 -9750 8864/8972 4-1/2"12.6# 13Cr80 33-8804 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8663/8013 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 - Service 0 14.Estimated Date for Commencing Operations: February 12,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington,Aras J be deviated from without prior written approval. Contact Email: Aras.Worthingtonabp.com Authorized Name: Worthington,Aras J Contact Phone: +1 907 564 4102 Authorized Title: Interventions&Integrity Engineer Authorized Signature:/ / 4Date: 2/ /218 /�-- COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number31 0 _o ! s Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: 1o Post Initial Injection MIT Req'd? Yes❑ No L� �� �5 LL F� LI,�O Spacing Exception Required? Yes 0 No El Subsequent Form Required: /Com— 4 c4 APPROVED BYTHE p Approved by: abg7 I/77- z/!g 1 COMMISSIONER COMMISSION Date:2—/Q..—/O f� ORIGINAL, Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • bp 0 Well: N-12 N-12 OA WeIlLock Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Matt Bergene (907) 564-4849 Expected Start Date: February 12, 2018 History N-12 is a vertical producer in the N-28 UZI pattern. The well was drilled in 1981, and was initially completed with L80 tubing. After finding a leak in the tubing, as well is identifying IxOA communication, a RWO was performed in 2008. At that time the OA was cemented to surface and new 13Cr-80 tubing was installed. At that point the OA was manageable below 1000 psi. Recently the OA began to show signs of increased build up rate. During the summer of 2017, after multiple gas samples off the OA confirmed that gas was from an external source (consistently 94% methane and no CO2). In September 2017 the OA NOL was raised to 1500 psi. The OAP was manageable below this pressure until the well was POPd on 1/14/18. On 1/21/18 the OAP was found to have climbed to 1830 psi and was bled down. Current Status The well is currently shut-in and will be classified as "Not-Operable" by BP. Objective Squeeze the cemented OA with Well Lock to seal off the OA re-pressurization. Procedure 1. ND OA Gate Valves, NU OA Integrals. 2. Bleed Annuli, Prep OA, WeIlLock OA top job squeeze to 3500 psi per RPs. 3. ND OA Integrals, NU OA Gate Valves. • • TREE= CAN WELLHEAD= MCEVOY _ SAFETY NOTES: ***4-112""CHROME TBG*** ACTUATOR= BAKER C ISI KB ELEV= 79 6' BF ELEV= 45 75' 144 •i KOP= 3200" ��/ ♦• Max Arae= 33°@ 6100" 4 ♦• Datum MD= 9638' •s f ^ 2071H 9-5/8"WFD CEMENTER •Datum IVO= 8800'SS 4 •� 9-5/8"CSG,47#,L-80 HYD 563,ID=8.681" —•r 2086' ' , 1-4—f..._2109'....1—{4-1/7 HES X NIP ID .81 3" 3 1 2543' —/9.5/8"HOWCO DV PKR 13-318"CSG,72#L-80,ID=12-347 2680' �...., GAS LIFT MANDRELS 1ST MD TVD DEV TYPE VLV LATCH PORT DATE : 3 4 3391 3385 14 PING DONE RK 16 08103/08 3 6024 5715 33 MIG SO RK 20 08/03/08 2 7522 7009 26 MIG DAM RK 0 07/02/08 1 8558 7927 28 NM DMI' RK 0 07/02/08 Minimum ID = 3.725" @8779' �-112" HES XN NIPPLE . . ., . , 1 , 8629' —4-1/7 HES X NIP,ID=3.813" i8650' —9-5/8"X 4117'BKR S-3 PKR,O=3.875" I ' 8674' —14-117'HES X NIP,ID=3 813" TOP OF r LNR H 8744' ' 1 — 8779' H4-1/2"HES XN NIP,O=3.725" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, H 8791' f ( 8791' -^4-1/7 WLEG,ID=3.958" .0152 bpf,ID=3.958" 9-5/8"CSG,47#,L-80 BUTT,ID=8.681" H 9243' PERFORATION SLA/MARY REF LOG SWS-BHCS ON 05/29/81 9644' J--17"MARKER JOINT ANGLE AT TOP PERF 25" 1c 9631' Note Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9631 -9646 0 01/26/10 I 3-3/8" 6 9670.9690 0 03/20/09 3-1/8" 4 9678-9700 • S 02/23/92 3-3/8" 6 9684-9700 ' 0 11109/08 I 3-3/8" 6 9713-9730 • 0 11/09/08 3-3/8" 12 9713-9750 . 0 01/13/96 I PBTD 10010' 1/1111!1( 11111111 1111111/1/1111 7"LNR,29#,L-80 0371 bpf,ID=6.184" H 10060' DATE REV BY CDUINENTS DATE REV BY COMMENTS PRUDHOE BAY LRVIT 06/02/81 ORIGINAL COMPLETION 10/20/08 PJC DRAWING CORRECTIONS WELL, N-12 07/04108 N4ES RWO 1121/08 TFA/TLH PERFS(11/09/08) PERMfT No '1810140 12/25/06 RM.-1/PAG CORRECT NIP REDUCER ID 03/29/09 JKDYPJC PERFS(03/20/09) API No 50-029-20557-00 08/12/08 HB/JMD DRLG DRAFT CORRECTIONS 02/03/10 JEDVPJC PERFS(01/26/10) SEC 8,T11 N,R13E,1144 FSL&544 FWL 1 09/01/08 KSB/PJC GLV C/0(08/03108) 04/04/12 RLW/JMD PERF DATE CORRECTION 09/02/08 PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) 2 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,January 23, 2018 3:59 PM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad MN;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua;Worthington, Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATON: Producer N-12 (PTD# 1810140) Sustained outer annulus casing pressure above NOL Attachments: N-12.pdf All, Producer N-12 (PTD#1810140)was reported to have sustained outer annulus casing pressure above NOL on 1/22/18. The pressures were confirmed to be T/1/0= 240/1600/1830psi. N-12 has known OA repressurization from a shallow gas source and has a revised NOL of 1,500psi. The well is now reclassified as Under Evaluation and is on the 28 day clock for diagnostics. Plan Forward: 1. Wellhead—Sting into IC test void and record pressure. 2. DHD—Obtain IA and OA gas samples. 3. DHD—Bleed IA pressure to 1,000psi and monitor OA response. 4. DHD—OART(Pending results from step 4) 5. Wells Engineer—Evaluate for wellock treatment 6. Well Integrity Engineer—Additional diagnostics as needed. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110SCAWS Cell: 907-341-9068 WO 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, September 13, 2017 12:08 PM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS GC2 Facility OIL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad MN;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver, Tyson;Wellman,Julie; Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer N-12 (PTD#1810140) Sustained OA Normal Operating Limit (NOL) Revised to 1,500psi All, Producer N-12 (PTD # 1810140) now has a revised OA Normal Operating Limit (NOL, formerly MOASP) of 1500 psi. The NOL revision is via Management of Change ADW-MOC-10221, which applies to wells with OA's cemented to surface. An engineering design review of the well and wellhead system was completed and approved. A sign indicating the revised NOL has been installed. With the NOL revision this well now meets BP operability criteria and can continue to operate as Operable. Please be mindful of the OA's small volume,possibly fluid packed annuli when placing the well on production to ensure not to exceed NOL. Please ensure any previously installed signs required for the OA build up rate test stating not to bleed the OA annuli, are removed. Please respond with any questions. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 cLT, 2 1 ;'(l Cell 907-980-0552 ���� Harmony 4530 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday,August 17, 2017 7:11 AM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad MN;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver, Tyson;Wellman,Julie; Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer N-12 (PTD#1810140) OA Repressurization All, Producer N-12 (PTD# 1810140) was has been placed UNDER EVALUATION for having sustained outer annulus casing pressure above NOL when the well is offline. Diagnostic work indicates the OA pressurization is due to an external shallow gas source and not IAxOA communication. An OA NOL revision is currently being progressed. Please reply if in conflict. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110SCANNED AUG 2 1 N17 Cell 907-980-0552 Harmony 4530 \ From: AK, GWO Well Integrity Engineer Sent: Tuesday, July 25, 2017 5:46 PM o: AK, GWO SUPT Well Integrity; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC ' - •ad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad MN; Ak, Ops West Area TL; AK, RES GPB Ea s Opt Engr; AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg, Amy; Peru, Cale; Rupert, C. Ryan; Shriv- , son; Wellman, Julie; Youngmun, Alex; Zoesch, Eric; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.re•:qialaska.gov) Cc: AK, GWO DHD Well Integrity; A , • A 0 Projects Well Integrity; AK, GWO Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, •: • A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, : - • O'connor, Katherine; Sternicki, Oliver R; Worthington, Aras 3; 'chris.wallace@alaska.gov' (chris.wallace@alaska.gov Subject: OPERABLE: Producer N-12 (PTD #1810140) OA • - , - rization Rate Manageable by Bleeds All, Producer N-12 (PTD# 1810140)was reported to have sustained outer annulus(OA)c. 4:44sure over NOL on 07/25/17. This well just finished diagnostics on 7/17/17 and on investigation this well is stil :LE, subject to 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,July 25, 2017 5:46 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad MN;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson;Wellman,Julie;Youngmun,Alex;Zoesch, Eric; Regg, James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer N-12 (PTD#1810140) OA Repressurization Rate Manageable by Bleeds All, Producer N-12 (PTD# 1810140)was reported to have sustained outer annulus(OA) casing pressure over NOL on 07/25/17. This well just finished diagnostics on 7/17/17 and on investigation this well is still OPERABLE,subject to maintaining NOL's. The Well Integrity team will continue to monitor the well to assess well barriers for a period of 90 days. Please report any NOL excursions. Please reply if in conflict. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering SCANNED AUG fl 9 201 Office 907-659-8110 Cell 907-980-0552 Harmony 4530 From: AK, SUPT Well Integrity [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Monday, Jul 2017 2:18 PM To: AK, OPS GC2 Facility . L;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Contro •AK, OPS Well Pad MN;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Bergen-, atthew;Frankenburg, Amy;Peru, Cale;Rupert, C. Ryan;Shriver,Tyson;Wellman, Julie;Youngmun, Alex;Zoesch, Eric;'Regg,Ja B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects - I Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App . 'Cismoski, Doug A;Daniel, Ryan;Dempsey, David G;Hibbert, Michael;Janowski, Carrie;Montgomery,Travis J;Munk, • - ;Obrigewitch, Beau;O'connor, Katherine;Sternicki, Oliver R;Worthington, Aras J;'chris.wallace@alaska.gov' (chris.wallace@a . ..gov) Subject: OPERABLE: Producer N-12 (PTD #1810140) OA Repressurization Rate - ageable by Bleeds All, Producer N-12 (PTD# 1810140)was reported to have sustained outer annulus(OA) casing pressure over N• • 06/15/17.Subsequent Outer Annulus Repressurization Tests(OART) have confirmed that the rate of repressurizati. ' is 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday,July 17, 2017 2:18 PM To: AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad MN; Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver, Tyson; Wellman,Julie;Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer N-12 (PTD#1810140) OA Repressurization Rate Manageable by Bleeds Attachments: Producer N-12 (PTD#1810140)TIO Plot 2017-07-17.docx All, Producer N-12 (PTD# 1810140)was reported to have sustained outer annulus(OA)casing pressure over NOL on 06/15/17.Subsequent Outer Annulus Repressurization Tests(OART) have confirmed that the rate of repressurization is manageable by bleeds, requiring 2 or less bleeds per week to maintain OA pressure below NOL.The well is now classified as Operable. Work Completed: 1) Downhole Diagnostics:Warm OART-Completed 06/21/17; OA build-up rate(BUR) =70 psi/day 2) Wellhead: Positive Pressure Packoff Test—Inner Casing—Passed 06/24/17 3) DHD: Collect OA gas sample—Completed 06/26/17; sample indicates hydrate source 4) DHD: Cold OART with gas lift pressure on IA—Completed 07/04/17;OA BUR= 160 psi/day 5) DHD: Cold OART with IA bled down—Completed 07/16/16; OA BUR initially rapid, but stabilizes at 900 psi An updated TIO plot is attached. Thanks, Adrienne McVeyf 2 01 Well Integrity Superintendent—GWO Alaska SCANNED �' (Alternate:Jack Lau) 0:(907)659-5102 AUG l C:(907)943-0296 H:2376 From: AK, GWO We • -•rity Engineer Sent: Monday, June 19, 201 . t PM To: AK, GWO Well Integrity Engineer; WO SUPT Well Integrity; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad MN; *PS Prod Controllers; AK, OPS PCC Ops Lead; AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES •: I est Wells Opt Engr; AK, RES GPB East Wells Opt Engr; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov , :-r•ene, Matthew Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; WO Completions Well Integrity; AK, OPS FF Well 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday,June 19, 2017 5:10 PM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Well Pad MN;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Regg, James B (DOA); Bergene, Matthew Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;AKIMS App User Subject: UNDER EVALUATION: Producer N-12 (PTD#1810140) High Outer Annulus Pressure Over NOL All, Producer N-12 (PTD# 1810140)was reported to have sustained outer annulus casing pressure over NOL on June 15, 2017. The pressures were confirmed to be TBG/IA/OA= 740/1680/1020 psi. At this time,the well has been reclassified as Under Evaluation and well barriers will be verified or repaired within 28 days. Plan Forward: 1. Well Head: PPPOT-IC 2. Well Integrity Engineer: Additional diagnostics as needed Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering SCANNED JUN 2 3201? Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 \ RECEI � �- ° 04 • rr=n" BAKER JUN 15 2017 PRINT DISTRIBUTION LIST HUGHES BP�p�tfa�aska Inc Please ign and return onecopy of this transmittal form to: COMPANY n BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 1-.) ,TA LOGGED is WELL NAME N-12 900 E. Benson Blvd. i201M K BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit Ito acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska LOG DATE May 6,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares c7i bakerhughes.com TODAYS DATE June 7,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOJ}; LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF PRIN I S #OF COPIES #OF COPIES #OF COPIES U 1 Baker Hughes,Inc. 0 0 795 E.94th Ave. Anchorage,AK 99515 Attn: Arelys Carolina Martinez SCANS -I I IN 2 7 2.0174 Patrick Rider 2 ConocoPhillips Alaska Inc. 1 1 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobll,Alaska 0 1 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4'State of Alaska -AOGCC 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 1 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 *Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: TOTALS FOR ALL PAGES: 0 3 4 0 S • 2.-CpP1 Gyrodata Incorporated 23000 Northwest Lake Dr. gyro/data 'Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 RECEIVED SEP 2 3 2015 AOGCC September 22, 2015 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 ! Anchorage, Alaska 99501 Re: N-Pad, Well # N-12 Prudhoe Bay, Alaska Enclosed, please find one (1) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Kelly Landram Senior Operations Assistant RIGHT PLACE FIRST TIME SGS ; www.gyrodata.com 2-1 Gyrodata Incorporated gym/data 23000 Northwest Lake Dr. Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 RECEWED SEP 2 3 2015 AOGCC DATA LOGGED 9 /2q4/2015 IVI. K.BENDER SURVEY REPORT BP Exploration N-Pad #N-12 Wellhead Prudhoe Bay, North Slope Borough, AK AK0915GCM169 5 September 2015 RIGHT PLACE FIRST TIME www.gyrodata.com _. . . . 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I - I .., s• • - o s • • I i CO , • I 'L: ; O V N (O Z - V) N Q Z co • O s - r -- C = I a ,-1 • L � _O O O.Z O , x _ I i I i I I I i _I i LLI N 1 l' I I I --O 0_ U Ln 0 LA 0 LA O Ln 0• LA O m J d M M N N r-1 O O (1400T/bap) A1I2i�ADS 931JOa • • Survey QC - RGS-CT Specification Sheet g .`:_• SURVEY QUALITY CONTROL-SPECIFICATION DATA PRE-JOB CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 13252 270.44 133.45 0.00003335 3.16 13251 270.45 139.16 0.00003478 4.11 13250 226,05 -390.03 -0.00009753 -3.50 13249 226.05 -386.12 -0.00009656 -2.14 13248 45.70 -328.56 -0.00008217 -1.46 13247 45.70 -321.03 -0.00008029 -0.77 13246 0.48 1.97 0.00000049 2.98 13245 0.48 13.48 0.00000337 3.89 13244 332.14 333.28 0.00008333 4.03 13243 332.14 341.87 0.00008548 3.56 13242 271.69 134.39 0.00003359 4.88 13241 271.69 132.81 0.00003319 4.18 13240 237.72 -305.80 -0.00007646 -0.18 13239 237.72 -300.29 -0.00007508 -1.30 13238 297.73 395.99 0.00009896 6.55 13237 297.73 396.90 0.00009919 7.84 13236 211.68 -376.80 -0.00009424 -3.92 13235 211.68 -363.28 -0.00009086 -4.31 13234 180.30 -31.90 -0.00000798 -5.58 13233 180.30 -27.09 -0.00000677 -5.52 13232 152.97 311.50 0.00007788 -8.23 13231 152.97 317.15 0.00007930 -7.86 13230 120.28 413.99 0.00010346 -7.48 13229 120.28 414.89 0.00010368 -6.98 13228 91.56 169.42 0.00004234 -4.83 13227 91.56 178.91 0.00004472 -5.66 13226 60.24 -206.37 -0.00005161 -3.10 13225 60.24 -199.47 -0.00004988 -1.77 13224 31.16 -296.25 -0.00007411 1.00 13223 31.16 -293.52 -0.00007343 0.71 13222 2.00 -8.81 -0.00000220 4.88 13221 2.00 -10.41 -0.00000260 4.99 13220 239.43 -303.08 -0.00007577 -1.44 13219 239.43 -297.45 -0.00007437 -2.24 13218 271.70 116.08 0.00002901 3.45 13217 271.70 125.57 0.00003138 4.68 13216 225.59 -416.15 -0.00010406 -5.49 13215 225.59 -407.73 -0.00010196 -6.34 13214 44.91 -349.94 -0.00008752 -1.01 13213 44.91 -342.89 -0.00008575 -0.80 13212 0.54 -13.10 -0.00000328 8.04 13211 0.54 -5.64 -0.00000141 8.00 13210 330.24 330.09 0.00008252 6.08 13209 330.24 335.71 0.00008393 6.33 13208 299.51 391.64 0.00009787 10.34 13207 299.52 394.55 0.00009860 9.67 13206 270.12 85.24 0.00002130 3.37 13205 270.12 90.76 0.00002268 7.34 13204 207.91 -358.94 -0.00008978 -5.39 13203 207.91 -351.40 -0.00008789 -5.73 13202 180.27 -49.04 -0.00001227 -6.76 13201 180.27 -45.30 -0.00001133 -6.61 13200 149.39 331.84 0.00008296 -4.63 13199 149.39 334.24 0.00008356 -8.35 13198 118.65 413.42 0.00010332 -1.33 13197 118.65 414.54 0.00010360 -4.45 13196 89.45 107.98 0.00002699 -2.17 13195 89.45 112.54 0.00002813 0.48 13194 59.94 -226.98 -0.00005676 -2.64 13193 59.94 -225.48 -0.00005638 -1.58 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 1 of 6 AK0915GCM169 • 11/ Survey QC - RGS-CT Specification Sheet gyro/data 13192 27.69 -296.77 -0.00007424 3.64 13191 27.69 -283.26 -0.00007086 3.47 13190 0.86 -36.14 -0.00000904 3.50 13189 0.86 -32.65 -0.00000817 3.33 MBO= -0.33 Gravity Error= -7.41 Scale Factor Uncertainty= -0.00000187 Rate Error= -0.05 POST-30B CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 13315 270.78 227.08 0.00005676 -2.21 13314 226.99 -316.58 -0.00007918 -13.89 13313 226.99 -321.40 -0.00008038 -16.49 13312 46.15 -241.57 -0.00006043 -6.65 13311 46.15 -234.10 -0.00005856 -6.24 13310 0.75 70.70 0.00001769 0.51 13309 0.75 78.53 0.00001965 -2.31 13308 331.28 409.98 0.00010252 -0.19 13307 331.28 409.69 0.00010245 -0.66 13306 300.91 484.56 0.00012111 2.11 13305 300.91 486.32 0.00012155 0.64 13304 270.78 243.00 0.00006074 -0.26 13303 270.78 229.11 0.00005727 3.03 13302 241.55 -166.59 -0.00004166 -4.59 13301 241.55 -167.51 -0.00004189 -6.09 13300 210.99 -287.68 -0.00007197 -9.74 13299 210.98 -283.07 -0.00007081 -8.83 13298 181.13 27.17 0.00000680 -7.82 13297 181.13 31.43 0.00000786 -10.57 13296 151.45 394.22 0.00009857 -7.20 13295 151.45 400.27 0.00010009 -9.35 13294 121.36 513.50 0.00012835 -8.38 13293 121.36 515.05 0.00012874 -8.50 13292 91.05 296.54 0.00007414 -9.40 13291 91.04 305.35 0.00007634 -9.42 13290 60.45 -116.26 -0.00002908 -5.52 13289 60.45 -118.35 -0.00002960 -3.28 13288 28.89 -213.73 -0.00005347 -1.76 13287 28.89 -214.55 -0.00005368 -4.08 13286 0.95 67.98 0.00001701 -3.07 13285 0.95 70.72 0.00001769 -5.11 13284 270.87 205.89 0.00005146 11.69 13283 270.87 213.21 0.00005329 13.63 13282 226.09 -341.49 -0.00008540 -6.54 13281 226.09 -342.72 -0.00008571 -6.59 13280 46.11 -270.64 -0.00006769 -4.13 13279 46.11 -277.02 -0.00006929 -3.73 13278 0.50 26.95 0.00000674 1.94 13277 0.50 39.14 0.00000979 1.64 13276 330.83 376.55 0.00009415 8.72 13275 330.83 377.40 0.00009436 8.64 13274 300.69 473.53 0.00011835 14.86 13273 300.69 472.78 0.00011816 15.83 13272 270.69 225.11 0.00005627 12.31 13271 270.69 232.11 0.00005802 10.55 13270 239.62 -206.14 -0.00005155 1.89 13269 239.62 -200.79 -0.00005021 0.40 13268 209.24 -321.79 -0.00008049 -9.66 13267 209.24 -319.64 -0.00007996 -11.10 13266 182.57 -42.60 -0.00001066 -7.54 13265 182.57 -37.51 -0.00000938 -7.11 13264 151.87 346.65 0.00008667 1.17 13263 151.87 349.25 0.00008732 -0.01 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 2 of 6 AK0915GCM169 • • Survey QC - RGS-CT Specification Sheet 1 13262 121.33 509.93 0.00012746 7.64 13261 121.33 513.07 0.00012825 7.72 13260 90.73 308.30 0.00007708 7.01 13259 90.73 322.82 0.00008071 6.99 13258 59.45 -113.96 -0.00002850 0.56 13257 59.45 -105.43 -0.00002637 0.00 13256 31.48 -272.53 -0.00006818 -7.15 13255 31.48 -269.71 -0.00006747 -4.66 13254 358.14 27.74 0.00000694 -0.31 MBO = -0.35 Gravity Error= 72.23 Scale Factor Uncertainty= 0.00001805 Rate Error= -1.62 INITIALISATION Gyro Compass Reading/Station Raw Inclination Raw Azimuth Abs(ER Meas-ERrne°1 70 12.18 105.05 0.0233 71 12.18 104.67 0.0422 72 12.18 104.91 0.0170 73 12.18 105.18 0.0058 74 12.18 104.87 0.0005 75 12.18 104.87 0.0421 76 12.18 105.03 0.0688 Average 12.18 104.94 0.0285 Tolerance on Average* 0.0820 Standard Deviation 0.00 0.16 0.0240 Tolerance on St. Dev.** 0.10 0.20 0.0370 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance =TBA * Tolerance on Average of earth horizontal rate difference is given by (1/CosI)*J[(CosA*SinI*0.1)2+0.0821 °/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cosi)*J[(CosA*SinI*0.1)2+(0.082/(n-1))) °/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 726.75 4000.22 29.01 114.37 -0.003 0.004 0.007 -0.004 2 1467.78 6399.86 31.98 118.44 0.002 -0.001 0.008 -0.006 3 1413.52 7700.95 27.20 117.43 0.001 -0.000 0.002 -0.001 4 793.60 8149.92 28.31 120.70 -0.002 0.002 0.000 -0.001 5 1050.08 8760.17 28.88 126.56 -0.001 0.002 0.004 -0.003 6 466.99 9000.54 29.69 129.63 -0.004 0.004 0.005 -0.004 7 519.87 9400.58 26.90 135.19 -0.002 0.002 0.003 -0.001 8 692.48 9759.83 24.17 134.81 0.001 0.000 0.003 -0.001 9 689.32 9399.93 26.87 134.99 0.002 -0.001 0.003 -0.001 10 630.34 9000.28 29.70 129.51 0.000 0.000 0.003 -0.002 11 438.56 8759.91 28.86 126.60 0.001 -0.001 0.002 -0.001 12 905.81 8149.98 28.13 120.80 -0.002 0.003 0.004 -0.003 13 716.25 7699.97 27.04 117.49 0.001 -0.000 0.001 0.000 14 1406.30 6387.53 32.32 118.72 -0.001 0.002 0.005 -0.001 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 3 of 6 AK0915GCM169 i ! Survey QC - RGS-CT Specification Sheet gym/data 15 1436.31 5000.00 28.40 116.41 -0.001 -0.000 0.001 0.002 16 1097.05 4000.03 29.24 114.41 -0.003 0.003 0.002 -0.002 17 1371.69 3299.93 12.35 104.54 -0.001 0.001 0.002 -0.002 Average -0.001 0.001 0.003 -0.002 Standard Deviation 0.002 0.002 0.002 0.002 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth Corrected Inclination Corrected Azimuth Inrun * I Outrun * I Difference Inrun * I Outrun * I Difference 100.00 0.26 0.17 0.08 235.00 244.58 -9.58 200.00 0.15 0.16 -0.01 167.21 169.73 -2.52 300.00 0.20 0.18 0.02 175.09 174.06 1.03 400.00 0.20 0.17 0.03 178.11 172.44 5.66 500.00 0.14 0.12 0.02 180.33 175.30 5.02 600.00 0.14 0.12 0.01 176.43 163.94 12.49 700.00 0.08 0.10 -0.02 154.39 180.68 -26.29 800.00 0.08 0.08 0.00 172.05 154.42 17.63 900.00 0.08 0.08 -0.00 174.53 157.98 16.55 1000.00 0.10 0.09 0.00 165.11 163.94 1.17 1100.00 0.20 0.21 -0.01 122.97 120.59 2.37 1200.00 0.21 0.20 0.01 129.59 127.69 1.90 1300.00 0.21 0.21 -0.00 127.13 123.76 3.37 1400.00 0.18 0.17 0.01 114.82 108.69 6.12 1500.00 0.17 0.16 0.01 124.50 124.29 0.21 1600.00 0.06 0.06 -0.00 254.96 264.40 -9.44 1700.00 0.16 0.15 0.01 289.99 289.44 0.55 1800.00 0.15 0.13 0.02 293.58 295.38 -1.80 1900.00 0.12 0.14 -0.03 298.95 284.74 14.22 2000.00 0.12 0.11 0.01 268.98 276.62 -7.65 2100.00 0.16 0.17 -0.02 135.73 138.13 -2.39 2200.00 0.30 0.29 0.02 108.13 116.14 -8.01 2300.00 0.28 0.29 -0.01 116.16 118.68 -2.52 2400.00 0.27 0.28 -0.01 101.59 109.99 -8.40 2500.00 0.31 0.32 -0.01 65.80 64.58 1.22 2600.00 0.32 0.33 -0.01 64.14 66.70 -2.56 2700.00 0.98 0.98 0.00 249.77 257.71 -7.93 2800.00 1.41 1.50 -0.09 200.21 198.72 1.48 2900.00 1.58 1.58 -0.00 152.06 156.77 -4.71 3000.00 3.46 3.48 -0.02 123.35 126.01 -2.65 3100.00 6.44 6.51 -0.08 109.15 113.68 -4.53 3200.00 9.45 9.43 0.02 104.24 103.08 1.16 3300.00 12.17 12.21 -0.04 104.98 104.48 0.50 3400.00 13.78 13.59 0.19 113.09 113.29 -0.20 3500.00 16.41 16.43 -0.02 117.82 117.73 0.08 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 4 of 6 AK0915GCM169 • • Survey QC - RGS-CT Specification Sheet gyrolaaa ta 3600.00 19.56 19.55 0.00 116.34 116.21 0.14 3700.00 21.41 21.37 0.04 114.88 115.12 -0.23 3800.00 24.17 24.20 -0.03 112.67 112.82 -0.14 3900.00 26.57 26.56 0.01 113.17 113.25 -0.08 4000.00 29.04 29.02 0.01 114.38 114.43 -0.06 4100.00 30.07 30.06 0.01 114.53 114.65 -0.12 4200.00 30.00 29.99 0.01 114.38 114.52 -0.14 4300.00 29.84 29.84 0.00 114.69 114.83 -0.14 4400.00 29.85 29.86 -0.01 114.89 115.03 -0.14 4500.00 29.58 29.55 0.03 115.23 115.22 0.01 4600.00 28.98 29.00 -0.01 115.01 115.11 -0.10 4700.00 29.03 29.07 -0.03 115.29 115.38 -0.09 4800.00 29.03 29.06 -0.03 115.63 115.71 -0.08 4900.00 28.62 28.58 0.05 115.89 115.94 -0.05 5000.00 28.35 28.32 0.03 116.28 116.40 -0.12 5100.00 28.03 28.02 0.02 116.86 116.93 -0.07 5200.00 27.69 27.67 0.02 116.95 117.04 -0.09 5300.00 27.37 27.36 0.01 117.00 117.10 -0.09 5400.00 27.52 27.53 -0.01 117.10 117.20 -0.09 5500.00 28.41 28.42 -0.01 117.34 117.42 -0.09 5600.00 29.45 29.46 -0.01 117.69 117.84 -0.14 5700.00 30.36 30.37 -0.01 117.76 117.89 -0.13 5800.00 31.45 31.48 -0.03 117.78 117.89 -0.11 5900.00 32.10 32.12 -0.02 118.01 118.19 -0.18 6000.00 32.43 32.44 -0.01 118.53 118.68 -0.15 6100.00 32.94 32.98 -0.03 119.08 119.24 -0.17 6200.00 32.98 33.01 -0.03 119.49 119.67 -0.18 6300.00 32.69 32.73 -0.04 119.05 119.17 -0.11 6400.00 32.08 32.12 -0.04 117.33 118.63 -1.29 6500.00 31.85 31.90 -0.05 117.81 117.95 -0.14 6600.00 31.46 31.52 -0.06 116.88 117.10 -0.22 6700.00 31.01 31.01 0.00 116.14 116.22 -0.08 6800.00 30.87 30.88 -0.01 115.05 115.23 -0.18 6900.00 30.46 30.43 0.02 114.87 114.79 0.08 7000.00 29.81 29.71 0.10 114.80 114.92 -0.12 7100.00 29.30 29.28 0.01 114.93 114.96 -0.03 7200.00 27.95 27.91 0.04 115.39 115.55 -0.16 7300.00 27.17 27.18 -0.01 115.39 115.37 0.02 7400.00 26.86 26.86 0.00 114.96 115.12 -0.15 7500.00 26.33 26.34 -0.01 115.37 115.51 -0.15 7600.00 26.60 26.51 0.09 116.64 116.54 0.10 7700.00 27.04 27.03 0.00 117.42 117.48 -0.06 7800.00 27.61 27.68 -0.07 118.27 118.35 -0.08 7900.00 27.32 27.38 -0.06 118.90 119.02 -0.12 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 5 of 6 AK0915GCM169 • • . Survey QC - RGS-CT Specification Sheet gyroldata 8000.00 27.85 27.95 -0.10 119.62 119.49 0.13 8100.00 28.11 28.17 -0.06 120.67 120.56 0.12 8200.00 28.09 28.11 -0.02 121.57 121.58 -0.01 8300.00 28.72 28.75 -0.03 122.39 122.42 -0.04 8400.00 29.33 29.35 -0.02 122.10 122.19 -0.09 8500.00 28.98 28.96 0.02 123.12 123.13 -0.01 8600.00 28.25 28.27 -0.02 124.36 124.42 -0.06 8700.00 28.22 28.24 -0.01 125.83 125.92 -0.10 8800.00 29.23 29.16 0.07 126.69 126.95 -0.26 8900.00 29.59 29.61 -0.03 128.31 128.13 • 0.18 9000.00 29.68 29.72 -0.04 129.75 129.44 0.31 9100.00 29.36 29.41 -0.05 131.49 131.25 0.24 9200.00 29.27 29.33 -0.06 132.54 132.46 0.09 9300.00 29.69 29.74 -0.04 135.39 135.16 0.24 9400.00 26.91 26.95 -0.05 135.19 134.97 0.22 9500.00 26.00 26.03 -0.04 134.62 134.86 -0.24 9600.00 25.36 25.40 -0.04 135.04 135.29 -0.25 9700.00 24.46 24.46 -0.00 134.21 134.48 -0.28 Average -0.0055 -0.0836 Standard Deviation 0.0392 0.2021 Tolerance for both the Average and the Standard Casing 0.3° Casing 0.5° Deviation Drillpipe 0.3° Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 6 of 6 AK0915GCM169 • • , Survey QC - RGS-CT Analysis Sheet ' `' SURVEY QUALITY CONTROL- DATA ANALYSIS REFERENCE SYSTEMS Grid System I I Grid Correction 10.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB I If other give details I TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 I ND 1 0.00 Northings 0.00 Eastings 0.00 Latitude 70.3182 Az. Ref:Grid/True True Grid Corrected Y/N? N Description I CALIBRATION Tool Number I F0007 I Calibration Date 122 Apr 2013 OPERATING TEMPERATURE Calibration range From 49.49 To 119.45 Gyro operating range From 69.73 To 106.78 I Spec'-Within calibration range FIELD ROLL TEST (Only valid on fixed structures. When not possible input roll test data performed after return to base) Cal value Pre job offset Post job Abs dif.cal.post Abs dif.pre.post Spec' offset Accel Scale 0.000055 -0.000002 0.000018 0.000018 0.000020 Cal/Post-0.00015 Mass Unbalance 1.01 -0.33 -0.35 0.35 0.02 Pre/Post-0.4°/hr INITIALISATION Depth(Approx) _ 3300.49 No of stns 7 Spec'- Min No. -6 Azimuth Mean 104.94 Std deviation 0.16 Spec'-Azi SD 0.2° Inclination Mean 12.18 Std deviation 0.00 Spec'-Inc SD 0.1° Earth Horizontal Rate Mean (Abs(meas-theor)) 10.03 Std deviation 0.02 Spec'-See Q167 DRIFT TUNE Residual x gyro bias Mean 0.001 Std dev' 0.002 Spec's- Mean and SD-0.333°/hr Residual y gyro bias Mean -0.002 Std dev' 0.002 Spec's- Mean and SD -0.333°/hr TOOLFACE RATE • Maximum toolface rate 164.04 I Spec'-400°/sec IN/OUT COMPARISON (AZI' N/A IF INC' <15°) Inclination Difference Mean -0.01 Std dev' 0.04 Spec's- Casing 0.3°/Drill pipe 0.3° Azimuth Difference Mean -0.08 Std dev' 0.20 Spec's- Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 0.56 Spec- 5.0/1000 Vertical Divergence/1000 0.05 Spec'-2.0/1000 DEPTH CONTROL Wireline Company Schlumberger I Line type 7/32" Encoder SF I Schlumberger Max Depth (TD) 9759 CCL Corrected NO Zero Depth (Rig up) RKB @ 79.6 ft AMSL Rezero Depth -4.8 Given pup joint depth NA Measured PJ NA Strech cor.At TD divided by TD/1000 .2869 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 .4900 Spec'-2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'- 2.0/1000 SURV-Q165(OPS SUR-MA-010)22nd Jan 2004/Revision 20 Page 1 of 1 AK0915GCM169 • • gytoidata • Survey QC - RGS-CT Acceptance Sheet FIELD AND SURVEY INFORMATION Operator BPXA Field/Platform Wellhead Well Number Prudhoe Bay Drilisite: N Well N-12 Survey section From 0.00 ft. to 9759.00 ft. Date 05 Sep 2015 Gyrodata Job No AK0915GCM169 Gyrodata Surveyors Ian Squier,Adam O'Connor Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation,after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13t Nov 03/Revision 12 Page 1 of 1 AK0915GCM169 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator @bp.com] Sent: Tuesday, October 15, 2013 8:06 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Bailey, Denise G; Wallace, Chris D (DOA); AK, OPS Well Pad MN Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); Climer, Laurie A Subject: OPERABLE: Producer N-12 (PTD#1810140)OAP Manageable by Bleeds All, Producer N-12 (PTD#1810140) had a warm OART completed with a manageable build up rate of 89 psi/day, and a passing PPPOT-IC. At this time the well is reclassified as Operable, and may remain online. Please call with any questions. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator GA/ GbotaiWas �� Organizat,on WIC Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, September 22, 2013 11:17 AM To: A OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS 2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; c-niel, Ryan; AK, D&C Wireline Operations Team Lead; D&C Well Services Operations Team Lead; AK, RES GPB West - s Opt Engr; AK, RES GPB East Wells Opt Engr; Bailey, ►-nise G; 'chris.wallace @alaska.gov'; AK, OPS Well Pad MN Cc: AK, D&C DHD ' -II Integrity Engineer; Holt, Ryan P; Walker, Greg (D& AK, D&C Well Integrity Coordinator; 'jim.regg @alaska.gov' Subject: UNDER EVALUA 'N: Producer N-12 (PTD #1810140) Sustained Outer • ulus Casing Pressure Above MOASP All, Producer N-12 (PTD#1810140)was reporte• o have sustained outer annulus casing pressure a'•,ve MOASP on 09/19/2013. The well is reclassified as Under Ev. ation and is placed on a 28 day clock to facilitate -valuation. Plan forward: 1. DHD: Bleed outer annulus and monitor repressurizatio 2. Wellhead: PPPOT-IC A copy of the TIO plot and wellbore schematic are included for reference. 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS • REPORT OF SUNDRY WELL OPERATIONS RECEIVED ~Eg 4 ~ 2g1d 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ iQ~~~ ~~ ~~ ~01111YII$810 Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Afit;h9fA~ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-en r Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory 181-0140 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ ~ API Number: Anchorage, AK 99519-6612 50-029-20557-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: \\ ~ ADLO-028283 PBU N-12 10. Field/Pool(s): \ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10070 feet Plugs (measured) None feet true vertical 9271 feet Junk (measured) None feet Effective Depth measured 10010 feet Packer (measured) 8650 true vertical 9217 feet (true vertical) 8007 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2681 13-3/8" 72# L-80 SURFACE - 2680 SURFACE - 2680 4930 2670 Intermediate 9243 9-5/8" 47# L-80 SURFACE - 9243 SURFACE - 8526 6870 4760 Production Liner 1316 7" 29# L-80 8744 - 10060 8090 - 9262 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# CR80 SURFACE - 8791 SURFACE - 8131 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X4-1/2" 8650 8007 12. Stimulation or cement squeeze summary: ~,# Intervals treated (measured): ~~er:"C~.i~"• ~"~t~ ~~ ~ ~~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 79 453 2049 187 Subsequent to operation: SI 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GS OR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 2/9/2010 N-12 181-014 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base N-12 7/1/82 PER 9,678. 9,700. 8,915.62 8,935.7 N-12 7/1/82 PER 9,720. 9,750. 8,953.97 8,981.36 N-12 2/23/92 SQZ 9,678. 9,700. 8,915.62 8,935.7 N-12 2/23/92 SQZ 9,720. 9,750. 8,953.97 8,981.36 N-12 3/2/92 RPF 9,730. 9,750. 8,963.1 8,981.36 N-12 10/25/94 SQZ 9,678. 9,700. 8,915.62 8,935.7 N-12 12/2/94 RPF 9,735. 9,745. 8,967.66 8,976.79 N-12 1/13/96 APF 9,713. 9,730. 8,947.57 8,963.1 N-12 11/9/08 APF 9,684. 9,700. 8,921.09 8,935.7 N-12 11/9/08 APF 9,713. 9,730. 8,947.57 8,963.1 N-12 3/20/09 APF 9,670. 9,690. 8,908.32 8,926.57 N-12 1/26/10 APF 9,631. 9,646. 8,872.84 8,886.47 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • N-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/25/2010°"**WELL SHUT IN UPON ARRIVAL""" (ELINE: PERFORATION) 'ARRIVE ON LOCATION, SPOT UP, AND STANDBY FOR PAD OP TO ARRIVE. *""** CONTINUE AWGRS ON 26-JAN-10""*** 1/26/2010***"" CONTINUE AWGRS FROM 25 JAN-10***** (ELINE. PERFORATION) ;INITIAL T/I/O: 1850/1720/0 9631' - 9646' API DATA: PENE = 36.5", ENTR HOLE = 0.37". WING/SSV/SWAB = C, MASTER = O FINAL T/I/O: 1850/1720/0 **"JOB COMPLETE. WELL LEFT SI UNPON DEPARTURE.*'`* FLUIDS PUMPED BBLS 1 DIESEL 5 METH 6 Total TREE = CM/ ',WELLHEAD =_ _-MCE~(OY 'ACTUATOR = BAKER C KB. ELEV = 79.6' BF. ELEV = _ 45.75' KOP = 3200' Max Angle = 33° @ 6100' Datum MD = 9638' Datum TV D = 8800' SS 9-518" CSG, 47#, L-80 HYD 563, ID = $.681" 13-3/8" CSG, 72# L-80, ID = 12.347" N _ ~ ~ SA TES: ***4-112" CHROME TBG'`** 2072' 9-518" WFD CEMENTER 2109' 4-112" HE5 X NIP, ID = 3.813"~ 2543' 9-518" HOWCO DV GAS LIFT MANt~RFI .~, ST MD TVD DEV TYPE VLV LATCH O P RT DATE 4 3391 3385 14 MMG DOME RK 16 08/03/08 3 6024 5715 33 MMG SO RK 20 08/03/08 2 7522 7009 26 MMG DMY RK 0 07!02108 1 8558 7927 28 MMG DMY RK 0 07(02108 Minimum ID = 3.725" @ 8779' 4-1/2" HES XN NIPPLE 4-1/2" HES X NIP, ID =3.813" 19-5/8" X 4-112" BKR S-3 PKR, ID = 3.875" 8674' (-j4-1/2" HES X NIP, ID = 3.813" TOP OF 7" LNR 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80 BUTT, ID = 8.681" PERFORATION SUMMARY REF LOG: SWS-BRCS ON 05/29!81 ANGLE AT TOP PERF: 24° @ 9670' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 9670 - 9690 O 03/20!09 3-1/8" 4 9678 - 9700 S 02/23/92 3-318" 6 9684 - 9700 O 11!09/08 3-318" 6 9713 - 9730 O 11/09108 3-318" 12 9713 - 9750 O 01113!96 PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS 06!02181 ORIGINAL COMP<_ETION 10120!08 PJC DRAWING CORRECTIONS 07/04108 N4ES RWO 11121108 TFA/TLH PERFS (11/09108) 12125/06 RMH(PA CORRECT NIP REDUCER ID 03129/09 JKD/PJC PERFS {03120(09) 08!1210$ HB/JMD DRLG DRAFT CORRECTIONS 09!01/08 KSBtPJC GLV C/O {08103/0$) 09/02!08 PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: N-12 PERMff No: "1810140 API No: 50-029-20557-00 SEC 8, T11 N, R13E, 1144 FSL & 544 FWL BP F~cploration (Alaska) ~ 4-1 /2" HES XN NIP, ID = 3.725" ~ 8791' ~-14-112" WLEG, ID = 3.958" 9644' ~-{ 7" MARKER JOINT STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~~~~~~.~ MAR ,~ ~ try 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated t 8S ~.iisb. ~01~;~;,~ ~f~ Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension ®nchora~~ Change Approved Program ~ Operat. Shutdown ~ Perforate Q , Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~~! 181-0140 - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20557-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 79.6 KB ~ PBU N-12 - 8. Property Designation: 10. Field/Pool(s): ADLO-028283 _ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10070 , feet Plugs (measured) None true vertical 9271 - feet Junk (measured) None Effective Depth measured 10010 feet true vertical 9217 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 30"x20" surface - 110' surface - 110' Surface 2681' 13-38/" 72# I-80 surface - 2680' surface - 2680' 4930 2670 Intermediate 9243' 9-5/8"47# I-80 surtace - 9243' surface - 8526' 8150 5080 Liner 1316' 7" 29# I-80 8744' - 10060' 80 90' - 9262' 8160 7020 (~ t, u"~~ I~~~ _ ~i~t ~'i a a w Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 8791' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"x4-1/2" BKR S-3 PKR 8650' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 105 1674 2785 246 Subsequent to operation: SI 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Service r Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ ~ Gas WAG ~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 3/23/2009 Form 10-404 Revise 04/200~i-z, F--; ,..r , _ ;. , ~ ~E~~,~ ~ 1~(1~ Submit Original Only 4. ~~~ ~~ N-12 181-014 PFRF OTTO[:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base N-12 7/1/82 PER 9,678. 9,700. 8,915.62 8,935.7 N-12 7/1/82 PER 9,720. 9,750. 8,953.97 8,981.36 N-12 2/23/92 SQZ 9,678. 9,700. 8,915.62 8,935.7 N-12 2/23/92 SQZ 9,720. 9,750. 8,953.97 8,981.36 N-12 3/2/92 RPF 9,730. 9,750. 8,963.1 8,981.36 N-12 10/25/94 SQZ 9,678. 9,700. 8,915.62 8,935.7 N-12 12/2/94 RPF 9,735. 9,745. 8,967.66 8,976.79 N-12 1113/96 APF 9,713. 9,730. 8,947.57 8,963.1 N-12 11/9/08 APF 9,684. 9,700. 8,921.09 8,935.7 N-12 11/9/08 APF 9,713. 9,730. 8,947.57 8,963.1 N-12 3/20/09 APF 9,670. 9,690. 8,908.32 8,926.57 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • N-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/19/2009°'"**WELL SHUT-IN ON ARRIVAL"`** ~(E-LINE ADD PERFS). INITIAL T/I/O = 1990/1950/0. BEGIN RIGGING UP E- ' ALINE. ***JOB CONTINUED ON 20-MAR-2009"** 3/20/2009 3/22/2009 ***JOB CONTINUED FROM 20-MAR-2009*** (E-LINE ADD PERFS) PERFORATED 9670' - 9690' WITH 3-3/8" HSD GUN -:LOADED WITH POWERJET 3406 HMX CHARGES. !API DATA: PENETRATION = 36.5", ENTRANCE HOLE = 0.37". REFERENCE !LOG SLB BHCS DATED 29 MAY 1981, TIE IN LOG SLB CNL DATED 2 FEB !,2000. NO DEPTH OFFSET BETWEEN REFERENCE AND TIE IN LOGS. (TAGGED TD AT 9764' ELMD. WELL SI ON DEPARTURE. FINAL T/I/O = X2000/1940/0. ***JOB COMPLETE*"* 'T/I/0=1990/1990/0. Temp=S1. Bleed IAP to CLP to mitigate high IAP. AL SI @ casing valve and manifold. ALP=320 psi. IA FL @ 6024' (sta #2 so). Bled IAP to production (well - 13) from 1990 psi to 1500 psi in 1 hr Post bleed IA FL unchanged. During IA bleed TP decreased 110 psi to 1880 psi Monitor for 30 ~ mins. IAP increased 20 psi, TP and OAP unchanged. Final W HP's=1880/1520/0. SV,WV=closeed.SSV,MV=open.lA,OA=OTG.NOVP. FLUIDS PUMPED BBLS 1 diesel 1 Total 01 /23/09 Schlun~berger Alaska Data & Consulting Services a(" 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 QJ a ATTN: Beth G~~J Q a°~~~` W/ oll \ ~ _Inh is ~:.~ d~'~ ~" ~ ,1 F.M. f" ~P ~ f„ ~ I ~ (pp € I td ;3 N0.5047 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 H-35 11970840 PRODUCTION PROFILE 08/12/08 1~ 1 -11 12111927 IBP & CROSS-FLOW STP ..- ~ 11/24/08 1 1 MPS-41 11966291 SCMT ~ - ~'o? 11/24/08 1 1 K-05C AWJB-00016 MEM PROD PROFILE p _ ~• j a iy2g/pg 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE ~ p -~ 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- ~ie'" 12/30/08 1 1 K-16AL2 AXIA-00009 MEM PROD PROFILE 0 - d 01/10/09 1 1 01-29 AP3O-00011 USIT '~ '- j 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER &IBP ~-- L.( 01/15!09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESS/TEMP - °' 01/06/09 1 1 R-24 AY3J-00004 USIT 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 AXBD-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 ALYF-00011 INJ PROFILE/WFL .r (~'~ 01/08/09 1 1 07-0$A AYOO-00009 USIT - L 01/22/09 1 1 N-12 12014053 RST 09/30/08 1 1 E-32B AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) t ]~.~. 06/15/07 1 B-27A 11999059 RST ~ ~~ ~ ~~ 11/07/08 1 1 12-37 40018138 OHM D/LWD EDIT _~ '~~- 11/07/08 2 1 N-18A 08AKA0037 OH MWD/LWD EDIT ~Q~ r- -~ 12/24/08 2 1 H-38 08AKA0031 OH MWD/LWD EDIT ~ 12/07/08 2 1 -1~ ~ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 n Date Delivered Alaska Data & Consulting Services 2525 Gambell Street, Swte 400 _ Anchorage, AK 99~~u ~aks ~ ~ ~~ ~~ ATTN: Beth ,~ ~ ~,, Received by: ~,,- ,~ `..: • STATE OF ALASKAV ALA OIL AND GAS CONSERVATION COM~ION ~ ~ ~ ~~ii?I REPORT OF SUNDRY WELL OPERATIONS ~~ ' ~ -- ~~° 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~ ; Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown [] Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r ~ Exploratory r 181-0140 " 3. Address: P.O. Box 196612 Stratigraphic r Service r 6. API Number: Anchorage, AK 99519-6612 50-029-20557-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 79.6 KB PBU N-12 ° 8. Property Designation: 10. Field/Pool(s): . ADLO-028283 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10070 - feet Plugs (measured) None true vertical 9271 - feet Junk (measured) None Effective Depth measured 10010 feet true vertical 9217 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 30"x20" surface - 110' surface - 110' Surface 2681' 13-38/" 72# I-80 surface - 2680' surface - 2680' 4930 2670 Intermediate 9243' 9-5/8"47# I-80 surface - 9243' surface - 8526' 8150 5080 Liner 1316' 7" 29# I-80 8744' - 10060' 8090' - 9262' 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 8791' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" 12.6# 13CR-80 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 63 255 2731 189 Subsequent to operation: 61 325 1351 178 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development r- Service r Daily Report of Well Operations X i6. Well Status after proposed work: Oil r Gas r WAG r GINJ r WINJ ~ WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact Gary Preble t, y;;,~z., i , ~,~ ~ n~ Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 11/17/2008 Form 10-404 Revd 04/2006 1 1 ~~ ~~ ~ ~ Submit Original Only ~l t,J I ~S N-12 181-014 PFRF ~TT~C_HMFNT CJ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base N-12 7/1/82 PER 9,678. 9,700. 8,915.62 8,935.7 N-12 7/1/82 PER 9,720. 9,750. 8,953.97 8,981.36 N-12 2/23/92 SQZ 9,678. 9,700. 8,915.62 8,935.7 N-12 2/23/92 SQZ 9,720. 9,750. 8,953.97 8,981.36 N-12 3/2/92 RPF 9,730. 9,750. 8,963.1 8,981.36 N-12 _ 10/25/94 SQZ 9,678. 9,700. 8,915.62 8,935.7 N-12 12/2/94 RPF 9,735. 9,745. 8,967.66 8,976.79 N-12 1/13/96 APF 9,713. - 9,730. 8,947.57 8,963.1 N-12 11/8/08 APF 9,684. 9,700. 8,921.09 8,935.7 N-12 11/8/08 APF 9,713. - 9,730. 8,947.57 8,963.1 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 11 /8/2008 N-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY *""WELL SHUT IN ON ARRIVAL"*" INITIAL T/I/O = 1800/1800/0. SWAB LEAKING, GREASE CREW SERVICED SWAB. DRIFTED W/ 3-3/8" DMY GUN TO TD @ 9764' ELM. MADE JEWELRY LOG FROM TD TO 8500' ELM. TIED INTO SLB BHCS 5/29/1981 LOG. ""`*JOB CONTINUED ON 9-NOV-2008*"* 11/9/2008~*"`JOB CONTINUE FROM 8-NOV-2008""* MADE 2 RUNS & PERFORATED INTERVALS 9713' - 9730' & 9684' - 9700' W/ 3- 13/8" PJ, 6 SPF, 60 DEGREE PHASING. CLOGS CORRELATED TO SLB CNL LOG DATED 2-FEB-2000, WHICH IS ON <DEPTH WITH REFERENCE LOG SLB BHCS DATED 29-MAY-1981 "SV, WV LEFT CLOSED...MV, SSV, & CASING VALVES LEFT OPEN. FINAL T/I/O = 1800/1800/0. ***JOB COMPLETE"** FLUIDS PUMPED BBLS 1 diesel 1 Total STATE OF ALASKA €~o ~) ~ , 0 ALASKA OIL AND GAS CONSERVATION COMMISSION ~ f REPORT OF SUNDRY WELL OPERATIONS °~J~- ~ U 2008 fi ~ ~.,E ~, ~ , ,., 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® 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 181-014 `' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 SO-029-20557-00-00 7. KB Elevation (ft): 79 6'` 9. Well Name and Number: PBU N-12 - 8. Property Designation: 10. Field /Pool(s): ADL 028283 ~ Prudhoe Bay Field / Prudhoe Bay Pool - 11. Present well condition summary Total depth: measured 10070 - feet true vertical 9271 - feet Plugs (measured) None Effective depth: measured 10010 feet Junk (measured) None true vertical 9217 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 30" x 20" 110' 110' Surface 2681' 13-3/8" 2681' 2681' 4930 2670 Intermediate 9243' 9-5/8" 9243' 8526' 8150 5080 Production Liner 1316' 7" 8744' - 10060' 8090' - 9262' 8160 7020 ~ ~ AUG :~ ~ 2DD8 Perforation Depth MD (ft): 9713' - 9750' Perforation Depth TVD (ft): 8948' - 8981' 4-1/2", 12.6# 13Cr-80 8791' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker S-3 packer 8650' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Tubbing cut and pulled. Cut and pull 9-5/8" casing from 2081'. Run 9-5/8" (47#, L-80) tieback to surface. Cement w/ 145 bbls Class 'G' 814 cu ft / 702 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564-5444 307-219 Printed Name Sondra Stewman Title Drilling Technologist ~ ~) Prepared By Name/Number: 5 nature Phone 564-4750 Dat °~f~~'(~b Sondra Stewman 564-4750 Form 10-4 4 Revised 04/2006 Submit Original Only ~~~I~ .TREE = ~-1116'" CNV WFILHEAD = GRAY _ AGTUA TOR = _. OTIS KB. ELEV = 79.6` BF. ELEV ~ 45.75' KOP - ~_ 320(1' Nr~ x Angie = 33 ~ 6200` Datum NEl = 963$' DatumTVD= 88Q4'88 DRLG DRAFT N~1 2 `;- ~. w fir, L-Sfl, - _2085' 13-3f€3° csG, 72#, L-sa. I~ - 1 z.3d7" 2680' NlttlltllUtTl IC1 = ,~~~'~ $~7g` 4-'1/~" HES XN NIPPLE 2149' I--14-' 2' I iE ~: x Iatl~Pt. ID = 3.s1 s" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3381 3385 14 MMG DOME RK 16 47/07108 3 6024 5715 33 MMG SO RK 20 071fl710$ 2 7522 7009 26 MMG DMY RK 0 0710210$ 1 855$ 7927 28 t~1MG DMY RK 0 07!02/08 8629' ~4-112" NES ~ N!F'FtE, Ifs 'x ~i:~' Sft~iO' 9-51$" X ,~ 1i~ r ~~~ s ~~:F,'. F~ '~_€#i~~ $674` ~- 4-112 I-~~ ~ r' : ,.~ = 3.813„ (4-1f2" OTi XN N1F', ID = 3.725" I 9-5t$" GSG, 47#, L-80, ID - 8.6$1" PERFG'iRATI(?N SUMMARY REF LOG. SWS-BHf:S dN 05/29181 ANGLEATI"OPFEttF: 24 9878' Note: Refer to Production DB for histaricat petfi data SIZE SPF tPd"f'E32VAL OpnlSgz DATE 3-1lf3" 4 9678 - 8700 S 02/23182 3-313'" 12 9713 - 9750 O O i /43196 PBTD _ 10010' 7" LNR, 29#, 1.-80„ .0371 bpf, ~ = 6.184" 90060' . ~. DATE_ REV SY COMMENTS DATE REV BY CaMMENfS Q6102181 ORIGINAL COMRLETION 071tDi08 tTLH CORRG-CTK7NS & GLV G/fl 05/24/05 JNA/PJC ECLIPSE PRTCH '09f19146 DRFlTLH NIP REDUCER((141211t15} 12125!06 RMFUFA ' CORRECT NIP REDUCER'ID 01141!07 RCT,rTLH GLV C/Q v"7)Q4J08 TEES R',~Vt7 - -_ ___ PRUI~IOE BAY UNtT WEI.I: N-t2 PERMT Ne: 181(}140.. API No: 50-029-20557-Q0 SECS. Ti 1 N, R13E BP ~pivration (Alaska) 7" LNR I-1 874$' €>79fl` ~-t~-1r~ 9644' 1---17" MARKER JOINT NS-12 Well History Date Summary 5/8/2007 T/IA/OA= 780/500/0 PPPOT-T(PASS) PPPOT-IC (PASS) (PRE RWO) PPPOT-T (PASS) RU bled tool onto tubing head adapter, 1800 psi bled to 0 psi. 5000 psi for 30 minute test, 4850/15 minutes, 4850/30 minutes. Gland nuts were leaking on 3 LDS adjusted them. Cycled LDS on THA all moved free no bent or broke pins wiped up oil from flange. RD test equipment re installed Alemite cap. PPPOT-IC (PASS) RU bled tool onto IC test void, 0 psi. 3000 psi for 30 minute test, 3000/ 15 minutes, 3000/ 30 minutes. Cycled all LDS on IC flange all moved free no bent or broke pins. RD test equipment re installed Alemite cap. 5/31/2007 MADE DRIFT RUN TO TOP OF DSSSV 02,001' SLM WITH 4.55" GAUGE RING. LATCHED AND PULLED 5 1/2" DSSSV (2.25" MIN. I.D.) 02,001' SLM. 6/1/2007 HAVE MADE SEVERAL ATTEMPTS TO PULL PATCH 08,500' SLM. RIG DOWN SLICKLINE AD RIG UP BRAIDED LINE. 6/2/2007 MADE SEVERAL ATTEMPTS TO PULL PATCH 08,500' SLM. HAD 10 HOURS OF SLB NPT TIME DUE TO UNIT HYDRAULIC ISSUES. 6/3/2007 ATTEMPT TO PULL 5 1/2" ECLIPSE PACKER 0 8500' SLM W/BRAIDED LINE. UNABLE TO GET ANY MOVEMENT LIPHOLE WITH PATCH_ 5 1/2" ECLIPSE PULLING TOOL STILL ON PATCH. (USE 4 1/2" GS TO PULL, 18" O.A.L.) RIG DOWN BRAIDED LINE. 6/26/2007 FISH 5-1/2" ECLIPSE TUBING PATCH, CTU # 9, 1.75" CT: Travel from P2-16 to N-12, MIRU, Perform BOP Test. MU &RIH with WFD 4-1/2" "G" spear. Latch up at 8512' ctmd. Hit 50 iar licks 23-25k over. No luck. POOH for pipe management. 6/27/2007 Pull 5-1/2" Eclipse patch/ CTU #9. ***Continued from 6/26/07 WSR*** UD tools, cut pipe, change out packoffs, MU tools.RlH with same BHA - 4-1/2" G spear. Attempted to null Hatch with 50~oad solid jar licks nulling 24-25K aver, oickuo weight with no luck. POOH with fishing BHA. Break down fishing string, cut 100' of pipe and MU BHA #2 with a 3.625" OD taper tap for pulling the ER packer retrieval tool and RIH. Tag bait 0 8517', pumping. Engage tap, POOH to check fish. ~aiUretrieval tool was not retrieved. 6/28/2007 RAN 4.5 GR TO ECLIPSE PULLING TOOL 0 8515' SLM , SHEARED GR , ECLIPSE TOOL DOESN'T APPEAR TO BE RELEASED ALL THE WAY. 7/5/2007 T/I/0= 450/700/120 ASSIST E-LINE. Pumped 14.6 bbls of crude to test against Plug. Test for 15 min. PASSED. Bled pressure back to 450 psi. FWP= 450/700/120 INITIAL WHP: 375/700/0. SET 5.5" BAKER COMPOSITE BRIDGE PLUG AT 8.505'. OVERALL PLUG LENGTH = 1.65', MID ELEMENT TO TOP OF PLUG 0.65', MID ELEMENT TO BOTTOM OF PLUG 1'. PLUG PRESSURE TESTED TO 1000 PSI FOR 20 MIN. JET CUT TBG AT 8.475' W/ 4.15" POWER JET CUTTER. CORRELATED TO TBG TALLY DATED 02-JUNE-1981. FINAL WHP: 250/700/120. 7/11/2007 T/I/0=200/700/140 [Pre RWO] Circ out. CMIT TxIA FAILED, MITOA PASSED. Pumped 5 bbls neat meth, 1102 bbls 1 % KCL, followed by 150 bbls diesel down Tubing taking returns up IA through jumper line down F/L. U-Tube T x IA to Freeze protect. Freeze protected Flowline per WOA procedure w. 7 bbls neat meth and 114 bbls DSL. CMIT TxIA FAILED 5 attempt's in first 15 minutes MITOA PASSED to 2000 psi- on 1st try. Pressured up w. 2.2 bbls DSL. OA lost 60 psi in first 15 min & 40 psi in second 15 min for a total pressure loss of 100 psi over 30 min. bled OAP. 7/12/2007 ***Continued from 7-11-07*** Attempt to establish LLR. Pumped 14 bbls diesel down tubing- unable to establish LLR, can't pump slow enough. FWHP's= 0/40/60 7/13/2007 T/I/0= VAC/VAC/30. Temp= SI. TBG & IA FL (post MITIA). AL SI 0 casing valve, ALP= 460 psi. TBG FL 0. 990', IA FL 0 30'. 7/14/2007 T/I/O =Vac/vac/20. Temp = SI. Monitor WHPs (pre RIG). IAP decreased 40 psi, OAP decreased 40 psi in 2 days. 7/15/2007 SET BPV, PRE RIG 7/27/2007 T/I/0= BPV/0/30. Temp= SI. Monitor WHP's (SL). Wellhouse, scaffolding, and F/L removed. 7/28/2007 T/I/0= BPV/0/30. Temp= SI. Bleed WHP's to 0 psi (for SL). OA FL near surface. Bled OAP to slop trailer from 30 psi to 0 psi in 45 minutes. Monitored for 30 minutes. No change in pressures. Final WHPs= BPV/0/0. NS-y2 Well History Date Summary 7/29/2007 *** DC 5 STANDBY DUE TO DOYON 14 *** 8/4/2007 T/I/0= 0/0/0. Temp= SI. Pumo 50 bbls of diesel through TWC for freeze protect. ***Note*** Do not exceed 3500 psi. Conducted pre-job safety meeting w/ company man and crew of Doyon 14. Spotted all equipment. Rigged up MIT manifold to wing valve with 1/2" hose. Fluid packed all lines and P.T. to 4000 psi. Strapped diesel source, 29 3/4" (16.53 bbls). Began pumping operations with diesel down tubing. Pumped a total of 7 3/4" (5.05 bbls) away in A hrc Final strap of diesel source, 22". Day crew arrived, made change out. FWHPs= 0/0/0. 8/4/2007 T/I/0=0/0/0. Temp=Sl. Pump 50 bbls of diesel thru TWC for freeze protect. Pumped 5.5 bbls diesel in 12 hrs. Final WHPs=O/0/0. 8/5/2007 T/I/0= 0/0/0. Temp= SI. Pump 50 bbls of diesel through TWC for freeze protect. ***Note*** Do not exceed 3500 psi. Made change out with day crew. Strapped source, 13.875" (6.2 bbls). Began pumping operations. Pumped 8.68 bbls in 12 hrs, for a total of 19.23 bbls of diesel has been pumped. Day crew arrived, made change~out. FWHPs= 0/0/0. 8/5/2007 T/I/0=0/0/0. Temp=Sl. Pump 50 bbls of diesel through TWC for freeze protect. ***DO not exceed 3500 psi.*** Pumped 9 bbls diesel in 12 hrs. Total bbls of diesel pumped 29.2. Final WHPs=O/0/0. 8/6/2007 T/I/0= 0/0/0. Temp= SI. Pump 50 bbls of diesel through TWC for freeze protect. ***Note*** Do not exceed 3500 psi. Made change out with day crew. Strapped source, 19" (9.50 bbls). Began pumping operations. Pumped for 1.5 hrs until fueler came by to fill source. Strapped source, 17.125" (8,26 bbls), 1.24 bbls pumped. Fueler filled source. Strapped source, 36.75" (20.48 bbls). Continued pumping. Day crew arrived, made change out. Strapped source, 24.125" (12.88 bbls), 7.6 bbls pumped. For a total of 8.84 bbls pumped in 12 hrs, for a total of 37.05 bbls; pumped for this job. FWHPs= 0/0/0. 8/7/2007 T/I/0= 0/0/0. Temp= SI. Pump 50 bbls of diesel through TWC for freeze protect. ***Note*** Do not exceed 3500 psi. Made change out with day crew. Strapped tank, 20" (10.14 bbls). Began pumping operations. Pumped 8" (5.08 bbls) in 6 hrs, for a total of 50.13 bbls pumped for this iob. FWHPs= 0/0/0. 8/22/2007 Fish TWC: T/I/0= 0/0/0. Rigged up HO-165 Gray Lubricator, pressure tested to 500 psi. Ran down and tagged TWC 150", Turned polish rod to the right until it dropped into slot on top of mandrel. Attempted several times to turn polish rod. No movement. Locked uptight. Rigged down Lubricator. 9/1/2007 7" BOP rebuild charges for Work Platform Job (Pull stuck TWC). New Hydril Bag and ram inserts. 9/10/2007 COST PLACEHOLDER FOR 5" OD x 24' LUBRICATOR INSPECTION. SN# 60070-4001. TUBOSCOPE INVOICE # 13-122972400 10/7/2007 CTU #9 w/2.375". Rig up for BOP test on Klondike Work Platform. 10/8/2007 CTU #9 w/2.375". Assist with removal of TWC stuck in trek. *** Continued from 10/07/2007 *** Perform BOP test with 400 low / 4000 high -Good test. Assist wellhead techs with attempting to fish TWC. Note: AOGCC inspector, Bob Noble waived witness of test. 10/9/2007 CTU #9 w/2.375". Attempt to fish TWC with WWP. Pump 5 gallons of WD-40 into wellhead and overdisplace with diesel through TWC. Continue assisting wellhead tech attepmting to free TWC. Engage TWC make 1 right hand turn -attempt left hand turn -tool disengaged from TWC - POH -tool lugs were flattened -Plan forward -rebuild tool with larger lugs. Attempt to rotate both directions with new tool with no success. 10/10/2007 FISHED COIL TUBING MILLING ASSY. OFF TOP OF 2-WAY CHECK, RAN 4.50" LIB TO 2-WAY CHECK IN TBG HANGER LIB SHOWED LIGHT IMPRESSION OF TOP OF 2-WAY CHECK RAN 3.80" TAPERED LIB TO 2-WAY CHECK IN TBG HANGER LIB SHOWED THREADS INSIDE 2-WAY CHECK CTU #9 w/2.375" on WWP. Mill TWC stuck in wellhead. Rig up CTU on WWP. Makeup BHA #1 Baker milling string with 3.5" Hollow Mill with 1.75" ID hole. RIH tag 19.4' -start milling -good motor work -lots of vibration - SD check connections, found several studs/nuts loose -Call for make up crew and manlift -Break off well to inspect tools -Tool string was parted at lower disconnect leaving disco body, motor, stabilizer, mill in well. Confer with CTcord/OTL for plan forward.- LD BHA #2 - RU Slick line- Continue MU studs/nuts- All nuts Hi Torqued and marked• Send overshot to BOT shop to break out cross over for slick line tools. Slickline recovered fish. Mill was completely flattened and 0.07' shorter. Slickline ran LIBs determining what remaining plug looked like. NS-12 Well History Date Summary 10/11/2007 CTU #9 w/2-3/8" on WWP. Mill TWC in tree. *** Continued from WSR 10/10/2007 *** Standby on Baker to machine BHA parts.MUBHA #2 /RIH without the Intensifier- w/ 3.5" Hollow Mill -Mill 1/5 hr - no stalls - POH inspect mill -mill had starting of a ring inside - no other wear om mill or stabilizers. RBiH -mill for 1 hr -had several stalls and good motor work - POH inspect mill -same patern as 1st run with the ring now extending inside mill ~1/4" -Both mill runs without the Intensifer has been very smooth and able to hydraulic control the weight. Confer w/ CT Cord - plan forward to run 3.5" parabolic diamond mill - MU/RIH w/BHA #3 w/3 1/2 "Parabolic Diamond Mill- Inspect mill after 1 hour for wear pattern. Appeared to have normal engagement pattern on bottom of mill. Inspected mill after 2 hours. 10/12/2007 CTU #9 w/2.375" and WWP. Mill TWC. Inspect 3.5" diamond parabolic mill after 3 hours of milling. Mill was 2/3 of the way up the cutting structure. Well on vac in tubing. Visual inspection of plug milling pattern on center of plug. Continue milling with seawater. Inspect mill at 6 hours of milling. Wear almost to full gauge on 3.5" mill. Well was not on vacuum when checked. Re-establish communication by pumping 50/50 meth through plug. Pump 10 bbls of 50/50 meth into wellbore down tubing with IA pressure tracking. Resume milling with seawater-inspect mill at 8 hrs - leading edge wearing some outer wear -motor stopped turning -mill inspection after 9 hrs shows marks of being buried into thread body ~4". Make 2 Venturi runs -recover 3/4 cup of soft black rubber. MU/RIH with 3.5" Metal Muncher Hollow (cutrite coating) Mill -Milling -Inspect mill 1 hr, mill showed slight wear pattern on nose as expected. Continue milling with seawater. Inspected mill at 3 hours. Normal wear was seen. Tubing was on vacuum. Confirm hole was tracking down center of plug visually, resume milling. 10/13/2007 CTU #9 w/2.375" with WWP. Mill TWC. Continue milling at 2 bpm on TWC with seawater with 3.5" OD 1.75" ID hollow mill. Inspect mill for wear pattern after 3 hours. Mill showing expected wear , 2 stabilizer fins showing slight wear. Miiling while adjusting weighUrates- POH inspect mill - MiA not cutting but shows no wear- Pictures show marks on plug that correlate with 'weep' holes on bottom of thread body.MU new mill w/tattle tales- Secure well and CT-Cut 110' pipe. RIH with new 3.5 Metal Muncher Hollow Mill- Pull after 3 hrs - a few dings on face, no wear on side. Continue milling for 6 hours. 10/14/2007 CTU #9 w/2.375" with WWP. Mill stuck TWC. Inspect mill after 6 hours. Leading edge of mill showed good wear, inner sleeve showing smoothing 1 "into bore. Makeup BHA #5 with 3.5" Hollow Mill with Opticut facing. Resume milling at 1.6 to 1.8 bpm with seawater. At 4 hours, mill check indicated 4" down outside marked, inside tattle tail marked to 3". Milled additional 1 hr POH mill had normal wear -bottom 3 tattle tails bent. Conduct no flow test -well dead .RIH with PDS Womega camera- picture results were not usable, there was too much glare. Digital pictures revealed similar results as previous pictures, appearance of a core -unable to estimate Iength.Continuemillipg with good motor work - POH inspect BHA he 4thtattle tale (TT) from btm of mill (6") was bent- the 1st TT inside the mill was bent (5") - Measurement to the plug from rig floor confirms the measurements of the mill suaaestina a total of 6" of the TWC has been milled - MU new 3.5" mill dressed with combo of opti cut and metal muncher and new disconnect. Continued milling with seawater adjusting rates to minimize tree vibration. 10/15/2007 CTU #9 w/2.375" on WWP. Mill TWC. Continue milling with 3.5" MM Hollow Mill. Run LIB after 2 hrs of milling. Crescent pattern noted. Continued milling for 2 hours with 5 stalls. On 5th stall, pipe pulled heavy.,POH to inspect mill finding top cap spun upon back of mill. Resume milling with 3.5" Hollow mill with 1.75" ID. Milling, appears headway is being made, tools became stuck, work tools free. POH -inspection of BHA revealed wear on botton of no-go indicating target depth reached. Confer with CT Coord -plan forward to RIH with slickline and set 3.5" tapered tap. Finish LO milling tools - FP CT - RU Slickiine RIH w/ 3.5" Tapered Tap - TT wiA engage to top thread but slips out -appears to be too small. Research options. Decision made to run 4" hollow mill to insure dogs release. Standby on tools being built. 10/16/2007 CTU #9 w/2.375" on WWP. Mill TWC. Standby on Baker to finish building up 4" mill and redress 6" stabilizer. Displace 46 bbls of 50/50 meth from CT into wellbore to insure freeze protected. IA pressure tracked with tubing pressure. Makeup BHA #8 4.00" Opticut Hollow mill w/1.75" ID.for 6" - POH heavy, 8k over -for -6' then normal wt for -14'- Recovered Top Plate of TWC. Conduct no flow test, well dead -visual inspection revealed plug was still in profile. Confer w/ CT Coord of plan forward to manually engage plug with 4 1/8" taper tap. No flow test - RIH w/ TT engage plug -good bite - TT pops out- shear off and POH -RIH fish TT with GS- TT shows signs of fully engaged to n. O a0. Ran tapered LIB -marks are at 4 "Plan forward modify TT and re run. Prepare to re-attempt to latch with re- machined spear. NS-12 Well History Date Summary 10/17/2007 CTU #9 w/2.375" and WWP. Fish TWC. Well remains dead and taking fluid. Attempt to engage plug with remachined taper tap. Screwed inlo top of fish with minimal engagement. Attempt to lift with WWP crane but pulled free at 800 Ibs pull, no obvious marks on taper tap. The top of plug could be seen moving and attempted to fish with a magnet with no success. Attempt to screw in taper tap. Pulled up and poppe tee at 2500 Ibs straight pull with crane. Markings on Taper Tap were on opposite sides engaing 7 wickets. Visual inspection appeared to have a piece of steel across hole. Attempted to fish with 3.8" and 5.5" magnets with no luck. Attempt to re-engage Taper Tap with paint markings. No Luck. 10/18/2007 CTU #9 w/2.375" and WWP. Fish TWC. Engauge two way check and start milling w. 4.0" Opti-Cut Metal Muncher, Pulled BHA after 4 hours of milling and 12 stalls. Cutters and inside ware gave indication of 4" of penitration into plug body. Perform weekly BOP test. MU and RBIH with milling assy. 10/19/2007 Continue milling on Two-way check valve. Pulled off milling after 6 hours. Visually checked condition of plug and found that the lower cap and the plunger assembly had feA down hole. Ran 16' of stem w. spang jars with 2.78" tapered swedge. Tagged 20' down from work platform floor and jarred down a few times. POOH and found marks on swedge at 1.65" OD RIH w. same BHA assembly & new 4" Opti-cut mill. Stick bit and unable to pull free. Disconnect and fish tool string. Free with 1 jar lick. Recovered tool string but no TWC. RBIH with 3.80" OD DSM w. 3.79" string reamer and begin milling again. Milled for 6 hours and pulled milling assembly. Inspection of mill all diamonds worn badly mill taken out of service. Did visual inspection down stack and found TWC seal stuck across lowest ram body. Fished seal out. Measurement from floor to top of TWC originally 20' now at 21' shows that TWC fell with added problem.. Looks like part of olua fell in and is across body. Start fishing with magnet. 10/20/2007 Fish parts of TWC from hanger area. Able to get good friction bite on body of TWC with tapered mill and taper tap spear. Pulled upper ring on TWC 26" to master valve but was unable to work by. Top of ring damaged to badly to recover or any parts of same. Get pilot mill built based on visual inspection of remaining fish. 10/21/2007 RIH w. 3.5" probing 6 bladed carbide mill, start milling and slowly applied WOB once at 4.5k down motor work only came up 120 psi. Pulled up off and stalled. POOH to look at mill and found all six carbide tips worn down. RIH with borescope. TWC setting dogs have fallen in on too of what is left of TWC. Use borescope and 2-prong wire grab in attempt to recover dogs. Able to arab dogs but lose them pooh. Attempt to super suck debris out of hole. Used Super Sucker and retrieved two of the four outer keys from the TWC. RIH w. 4.5"- 5.5" threaded taper tap spear and retrieved upper portion of housing for locking keys; 10/22/2007 Continue manually fishing TWC parts out of hole. RBIH with 4" OD metal muncher mill. Mill for 1.5 hrs. Attempt to catch lower ring of upper body with tapered pin taps with no luck. RBIH with same mill. Mill for 3+ hrs. Saw good motor work. After visual, it appears that mill is entering lower lower body. 10/23/2007 Milled on TWC for three hours total. Face of mill had substantal wear. Changed out with new mill and continued milling on TWC Lost 200 psi off circulation pressure reduced pump rate and POOH. Attempted to close swab valve made only 13 turns and opened backup. Pop off well and found that disconnect had parted. Fish lower disco, stabilizer, motor and mill. Cut 130' of coil. Suck out another TWC dog with super sucker. Able to engage 1.3" OD - 2.0" OD tapered pin tap into inner mandrel. Pulled tap out of mandrel. MU and RIH with 3.5" OD pilot mill and resume milling. Milled for 3 hours put more WOB and no increase on motor work, pulled mill and found cutting surface worn down. Put new metal muncher/opti-cut mill on and continue with milling process. 10/24/2007 Continue milling TWC w. 4" Metal Muncher/Opti-cut mill. POOH to look at wear on mill, looked good. Suspected loose debris on TWC. Super suck and no evidence of any debris. RBIH milling with 4" Metal Muncher/Opti-cut mill. Broke another hydraulic disconnect. Third one on this lob. RIH with baited overshot on slickline toolstring and fish tools. Recovered broken disconnect, motor and mill. Replace disconnect and swap worn 4.0" Metal Muncher/Opti- cut mill for rebuilt one. RIH and begin milling. 10/24/2007 Continue milling TWC w. 4" Metal Muncher/Opti-cut mill. POOH to look at wear on mill, looked good. Suspected loose debris on TWC. Super suck and no evidence of any debris. RBIH milling with 4" Metal Muncher/Opti-cut mill. Broke another hydraulic disconnect. Third one on this job. RIH with baited overshot on slickline toolstring and fish tools. Resume milling with redressed 4" OD MM mill. NS-12 Well History Date Summary 10/25/2007 CTU #9 Continue milling TWC with 4.0" "Opti-Cut" mill. POOH to check mill. String reamer and mill backed off. Fish mill.. Fish Recovered with mill heavily worn. MU and RIH with 2.75" OD crayola mill. Mill for 1.5 hrs. Swapped out millls to pilot mill. 1.6" pi of x D 5-bade mill body. Milled thru TWC after 4 hrs of milling. Swapped out millls to 3.80" OD diamond speed mill and 3.79" OD diamond string reamer. Milled thru TWC. Made several milling and dry passes. Mill gauged 3.75" OD after milling. RDMO. Notify pad operator of well status. ***Job Complete*** TWC milled out to 3.75" OD 10/26/2007 T/IA/OA= 0/0/0 Temp=Sl PPPOT-T (PASS) (POST J-PLUG MILL ) PPPOT-T RU HP bleed tool onto tubing head adapter, 400 psi bled to 0 psi. Cycled LDS on THA all moved free no bent or broke pins. Pressured test void to 5000 psi for 30 minute test, 4850/15 minutes, 4850/30 minutes. RD test equipment re installed Alemite cap. 10/27/2007 RAN 3.625" DRIFT W/ S. BAILER, SD (~ 560' SLM ABLE TO WORK DOWN TO 677' SLM UNABLE TO WORK PAST... RECOVERD METAL BAND ON TOOLS, S. BAILER EMPTY. RAN 3.5" IMPRESSION BLOCK, SD ~ 677' SLM... LIB SHOWS IMPRESSION OF 2" WIDE METAL MARK. LRS PUMPED 34 BBLS NEAT METH DWN TBG... SEE LRS WSR. RAN JUNK CATCHER WITH 3.70" ENTRY GUIDE, SD ~ 677' SLM... TOOLS CAME EMPTY. RAN 3.5" x 10' P. BAILER [mule shoe flapper btm] SD C~ 677' SLM... TOOLS CAME BACK WITH HANDFULL OF METAL PIECES. CURRENTLY IN PROCESS OF RUNNING MAGNET 10/28/2007 RAN VARIOUS TOOL CONFIGURATIONS TO OBSTRUCTION @ 677' SLM. RAN 3.53" MAGNET TO 677' SLM, RECOVERED 1/2" x 3.80" METAL RING. RAN 4-1/2" JUNK BASKET, ABLE TO PUSH FISH DOWN TO 6263' SLM. RAN 3.625" CENT CLEAR DOWN TO 6263' SLM, UNABLE TO WORK PAST. 10/29/2007 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 0/0/0. RIG UP FOR 2 INFLATABLE BRIDGE PLUG RUNS WITH BAKER 3-3/8" IBP'S. 10/30/2007 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 0/0/0. RIG UP FOR 2 INFLATABLE BRIDGE PLUG RUNS WITH BAKER 3-3/8" IBP'S. RUN 1: SET 3-3/8" BAKER IBP (FIRST IBP) WITH MID-ELEMENT AT 6230'. MID-ELEMENT TO TOP OF IBP = 6.50'. LRS PRESSURE TESTED IBP TO 3500 PSI AFTER SETTING. PRESSURE TEST FAILED. IA PRESSURED UP DURING THIRD ATTEMPT. MIT-TxIA FAILED. SECOND IBP CANCELLED. WELL LEFT SHUT-IN. FINAL T/I/O = 0/0/0. ****JOB COMPLETE**** 10/30/2007 T/I/0=0/100/80 Assist E-Line w/ MIT TBG to 3500 psi ***FAILED 2 trys*** CMIT TxIA to 3500 psi ***FAILED 3 trys*** (Pre RWO) Pressure up Tbg to 3500 psi with 24.7 bbls 60/40 meth. Tbg lost 3400-3410 psi in 15 minutes for both tests. (See DATA Tab) CMIT Tx IA to 3500 psi.: Pressured up Tbg & IA w. 60/40 meth. (See DATA tab for fluid volumes & pressures) Tbg lost 360-390 psi in 15 min while the IA would lose 300 -360 psi in 15 min. Bled IAP to open top tank after second test (All Fluid) ***IA & OA left open and tags hung on IA*** FW P's=620/720/80 11/2/2007 LRS Unit 62 Standby for E-line Unit 11/2/2007 T/I/0=0/100/0 Assist E-line w/MIT-T to 3500 psi ***FAIL*** (Pre RWO) Pressured up TBG to 3500 psi with 29 bbls DSL, for MIT. TBG lost 3440 psi in 15 min. Fail. Attempted LLR. LLR was to low to read. Standby for SLB to set up for LDL. 11 /2/2007 W H P 100/100/0 SET BAKER 3 3/8" IBP (SECOND IBP) MID ELEMENT 6015', 1 3/8" JDC FISHING NECK LOCATED 6007.9', OVERALL LENGTH 11.10' WITH TWO 6" SEALS AND ONE 1"SEAL. TAGGED AFTER SET. LRS TESTED PLUG TO 3500 PSI AFTER SETTING PLUG FAILED TEST WITH A LLR OF > 0.3 BPM AT 3500 PSI. RU TO RUN LDL TO DETERMINE LOCATION OF POSSIBLE TUBING LEAK. NS-12 Well History Date Summary 11/3/2007 Assist E-line w/ LDUCMIT TxIA **FAILED** (Pre RWO) Pump 28 bbls 32* diesel down tbg to assist w/LDL. Pump 3 bbls diesel down IA to attempt CMIT TxIA 3000 psi Lost 260/360 in 1st 15 min. FAIL. Pressure up w/5 bbls diesel. Lost 240/330 psi 1st 15 min. FAIL. Pump 24 bbls diesel down tbg to assist w/LDL. FWHP's=200/-0/60 Annulus valves open to gauges, E-line on well upon departure. WHP 100/100/0 RU TO RUN LDL TO DETERMINE LOCATION OF POSSIBLE TUBING LEAK. LOGGED 100 FPM FROM 0'-6000' 5 PASSES WITH AND WITHOUT TAKING RETURNS, DETERMINED SSSV LEAKING AT 2020' TO IA 0.20 BPM 2850 TUBING PRESSURE WITH RETURNS UP IA. SET BAKER IBP (THIRD IBP) MID ELEMENT 1983',WITH 1 3/8" JDC FISHING NECK LOCATED 1975.9', OVERCALL LENGTH 11.10', TW 6" SEALS, ONE 1"SEAL, AND TWO 1"STIFFENER RINGS. TAGGED AFTER SET. WAIT FOR LRS TO TEST PLUG. 11/4/2007 T/I/0= 0/125/60 Temp=S/I Assist E-Iine,MlT T ~ 3500 psi. PASSED (Retrieve TWC pre RWO) Test IBP set C~1 1983' passed, Pumped 1.7 bbls. 50* diesel down to reac test pressure, TBG lost 40 psi. in 1st 15 min. and 20 psi. in 2nd 15 min. for a total loss of 60 psi. in 30 min., Bleed TBG pressure, Test IBP set ~ 500' passed, Pumped 1.2 bbls. 50* diesel down TBG to reach test pressure, TBG lost 40 psi. in 1st 15 min, and 20 psi. in 2nd 15 min. for a total loss of 60 psi., Bleed back pressure, Final WHP's= 0/125/80 11/11/2007 (Tree Change Out /Stuck TWC Inspection) Install Dry Hole tree /Inspected TWC Removed McEvo 6 3/8" tree and installed Gray "Double Master" with Tree Cap assembly. Tyler Norene Report Today we (Moffitt, Shoemake, Michel, Norene, & CIW) removed the tree and viewed inside the tubing hanger. We discovered that t,~ere were two separate pieces of the TWC still remaining. After some persuasion, we were able to recover the uppermost piece (see attachment). We then egan wor ing on the lower body of the plug. We were able to move it -8" up hole with hand jars. Then progress stopped. Some of the leftover cuttings appear to getting along side the plug body. I feel that this lower piece is probably best recovered with a spear run off the rig. It should take very little for the rig to pull this piece as we made a lot of progress by hand. We can discuss making a slickline attempt at recovering this piece, but with the adapter flange and tree valves still it place, the chances of success are reduced because of the reduced ID (6.38") of the tree and adapter flange. The lower plug body (6.31" OD) is currently 1"from entering the larger lift thread profile which ranges in ID from 6.9" at th Other notes for future fishing work and the rig: 11/12/2007 (Tree Change Out) Delivered McEvoy (6 3/8" x 7 1/16") Model "C" Tree to API Valve Shop for R&R 6/12/2008 T/I/0=0/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (1100 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0 psi). Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 3000 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 6/16/2008 T/I/O = 0/0/0 Temp = S/I -MIT OA PASSED to 2000 psi (RWO prep) -Pressured up OA to 2000 psi w/2.7 bbls 50* diesel. OA lost 40 psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 60 psi in 30 min test. Bled pressure to 0 psi. FWP's = 0/0/0 *** Casing valves open to guages, tags hung, DSO notified of well status *** 6/17/2008 T/I/0= 0/120/60 Temp= S/I MIT-T PASSED 3rd attempt to 3500 psi (PREP RWO) Pumped .5 bbls. 70* diesel down TBG to reach test pressure, TBG lost 20 psi. in 1st min. and 10 psi. in 2nd 15 min. for a total loss of 30 psi. in ~~~ ~ ~ ~.~ < 30 min. test. Bleed TBG pressure, Bled back - .5 bbls., Final WHP's 0/0/30 6/19/2008 T/I/0=. Temp=Sl. IA FL. No A/L or flowline. IA FL C~ 660' (28 bbls).***Integral on IA***. 6/20/2008 RIH W/ 2 1/2"JUS, 3" IBP EO. SLEEVE TO 500' SLM. JAR DOWN SAW NO PRESS CHANGE WHEN TOOL LATCHED UP, FOUR LICKS UP AND PULLED FREE, NO WT. GAIN, RIH TO 517' SLM, NOT LATCHING UP POOH, (JUS SHEARD), RIH W/ 3.60 BELL GUIDE, 2 1/2" JUS TO 1682' SLM LATCH UP, POOH WITH WEIGHT INCREASE. NS-12 Well History Date Summary 6/21/2008 PULL 3 3/8" IBP FROM 1983'MD HAD BOTH ELEMENTS & STIFFENER RING. PULL 3 3/8" IBP FROM 6015'MD HAD BOTH ELEMENTS & STIFFENER RING. PULL 3 3/8" IBP FROM 6230'MD HAD ONE ELEMENT, MISSING ONE ELEMENT AND STIFFENER RING. 7/4/2008 T/I/O =0/0/0 Pulled 4-1/16" CIW " H" BPV # 201 ~ 106 " 1-2' ext. used thru tree so 4ES can complete...no problems 7/5/2008 T/I/0=0/0/0 pull 4" ciw bpv thru tree post rig work 7/6/2008 PULL B&R FROM RHC PLUG BODY AT 8779'MD PULLED RK-DGLV FROM STA# 3 AT6024'MD. PULLED RKP-SHEAR VALVE FROM STA# 4 3391'MD. SET RK-LGLV IN STA# 4 AT 3391'MD. WHILE ATTEMPTING TO SET RK-S/O IN STA# 3 AT 6024'MD DROPPED VALVE. RAN 3.70" CENT,2.60" BELL GUIDE,1-5/8" JDC TO RHC PLUG BODY AT 8779'MD(DID NOT RECOVER VALVE) RAN 4-1/2" OM-1, 1.75" LIB TO STA# 3 AT 6024'MD(LIB INDICATES OPEN POCKET) RATTLED MANDRELS WITH KJ,KJ,2.60"BELL GUIDE TO RHC PLUG BODY AT 8779'MD(RECOVERED VALVE). CURRENTLY RIH W/ 4-1/2" OM-1.RK-S/O FOR STA# 3 7/7/2008 SET RK-S/O IN STA# 3 AT 6,024'MD. P1lLLED EMPTY 4-1/2" RHC PLUG BODY FROM XN-NIPPLE AT. 8.779'MD TAGGED SOFT BOTTOM W/ 3.50" CENT.TEL.S-BAILER AT 9,742'SLM + 13' CORK= 9,755'MD(5' OF RAT HOLE) (RECOVERED SAMPLE OF WHAT APPEARS TO DRILLING MUD) RAN PETREDAT SBHPS AS PER PROGRAM.(GOOD DATA) BP EXPLORATION Operations Summary Report Page 1 of 10 Legal Well Name: N-12 Common Well Name: N-12 Spud Date: 5/13/1981 Event Name: WORKOVER Start: 6/19/2008 End: 7/4/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/3/2007 Rig Name: DOYON 14 Rig Number: Date ~I From - To ~ Hours ~ Task ~ Code ~ NPT ~ Phase Description of Operations 6/19/2008 115:00 - 17:00 I 2.00 I RIGD I P 17:00 - 19:00 2.00 MOB P 19:00 - 20:00 1.00 MOB P 20:00 - 22:00 2.00 MOB P 22:00 - 00:00 2.00 MOB P 6/20/2008 00:00 - 01:30 1.50 MOB P 01:30 - 02:30 1.00 EVAL P 02:30 - 04:30 2.00 MOB P 04:30 - 07:30 3.00 BOPSUF~ P 07:30 - 15:30 8.00 BOPSU P 15:30 - 17:00 1.50 PULL P 17:00 - 18:00 1.00 PULL P 18:00 - 22:30 4.50 FISH P 22:30 - 23:00 I 0.501 FISH I P 23:00 - 00:00 1.00 FISH P 6/21/2008 00:00 - 00:30 0.50 FISH P 00:30 - 03:00 2.50 FISH P 03:00 - 05:30 2.50 FISH P 05:30 - 07:15 1.75 FISH P 07:15 - 10:00 2.75 FISH P 10:00 - 10:45 0.75 FISH P 10:45 - 12:30 1.75 FISH P 12:30 - 14:00 1.50 FISH P 14:00 - 15:00 1.00 FISH P 15:00 - 18:30 3.50 FISH P 18:30 - 19:00 0.50 FISH P 19:00 - 20:30 1.50 FISH P PRE PJSM. Scope down and lay over derrick. Rig down rig components. PRE Wait on Security, (change out). PRE PJSM. Move rig components from M pad to N pad. PRE Move on to well N-12. Spot pits, pipe shed and camp. PRE Raise and scope derrick. RU lines to pits. Accept rig at midni ht. PRE Secure well by confirming 0 psi on OA / IA /tubing. RU lines to tree to test IBP. Fill pits with 290 bbls 8.5 ppg seawater. DECOMP Test IBP to 3500 si on chart for 30 minutes. Test ood. DECOMP Bleed pressure from tubing. Bleed voids of tree. ND tree. DECOMP NU BOPE. BOPE arrangement: Annular bag, 3 1/2" x 6" VR, mud cross, Blind/shear rams. DECOMP PJSM. Test BOPE as er AOGCC and BP requirements. Witnessing of test by AOGCC rep Jeff Jones, an ool Pusher. No Failures. All manual valves on mud cross and choke valves tested to 250 / 3500 psi. Blind rams, and VBRs tested to 250 / 3500 psi. VBRs tested w/ 3 1/2" & 5 1/2" OD test jts. Annular preventor tested to 250 / 3500 psi. Drawdown test on accumulator, OK. Upper and lower kelly valves and surface safety valve tested to 250 / 3500 psi. DECOMP Wait on Baker Fishing, (manufacturing spear to fish remnants of two way check valve). DECOMP MU spear to drill pipe. Spear two way check remnant. Pull to floor. DECOMP PU SLB slickline tools. Spot SLB slickline unit. PJSM on slickline rigging and procedure. RU slickline. Attach lubricator to ROPE with shooting flange. Test lubricator to 500 psi. DECOMP RIH with pulling tool to 500'. Attempt to latch and pull IBP #1. Pulling tool released plug, lock pins failed. POH without plug to redress tool. DECOMP RIH with redressed pulling tool. DECOMP Continue to RIH with pulling tool. Latch at 1,682' md. POH. LD IBP #1. DECOMP Change out pulling tool. RIH to 1,983' md. Latch IBP #2. POH. LD IBP #2. DECOMP Redress pulling tool. RIH to 6,015' md. Latch to IBP #3. Attempt to pull. Pulling tool sheared. POH. Redress tool. DECOMP RIH w/ 3.60" bell guide and 2" JDC. DECOMP Crew change, POOH w/IBP #3, pulling heavy, 1200# - 1800# ~ 8 FPM - 70 FPM. DECOMP OOH. Retrieved 1BP & all elements. DECOMP RIH w/ 3.60" bell guide and 2" JDC. Set down and latched up ~ 6220'. Pushed down hole to 6260' SLM. Let IBP relax. Able to pull back up to 6222' & sheared JUS. DECOMP POOH. DECOMP OOH, Pull and cut 200' of .125" wire. Change tool string to RS, OC, X/O, 8' x 2 5/8", X/O, OC, 2 1/8" OJ, OC, & LSS, (1 3/4"). DECOMP RIH, latch up, pull heavy and work slowly up hole, pulling ~ 1800# C~ 30 FPM. Work through tight spot at _ 2,017' (SSSV). DECOMP OOH. Retrieved IBP #4 and all elements. LD IBP. DECOMP RD SLB slickline unit. Printed: 7/24/2008 1:40:40 PM BP EXPLORATION Operations Summary Report (Legal Well Name: N-12 Common Well Name: N-12 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code II Page 2 of 10 Spud Date: 5/13/1981 Start: 6/19/2008 End: 7/4/2008 Rig Release: 8/3/2007 Rig Number: NPT Phase, Description of Operations 6/21/2008 20:30 - 21:30 1.00 FISH P DECOMP RD shooting flange. RU flow riser. Monitor well -static. 21:30 - 00:00 2.50 KILL P DECOMP PJSM on circulating wellbore. Circulate 600 bbls 8.5 ppg seawater at 6 bpm, 770 psi. 6/22/2008 00:00 - 00:30 0.50 KILL P DECOMP Finish circulating 8.5 ppg seawater. Total circulated = 600 bbls. PJSM with crew, TP and WSL on open well. 0 psi on tubing and OA. 00:30 - 01:00 0.50 PULL P DECOMP PU, MU spear. BOLDS in tubing hanger. 01:00 - 02:30 1.50 PULL P DECOMP ear han er. Pull han er to floor. PUW = 150K. LD spear& hanger. Change out elevators. RU control line spooling unit. 02:30 - 07:00 4.50 PULL P DECOMP TOH with 5 1/2" tubing and control line. LD tubing. 07:00 - 07:30 0.50 FISH P DECOMP Service rig. Check PVT system, crown o matic, OK. Conduct daily derrick inspection, OK. Bleed O/A to 0 psi, got back (1) bbl of diesel. 07:30 - 13:30 6.00 PULL P DECOMP PJSM. Continue to POOH w/ 5 1/2" completion string. Laid down total of 208 jts tubing ~ (1 i) GLMs along with SSSV. No visible indication of lost control line bands downhole. Hole fill was 17 bbls over anticipated hole fill. Recovered 26 clamps and 5 stainless steel bands. 13:30 - 15:00 1.50 PULL P DECOMP Clear /clean rig floor. Prep to pick up fishing BHA. 15:00 - 17:30 2.50 FISH P DECOMP Pick up overshot BHA to dress off stub and latch onto stub with overshot and rotate out latch on Baker Packer.. 17:30 - 18:00 0.50 FISH P DECOMP PU 3 1/2" DP. 18:00 - 18:30 0.50 FISH P DECOMP Service rig at Tour change. Check alarms, lubricate equipment, 0 OA psi. 18:30 - 00:00 5.50 FISH P DECOMP Continue to PU 3 1/2" DP. RIH to 8,454' md. Monitor well-static. RU TIW valve. 6/23/2008 00:00 - 01:00 1.00 FISH P DECOMP Weekly safety meeting with crew, TP and WSL. Reviewed and discussed recommendations for changes to new procedure for "Pull /Install Packoff Through BOPE". Also covered use of Sweeney wrench and the 8 Golden Rules (specifically Energy Isolation: Lock Out /Tag Out). 01:00 - 03:00 2.00 FISH P DECOMP Ta tubin stub at 8 467' and with overshot fishing assembly and hollow mill. Dress off 5 1/2" stub at 40-50 rpm. Engage stub with grapple, attempt to rotate and jar fish to release latch with grapple, all No-Go's. Gra le slipped when jars fired. Parameters: PUW=150k, SOW=126k, ROTwt=137 c, pump rate 3 bpm at 340 psi, free torque 3k at 50 rpm. 03:00 - 06:00 3.00 FISH P DECOMP POOH with BHA for change out. 06:00 - 06:30 0.50 FISH P DECOMP Service rig, check crown o matic, PVT system, OK. Perform daily derrick inspection. 06:30 - 07:30 1.00 FISH P DECOMP PJSM. Continue to POOH w/ 3 1/2" DP. 07:30 - 08:30 1.00 FISH P DECOMP PJSM. Stand back collars, UD grapple in overshot. 08:30 - 10:00 1.50 FISH P DECOMP PJSM. Pick up extension, & make up double overshot assembly, drill collars, jars, bumpersub & accellerators. 10:00 - 12:00 2.00 FISH P DECOMP PJSM. RIH w/ fishin assembl on 3 1/2" DP. 12:00 - 13:00 1.00 FISH P DECOMP PJSM. Slip and cut 84' of drilling line. 13:00 - 15:00 2.00 FISH P DECOMP Continue to RIH w/fishing assembly on 3 1/2" DP. 87 stands total. 15:00 - 17:00 2.00 FISH P DECOMP PJSM. Establish parameters. Kelly up. Up wt = 153K, down wt = 125K. Latch up tubing, top of tubing stub ~ 8467' DPM, Jar up on fish a few times l~ 40 - 50K over up wt to get a good bite. Attempt to rotate out K anchor holding 12 - 15K over Printed: 7/24/2008 1:40:40 PM BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: N-12 Common Well Name: N-12 Spud Date: 5/13/1981 Event Name: WORKOVER Start: 6/19/2008 End: 7/4/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/3/2007 Rig Name: DOYON 14 Rig Number: I D t F ;H D i ti f O ti T T k d NPT Ph C , a rom - ours escr p on o pera ons e ; o as ; o e ase 6/23/2008 15:00 - 17:00 2.00 FISH P DECOMP neutral wt. Grapples released w/ 2000 - 3000 Wlbs of torque. Proceed to 'ar on fish tri in 'ars ~ 250K. After about an hour of jarring, fish cam,_e free. Line up pump and observe pressure locked ~ 500 psi, indicating fish on and plug in tubing holdin ressure. 17:00 - 21:30 4.50 FISH P DECOMP PJSM. Stand back kelly & POOH w/fishing assembly. PJSM with incoming crew at 1730. Service rig. Stand back all 3 1/2" DP. 21:30 - 00:00 2.50 FISH P DECOMP LD intensifier, stand back 3 stands 6 1/4" DC's, LD jars, 2 joints 5 1/2" tubing. PJSM on breaking down fish assembly and using hydraulic tubing punch. 6/24/2008 00:00 - 01:30 1.50 FISH P DECOMP Continue breakin down fish. LD tubing patch, seal bore receptacle, one GLM and one joint. 01:30 - 04:00 2.50 FISH P DECOMP Clean and clear rig floor of all tools and debris. Break tubing stub from overshot assembly. Stub measured 14.39'. Estimate top of slick stick at 8,672' md. Break connections on overshot assembly for re-dress to mill packer. 04;00 - 05:30 1.50 FISH P DECOMP MU washover BHA to mill acker; BHA: Washover shoe, 2 jts wash pipe, boot basket, bumper jars, oil jars, float, 9 - 6 1/4" drill collars, pump out sub. 05:30 - 06:00 0.50 FISH P DECOMP RIH with washover BHA on 3 1/2" DP. 06:00 - 06:30 0.50 FISH P DECOMP Crew change. Service rig. Inspect derrick. Check PVT alarms. 06:30 - 09:30 3.00 FISH P DECOMP Con't to RIH w/ BHA #3 on 3 1/2" DP. Ran in hole w/ 87 stands. 09:30 - 10:00 0.50 FISH P DECOMP P/U 5 singles & kelly. Break circulation & tag up ~ 8661' DPM. Wash down to 8675'. 10:00 - 18:00 8.00 FISH P DECOMP Mill packer from 8675' to 8679' P/U Wt = 156K, S/O Wt = 125K, Rot Wt = 140K. 65-75 RPMs, WOB = 5-15K. 4 BPM ~ 600 psi. Free Torq = 2500 ft-Ibs. Mill progress slowed after 4'. Pumped 35 bbl Hi-Vis sweep to clean top of fish. 18:00 - 00:00 6.00 FISH P DECOMP Pre-Tour safety meeting with incoming crew. Continue to mill packer at 8,679' md. Parameters: P/U Wt = 151 K, S/O Wt = 122K, Rot Wt = 140K. 75-80 RPMs, WOB = 15-20K. Dropped pumping from 4.5 BPM ~ 740 psi to 2 bpm ~ 170 psi to try and get bite on fish. Free Torq at 71 rpm = 150 amps, 3250 ft-Ibs. Increase pump rate back to 4.5 bpm X750 psi. 6/25/2008 00:00 - 01:30 1.50 FISH P DECOMP Continue to mill packer at 8679,'. Pump Hi-Vis sweep. Parameters: P/U Wt = 150K, S/O Wt = 122K, Rot Wt = 140K. 75-80 RPMs, WOB = 15-20K average (increased to 25k occassionally to see if mill would bite). Free Torq at 71 rpm = 150 amps, 3250 ft-Ibs. Pump rate 4.5 bpm ~ 750 psi. Pump 30 bbl Hi-Vis sweep. OA = 120 psi at 0100. OA = 0 psi at 0500. Review Tripping Out of Hole procedure with crew. 01:30 - 05:00 3.50 FISH P DECOMP Sweep returns show small amounts of fine metal shavings. POH with BHA to inspect shoe and boot basket. Stand back 3 1/2" DP. 05:00 - 06:00 1.00 FISH P DECOMP LD Pump out sub, stand back three stands 6 14" DC's, LD float, oil and bumper jars. Break off boot basket and inspect. Break off 2 jts wash pipe and change out shoe. 06:00 - 08:00 2.00 FISH P DECOMP Finish breaking out BHA. UD & empty boot baskets. Recovered 3 gals of: pipe dope, scale, smoo, metal millings & a wad of fine steel wool. hoe looked green w/ a maximum of Printed: 7/24/2008 1:40:40 PM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal WeII Name: N-12 Common Well Name: N-12 Spud Date: 5/13/1981 Event Name: WORKOVER Start: 6/19/2008 End: 7/4/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/3/2007 Rig Name: DOYON 14 Rig Number: i I Date ~ From - To Hours CI Task Code NPT Phase Description of Operations 6/25/2008 06:00 - 08:00 2.00 FISH P DECOMP 25% wear. Re-made u BHA w/ new shoe &RIH. 08:00 - 10:30 2.50 FISH P DECOMP Ran in hole w/ BHA #4 on 88 stands of 3 1/2" DP. 10:30 - 13:30 3.00 FISH P DECOMP P/U kelly & break circulation. Tagged up ~ 8679'. Milled from 8679 to 8680'. Lost returns & acker moved down hole. Chased down w/ kelly, hung up once & had to rotate- packer fell. P/U 2 jts & chased to 8696'. Top of slick stick ~ 8680'. P/U Wt = 154K, S/O Wt = 128K, Rot Wt = 140K. Pumped 4 BPM ~ 530 psi. WOB 5-10K. 60-70 RPMs. Free Torq = 3000 ft-Ibs. 13:30 - 17:30 4.00 FISH P DECOMP POOH & stand back 3 1/2" DP. Using continuous fill (~60 BPH) while POOH. Well losing -2 BPM while POOH. 17:30 - 18:30 1.00 FISH P DECOMP Day tour: LD Pump out sub, stand back three stands 6 1/4" DC's, LD float, oil and bumper jars. Night tour conduct tour brief. Pull 2 jts wash pipe and shoe above BOPE and close blinds for well control during "Lay Down BHA" proceudre review with crew. 18:30 - 19:30 1.00 FISH P DECOMP Break off 2 jts wash pipe. Break off boot basket and inspect. Recovered a proximately 10 gals of pipe dope, scale and metal shavin s from millin . 19:30 - 20:30 1.00 FISH P DECOMP Clean and clear rig floor of debris, boot basket, washover shoe. 20:30 - 22:00 1.50 FISH P DECOMP Change out BHA to 4 7/8" grapple to fish packer remains. BHA: overshot guide assembly with grapple, jars, float, 6 1/4" DC's, intensifier. 22:00 - 00:00 2.00 FISH P DECOMP RIH with fishing BHA on 3 1/2" DP. Monitor well and continued filling at - 30 BPH. Total fluids lost to well -420 bbls. 6/26/2008 00:00 - 01:00 1.00 FISH P DECOMP Continue to RIH with fishing BHA on 3 1/2" DP. Monitor well and continued filling at - 30 BPH. 01:00 - 03:00 2.00 FISH P DECOMP Slow rate until tag with fish at _8,702' md. Total run: 89 stands, one single, 24' pup, 10' in on kelly. Attempt to latch to 5" OD slick stick fish with 8 1/8" overshot guide and 4 7/8" grapple. Parameters: PUW=150k, SOW=120k, ROT wt=140k, Free Torque 150 amps / 3000 fUlbs. Set down 15k, varied pump rate from 40 spm ~ 200 psi to 62 spm ~ 440 psi. Could not et ositive indication of latch to fish. 03:00 - 06:00 3.00 FISH P DECOMP POH with BHA. Note increase in drag to 5-7k and increase in fluid lost (should average 2.7 bbls hole fill and took 5 bbls) on first five stands. Rest of the stands took normal fill and drag decreased to 2k. 06:00 - 06:30 0.50 FISH P DECOMP Crew Change. Service rig. Check PVT alarms. Inspect derrick. 06:30 - 07:30 1.00 FISH P DECOMP POOH & stand back 3 1/2" DP. 07:30 - 09:00 1.50 FISH P DECOMP Stand back DCs. Break out & VD Spear assy. Recovered 18.75' slick stick. See photos. 09:00 - 10:00 1.00 FISH P DECOMP Clear & clean rig floor. 10:00 - 12:00 2.00 FISH P DECOMP BHA #6 as follows to fish acker. Spear, 2-Ext, XO, Pony Collar, XO, XO, Bumper Sub, Oil Jars, XO, Bit Sub w/ Float, 9 -DCs, XO, Pump Out Sub, XO. TL = 329.75' 12:00 - 13:00 1.00 FISH P DECOMP RIH w/ BHA #6 on 89 stands of 3 1/2" DP. 13:00 - 16:00 3.00 FISH P DECOMP P/U 2 singles & kelly. Break Circulation 3 BPM ~ 440 psi. I wl slack off & en a e fish. Pump pressure increased 40 psi. Bottomed out w/ soear ~ 8740'. P/U & ensure fish engaged. Pull to 210K fish move, then stuck. Pull to 245K. S/O & begin jarring on fish. Hit 1 ~ 180K, 3 ~ 200K, 7 (~ 225K. Hit once w/ 235K & fish came free. P/U & POOH w/ kelly. Fish Printed: 7/24/2008 1:40:40 PM BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: N-12 Common Well Name: N-12 Spud Date: 5/13/1981 Event Name: WORKOVER Start: 6/19/2008 End: 7/4/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/3/2007 Rig Name: DOYON 14 Rig Number: Date I From - To Hours Task Code NPT Phase Description of Operations 6/26/2008 13:00 - 16:00 3.00 FISH P DECOMP dragged up to max of 220K, then dropped off to string wt while pulling kelly out. Set back kelly & UD 1 single. P/U Wt = 156K, S/O Wt = 126K. 16:00 - 21:30 5.50 FISH P DECOMP POOH w/fish & stand back 3 1/2" DP. Fish initially dragging at 100k over. Crew change at 1800: pre-tour safety meeting and service rig /check alarms. Drag eventually dropped down to ~80k over. Continued with hole fill every five stands at rate of ~30 b h. 21:30 - 00:00 2.50 FISH P DECOMP Stand back three stands 6 1/4" DCs. Break out & UD Spear assy. Recovered packer assembly (see photos). Total fluids lost to well since 0600: 214 bbls. 6/27/2008 00:00 - 01:30 _1.50 FISH P DECOMP Continue handling and LD fish. Used tubing punch to make several holes for pressure and fluid release in 4 1/2" tailpipe assembly below packer. Retrieved 35 gallons sediment / debris from assembly. 01:30 - 03:00 1.50 FISH P DECOMP Clean and clear rig floor of all tools, debris and absorb. 03:00 - 05:00 2.00 FISH P DECOMP Mobilize and MU BHA #7. BHA: 8 1/2" bit, 9 5/8" casing scraper, 2 boot baskets, bumper jar, nine 6 1/4" DC's, pump out sub. 301.29' total length. 05:00 - 06:00 1.00 FISH P DECOMP RIH with scraper BHA on 3 1/2" DP. Total fluids lost to well since midnight --100 bbls. 06:00 - 06:30 0.50 FISH P DECOMP Crew change. Service rig. Check PVT alarms. Inspect derrick. 06:30 - 08:00 1.50 FISH P DECOMP Con't to RIH w/ 89 stands of 3 1/2" DP. 08:00 - 09:00 1.00 FISH P DECOMP Cut & slip 84' of drilling line. 09:00 - 09:30 0.50 FISH P DECOMP P/U 3 jts of 3 1/2" DP & kelly. Break circulation & tag upon top liner ~ 8728' DPM. Scrape casing 4 times from 8685 to 8726'. Circulate 3 BPM ~ 390 psi. 09:30 - 10:30 1.00 FISH P DECOMP Swap valves & reverse bottoms up. Begin ~ 3 BPM & incease to 5 BPM ~ 800 psi. Loss rate -6 bbls in 5 min. Returns were clean. 10:30 - 11:00 0.50 FISH P DECOMP Set back kelly. UD 2 jts. 11:00 - 14:00 3.00 FISH P DECOMP POOH & stand back 89 stands of 3 1/2" DP. 14:00 - 15:30 1.50 FISH P DECOMP Break out & UD BHA #7. Clean junk baskets. Baskets were empty. ear c can rig floor. 15:30 - 16:00 0.50 FISH P DECOMP P/U & M/U 9 5/8" Model 3L RBP. RIH on 3 stands of DCs.. 16:00 - 18:00 2.00 FISH P DECOMP RIH w/ RBP on 3 1/2" DP. Pre-tour safety meeting with incoming crew from 1730-1800. Service rig, check alarms, inspect derrick. Total fluids lost to hole from 0600-1800 is 180 bbls. 18:00 - 19:30 1.50 FISH P DECOMP Reach 8,690' md. Conduct PJSM on setting RBP. Set RBP: Center of Element (COE) at 8,703' DPM, top of RBP at 8,692' DPM. Took two attempts to set. Confirmed set by standing back one stand DP, running back in hole, turn left, set down and PU. All tests show RBP set at expected depth. 19:30 - 20:30 1.00 FISH P DECOMP Pressure test 9 5/8" casing at 3500 psi for 30 minutes charted. Good test. 20:30 - 00:00 3.50 FISH P DECOMP POH with RBP setting tool on 3 1/2" DP. LD one single, stand back 89 stands and LD two singles. 6/28/2008 00:00 - 00:30 0.50 CASE P TIEB1 Finish POH & stand back DCs. Break out & UD RPB running/setting tool. Clear & clean rig floor. 00:30 - 02:00 1.50 CASE P TIEBi R/U to test BOPE: Drain stack. Pull Wear bushing. Install test plug. M/U test jts. R/U test equip. 02:00 - 06:00 4.00 CASE P TIE61 Test BOPE as er AOGCC and BP re uirements. Witnessing Printed: 7/24/2008 1:40:40 PM BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: N-12 Common Well Name: N-12 Spud Date: 5/13/1981 Event Name: WORKOVER Start: 6/19/2008 End: 7/4/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/3/2007 Rig Name: DOYON 14 Rig Number: I Date ;From - To Hours , Task Code NPT Phase Description of Operations 6/28/2008 02:00 - 06:00 4.00 CASE P TIEBi of test by AOGCC rep Chuck Sheve waived. WSL and Tool Pusher on floor to witness. No Failures. All manual valves on mud cross and choke valves tested to 250 / 3500 psi. Blind rams, and VBRs tested to 250 / 3500 psi. VBRs tested w/ 3 1/2" & 4 1/2" OD test jts. Annular preventer tested to 250 / 3500 psi. Drawdown test on accumulator, OK. Upper and lower kelly valves and surface safety valve tested to 250 / 3500 psi. 06:00 - 07:00 1.00 CASE P TIEB1 RD BOPE test equipment. Install Wear bushing. Clean and clear rig floor. PJSM with incoming crew. Inspect derrick, test alarms, service rig equipment. 07:00 - 08:00 1.00 CASE P TIEB1 RU SLB Wireline Services for cement and corrosion evaluation log run. 08:00 - 12:00 4.00 EVAL P TIEB1 RIH with logging tools to prepare USIT composition, cement and corrosion logs. TOC found at 2.120'. POH with tools. Logged from 3000' to surface Locatede collars ~ 2101' & 2062'. 12:00 - 13:00 1.00 CASE P TIEBi RD SLB Wireline Services. 13:00 - 13:30 0.50 CASE P TIEB1 P/U & M/U 9 5/8" Model 3L RBP. RIH on 3 stands of DCs. 13:30 - 14:00 0.50 CASE P TIEBi RIH with RBP on 2lstands of 3 1/2" DP. 14:00 - 17:00 3.00 CASE P TIEBi Conduct PJSM on setting RBP. Set RBP: Center of Element COE at 2 233' DPM, top of RBP at 2,229' DPM. Set first attempt. Confirmed set by standing back one stand DP, running back in hole, turn left, set down and PU. All tests show RBP set at expected depth. 17:00 - 18:00 1.00 CASE P TIEB1 RU sand hopper to DP. Begin pouring 2200 pounds of 20/40 river sand into DP. Pre-tour meeting for incoming crew. Service rig, inspect derrick, test alarms. 18:00 - 21:30 3.50 CASE P TIEB1 ontinue dum in 20/40 river sand into DP. Fill DP with seawater and allow sand to settle for 1 hour. Set down with ettin tool to find to of sand at 2,182'. Circulate one tubing volume of warm seawater. 21:30 - 22:00 0.50 CASE P TIEB1 POH with RBP setting tool. LD setting tool. Stand back DC's. 22:00 - 22:30 0.50 CASE P TIEB1 MU 9 5/8" multi-string casing cutter. BHA: 8 1/4" multi-string Cutter, stabilizer, nine 6 1/4" DC's. 22:30 - 00:00 1.50 CASE P TIEB1 RIH with casing cutter on 3 1/2" DP to 2,083' DPM. 6/29/2008 00:00 - 01:00 1.00 CASE P TIEB1 Continue RIH with 9 5/8" multi-string casing cutter on 3 1/2" DP to 2,083' DPM. 01:00 - 01:30 0.50 CASE P TIEB1 Confirm collar locations at 2,062' and 2,101'. Cut casing at 2 080' DPM. Parameters: PUW=57k, SOW=60k, ROT wt=60k, pump rate started at 60 spm ~ 310 psi and finished at 85 spm ~ 620 psi, free torque 70 amps ~ 1400 fUlbs, cutting torque ranged from 90 amps ~ 2000 ft/Ibs to 120 amps ~ 3000 ft/Ibs. Seawater temp in at 140 degrees, out at 84 degrees. 01:30 - 07:00 5.50 CASE P TIEB1 RU Little Red Hot Oil Service. PJSM with crew, Little Red Hot Oil, TP, WSL on pumping hot diesel and pressured lines. Pump 15 bbls hot (180 degrees) diesel down tubing. Close bag. Pump additional 45 bbls hot diesel down tubing, taking h annulus into o en to slo tank. Follow with 15 bbls warm seawater, taking returns to slop tank. Allow to soak for one hour. Displace with hot (140 degrees) seawater at 5-6 bpm, taking arctic pack returns to slop tank. Shut in for 30 min. Displace again with hot seawater at 5-6 bpm with returns to Printed: 7/24/2008 1:40:40 PM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: N-12 Common W ell Name: N-12 Spud Date: 5/13/1981 Event Nam e: WORKO VER Start : 6/19/2008 End: 7/4/2008 Contractor Name: DOYON DRILLIN G INC . Rig Release: 8/3/2007 Rig Name: DOYON 14 Rig Number: Date From - To I Hours Task Code NPT Phase Description of Operations 6/29/2008 01:30 - 07:00 5.50 CASE P TIE61 slop tank. Monitor returns. 07:00 - 07:30 0.50 CASE P TIEBi R/D hot oiler & lines. 07:30 - 09:00 1.50 CASE P TIE61 Con't to cirulate. 6 BPM ~ 980 psi. When hole came clean. POOH & stand back DCs.POOH w/ casing cutter & UD same. 09:00 - 10:30 1.50 CASE P TIEB1 Clean and clear rig floor. Pull wear bushing. M/U spear assy. BOLDS on 9 5/8" casing hanger. Double check annulus. Spear and Dull hanger free w/ 168K. Pull hanger to floor w/ 100K. Break out spear & UD hanger. 10:30 - 13:00 2.50 CASE P TIEB1 R/U floor w/ false bowl & 9 5/8" power tongs & tools. R/U circulating head & Circulare well ~ 6 BPM, 175 psi. Getting some Arctic Pac back to surface. 13:00 - 21:30 8.50 CASE P TIE61 POOH & UD 9 5/8" casing. PJSM with incoming crew at 1730. Inspect derrick, service rig, test alarms. Using continuous hole fill to break out Arctic Pack to surface tanks. Pipe in good condition visual) .Connections broke at average of 26,000 ft/Ibs. Total of 52 full joints pulled; cut stub measured 21.60'. See pics of stub and packoff. Final circulation rate of 94 spm / 140 psi. 21:30 - 23:00 1.50 CASE P TIEB1 Clean and clear rig floor of tools. Pressure wash tools, floor, equipment of Arctic Pack material. 23:00 - 00:00 1.00 CASE P TIEBi Weekly safety meeting with crew, WSL, TP. Discussed hand injuries, use of tongs, lifting operations. 6/30/2008 00:00 - 01:00 1.00 CASE P TIE61 MU Dressoff and scraper BHA: Dressoff shoe, dressoff mill, boot basket, casing scraper, jars, float, drill collars (length 322.95'). 01:00 - 04:00 3.00 CASE P TIEB1 RIH with BHA on 3 1/2" DP to 2,080' DPM. Stage in with bottom's up every five stands to circulate Arctic Pack out. Average pump rate of 95 spm / 145 psi. 04:00 - 05:00 1.00 CASE P TIEB1 Parameters above stump: PUW=60k, SOW=60k, ROT wt=60k. Tag stump with dressoff shoe. Ease onto stump and begin dressoff. Torque=90 amps / 1900 Wlbs. Dress 1' off stub. 9 5/8" casing stub now at 2,081'. 05:00 - 06:00 1.00 CASE P TIE61 Circulate Hi-Vis pill around to clean cuttings, scrapings and remaining Arctic Pack out of well in preparatoin for casing patch. 06:00 - 07:00 1.00 CASE P TIE61 Circulate well. Pump 30 bbl Hi-Vis sweep. 6 BPM ~ 290 psi. sweep came back clean. 07:00 - 08:00 1.00 CASE P TIEB1 POOH, stand back 3 1/2" DP & 3 stands of 6 1/4" DCs. 08:00 - 09:00 1.00 CASE P TIEB1 Break out & UD BHA. Inpect mill surface, good indication of dress off. Empty boot basket...no recovery. 09:00 - 13:00 4.00 CASE P TIEB1 Clear & clean rig floor. R/U torque turn equip. R/U floor to run 9 5/8" Tie-back string. 13:00 - 17:00 4.00 CASE P TIE61 Ran 9 5/8" 47# L-50 H d-563 casin as er ro ram. Torque turn all connections to 15200 ft-Ibs. Used Jet Lube seal Guard thread compound on all connections. Ran total of 53 jts. Installed free floating centralizer on each jt except last one run. All connections below Weatherford stage tool Baker-Lok'd. 17:00 - 17:30 0.50 CASE TIEB1 P/U 9.86' pup & 3' X-over pup & establish P/U & S/O wts of 97K. Slowly lower string & engage casing stub ~ 2081'. Slack 17:30 - 18:30 I 1.001 CEMT I P I ITIEBI to 130K & casing. PJSM with incoming crew. Printed: 7/24/2008 1:40:40 PM BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: N-12 Common Well Name: N-12 Spud Date: 5/13/1981 Event Name: WORKOVER Start: 6/19/2008 End: 7/4/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/3/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ,I Description of Operations 6/30/2008 17:30 - 18:30 1.00 CEMT P TIE61 Service rig, inspect derrick, check alarms. Pressure test casing to 2000 psi for 30 min (charted). Test good. Increase pressure to 3700 psi to shear opening pins in Weatherford cementer. 18:30 - 21:00 2.50 CEMT P TIEB1 RU SLB cementers. Circulate warm seawater: 100 degrees in, could only reach 70 degrees out. Hold PJSM with crew MI engineer, Halliburton and Weathertord reps, SLB cement team, TP, WSL on cement procedure. Verified crew placement, high pressure zones, returns tanks/pit. 21:00 - 21:30 0.50 CEMT P TIEB1 Pressure test rig lines to 2500 psi. Test cementing lines to 4500 psi. Establish circulation with rig pump. Switch to SLB cement pump and start pumping. 21:30 - 22:30 1.00 CEMT P TIEB1 Pump 145 bbls 15.8 Class G cement at average rate of 5 bpm / 300 psi. Drop p ug and isp ace wit 158 bbls of seawater. Positive indication of bump with pressure at 1700 psi. 22:30 - 23:30 1.00 CEMT P TIEB1 Wash down cement head, clean lines, blow down cement lines. 23:30 - 00:00 0.50 WHSUR P TIEB1 Split BOPE stack at 9 5/8" casing spool flange to prepare for emergency slips and to cut casing. 7/1/2008 00:00 - 03:30 3.50 WHSUR P TIEB1 Continue to split stack. Install emergency slips into wellhead. Set down with 9 5/8" casing to set slips. RD cement head. Attempt to install packoff for casing spool. Packoff was 1"too high. Send to Baker Machine for machining. 03:30 - 07:00 3.50 WHSUR N WAIT TIE61 Waiting on packoff to be re-machined. Transportation time 1 1/2 hrs plus machine time. 07:00 - 09:30 2.50 WHSUR P TIE61 Install packoff for casing spool. Notified Chuck Scheve w/ AOGCC & he waived right to witness test on breaks ~ 0630 hrs. Test pack off 3800 psi for 30 min. 09:30 - 12:00 2.50 BOPSU P TIEB1 NU BOPE. Install test plug. Pressure test BOP at flange connection that was broken choke and kill lines. LP 250 psi, HP 3500 psi. Charted testing. 12:00 - 13:30 1.50 CASE P TIEB1 P/U & M/U 8 1/2" bit BHA #10 to rig floor: Bit, boot collar baskets, jars, 6 1/4" collars, accelerator. 13:30 - 14:30 1.00 CASE P TIE61 RIH with BHA #10 on 3-1/2" DP to 2065'. LD 1 jt, PU kelly. 14:30 - 18:00 3.50 DRILL P TIEB1 PU 60k Ib, SO 60k Ib, Rot 60k Ib; 70 rpm, 150a, 3000 Ib-ft; 5 bpm, 210 psi; 5k-10k WOB. Drilled ES plug and cement 2065' - 2069'. Continued rotating through cement stringers to 2173'. Reverse circulated until clean at 4-1/2 bpm and 350 psi. 18:00 - 19:00 1.00 DRILL P TIEB1 Held crew change and performed pre-tour checks of PVT equipment and derrick. Tagged sand at 2176'. Dry drilled sand to 2183'. Reverse circulated until clean returns. 19:00 - 21:00 2.00 DRILL P TIE61 Blew down kelly and LD 3 jts. POH with BHA #10, standing back 3-1/2" DP. Broke out, LD and cleared boot baskets. Recovered about 2 gallons cement cuttings. LD BHA #10. 21:00 - 21:30 0.50 CASE P TIEBi Pressure tested 9-5/8" tieback casing to 3500 psi for 30 charted minutes. Good test. 21:30 - 23:30 2.00 DRILL P TIE61 MU RCJB BHA #11: jet basket, scraper, boot baskets, bumper jar, oil jar, 9 x DC, POS. RIH on 3-1/2" DP, tagged sand at 2183'. PU kelly, established parameters: PU/SO/Rot 60/60/60; 60 rpm, 80a, 1800 Ib-ft; 4 bpm, 880 psi; 3k WOB. Rotated and washed to 2195'. 23:30 - 00:00 0.50 DRILL P TIE61 POH with BHA #11, standing back 3-1/2" DP. 7/2/2008 00:00 - 01:00 1.00 DRILL P TIEB1 Continued POH with RCJB BHA #11. Stood back drill collars. Broke out and cleared junk basket. Recovered cementing plug Printed: 7/24/2008 1:40:40 PM BP EXPLORATION Operations Summary Report Page 9 of 10 ~ Legal Well Name: N-12 Common Well Name: N-12 Spud Date: 5/13/1981 Event Name: WORKOVER Start: 6/19/2008 End: 7/4/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/3/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours , Task Code NPT Phase j Description of Operations 7/2/2008 00:00 - 01:00 1.00 DRILL P TIE61 and most of aluminum landing ring. LD casing scraper. 01:00 - 02:30 1.50 DRILL P TIEBi RIH with RCJB BHA #12 (same as #11 without scraper). PU kelly, tagge san at otate an was e o 10'. 02:30 - 05:00 2.50 DRILL P TIEB1 POH with RCJB BHA #12. LD BHA, cleared boot baskets. Recovered remainder of aluminum ring. Cleared rig floor. 05:00 - 06:00 1.00 DHB P TIEB1 PU and MU RBP retrieving tool. 06:00 - 06:30 0.50 DHB P TIEB1 Service Rig. Inspect Derrick. Check PVT alarms. 06:30 - 07:00 0.50 DHB P TIE61 Trip in with Retrieving Tool. Tag TOS at 2,186'. 07:00 - 08:00 1.00 DHB P TIEB1 Reverse circulate through sand down to upper RBP at 2,229'. Continue to reverse circulate until clean. 08:00 - 10:00 2.00 DHB P TIE61 Latch RBP.. Work to get unloader valve to open. Unloader valve finally opened. Release RBP. 10:00 - 10:30 0.50 DHB P TIEB1 Reverse circulate two tubing volumes back to surface. No gas. 10:30 - 12:00 1.50 DHB P TIEB1 Trip out with 3 1/2" Drill Pipe standing back in Derrick. L.rY. down u er RBP com lete. 12:00 - 12:30 0.50 DHB P TIEBi Clear and clean floor. 12:30 - 15:30 3.00 DHB P TIEB1 Trip back in hole with Retrieving Tool to lower I~at~o RBP at 8 692'. 15:30 - 16:00 0.50 DHB P TIEB1 Open unloader valve and allow RBP to equalize. Release RBP with 178k Ib PU. 16:00 - 18:00 2.00 DHB P TIE61 Circulate bottoms up (+) at 5 bpm and 980 psi. 18:00 - 00:00 6.00 DHB P TIEB1 Held crew change and performed pre-tour checks of PVT system and derrick. POH, LD 3-1/2" DP. Fluid loss about 10 bph. 7/3/2008 00:00 - 02:00 2.00 DHB P TIEB1 Continued POH, LD 271 jts 3-1/2" DP. Fluid loss stable at about 10 b h. LD 9 x DC. LD RBP and running tool. 02:00 - 04:00 2.00 BUNCO RUNCMP Pulled wear ring. Cleared and cleaned rig floor. 04:00 - 06:00 2.00 BUNCO RUNCMP RU to run 4-1/2" 12.6# 13Cr80 VAM Top tubing. RU single joint compensator and torque turn equipment. 06:00 - 07:00 1.00 BUNCO RUNCMP PU and MU tailpipe ass'y: WLEG, 'XN' nipple, 2 jts tubing, 'X' nipple, and S-3 packer. 07:00 - 18:30 11.50 BUNCO RUNCMP RIH with 4-1/2" 12.6# 13Cr80 VAM Top tubing and accessories. Ran total of 203 jts tubing, 2 pup jts, 'XN', 3 'X', 4 GLMs. 18:30 - 19:30 1.00 BUNCO RUNCMP MU landing joint and tubing hanger. PU 108k Ib, SO 94k Ib. landed tubing hanger. RILDS on tubing spool. 19:30 - 20:30 1.00 BUNCO RUNCMP RD tubing handling equipment. RU to circulate completion fluid. 20:30 - 00:00 3.50 BUNCO RUNCMP Reverse circulated 150 bbls 110 deg seawater followed by 480 bbls 110 deg seawater with EC1124A corrosion inhibitor. Pumped 3 bpm at 110 psi. 7/4/2008 00:00 - 02;00 2.00 BUNCO RUNCMP Held crew change and performed pre-tour checks of PVT equipment and derrick. Droned ball/rod and allowed to fall. Pressured u tubin to 3500 si and held for 30 charted minutes. Bled tubin ressure to 1500 si. Pressured u annulus to 3500 si for 30 charted minutes. Bled tubing pressure, observed DCR valve shear. Confirmed valve shear by circulating through valve in both directions. 02:00 - 03:00 1.00 WHSUR P RUNCMP Installed TWC. Tested TWC from above and below to 1000 si for 10 minutes each. 03:00 - 04:00 1.00 BOPSU P RUNCMP ND BOPE. 04:00 - 05:30 1.50 WHSUR P RUNCMP NU adapter flange and tree. 05:30 - 06:00 0.50 WHSUR P RUNCMP Test Tubing Hanger Void to 5,000 x 30 minutes. Good test. Printed: 7/24/2008 1:40:40 PM BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: N-12 Common Well Name: N-12 Spud Date: 5/13/1981 Event Name: WORKOVER Start: 6/19/2008 End: 7/4/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/3/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ~ Code' NPT Phase ii Description of Operations - _- 7/4/2008 - - 05:30 - 06:00 0.50 WHSUR - - P - - RUNCMP - Test Tree to 5,000 psi. good test. 06:00 - 07:00 1.00 WHSUR P RUNCMP Rig up lubricator and test to 500 psi. Pull TWCV. Lay down same. 07:00 - 10:00 3.00 BUNCO RUNCMP Rig up Lil' Red. Pressure test line at 3,000 psi. Good. Pump 150 bbls of Diesel down IA. Rig down Lil' Red. 10:00 - 11:00 1.00 BUNCO RUNCMP Allow diesel to u-tube and freeze protect the tubing. Start to rig down misc equipment. 11:00 - 11:30 0.50 WHSUR P RUNCMP Install BPV. Test at 1,000 psi x 10 minutes. 11:30 - 3:00 1.50 RIGD P RUNCMP Rig down Pits and Pipe Shed and prep to move. Scope down and lower Derrick. Secure cellar. Release Rig. Printed: 7/24/2008 1:40:40 PM ~chlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ ~~~~ JU~ ~ ~ 2005 N0.4783 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~gI- 8~~ 07/16/08 ~~ BP Exploration (Alaska) Inc. Alaska Data & t;onsuinng Services Petrotechnical Data Center LR2-1 - 2525 Gambell Street, Suite ` 0 900 E. Benson Blvd. Anchorage, AK 9 3-28 Anchorage, Alaska 99508 ATTN: Beth Received by:- Date Delivered: ~'' 'i i "~'~ N-12 workover Sundry No. 307-219 • • Maunder, Thomas E (DOA) From: Reem, David C [ReemDC@BP.com] Sent: Thursday, June 19, 2008 8:35 AM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L Subject: RE: N-12 18( 1.014) workover Sundry No. 307-219 Page 1 of 2 Tom, coil milled out the core of this fine plug with a 4" OD mill. The TWC is a 6-3/8" Cameron "J" so there is still chunkies of former TWC in the profile. It will all come out when we pull the hanger and head it, the hanger, to the metal dumpster.... Terrie, could you get a operational summary from Doug Cismoski for all of the coil operations per Tom's request below? Thanks. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 19, 2008 8:21 AM To: Reem, David C ~~N~D ~~~ ~ ~ 2~~$ Subject: RE: N-12 (181-014) workover Sundry No. 307-219 Dave, I was reviewing the file to make sure all documents were there. This work was delayed by the stuck TWC and eventual milling. The last operational information we have in the file is when Doyon 14 moved off the well at the end of July. There are emails and procedures for the eventual milling of the plug, but no operational summary. Please be sure that Terrie includes any work since July last year in the 404 report she files. One question, were the remains of the TWC fished or is that a task still to be accomplished? Tom Maunder, PE AOGCC From: Reem, David C [mailto:ReemDC@BP.com] Sent: Wednesday, June 18, 2008 8:40 AM To: Maunder, Thomas E (DOA) Subject: RE: N-12 workover Sundry No. 307-219 Thanks Tom, all pressures are the same as before so we will proceed under the current Sundry. DCR From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, June 17, 2008 5:30 PM To: Reem, David C Subject: RE: N-12 workover Sundry No. 307-219 Dave, Are the pressures and all still the same? if you all can verify that the basis is still the same, it should not be necessary to do a new sundry. Tom Maunder, PE AOGCC From: Reem, David C [mailto:ReemDC@BP.com] 6/19/2008 N-12 workover Sundry No. 307-219 Page 2 of 2 • • Sent; Tue 6/17/2008 4:26 PM To: Maunder, Thomas E (DOA) Subject: N-12 workover Sundry No. 307-219 Tom, this fine well was scheduled to be worked over last July but a mis-set on atwo--way check caused us to take our rig and go elsewhere.....well now we're fixin' to go back onto this well and it is my assumption that the Sundry that was good back then is still good as the overall gist of the Sundry and workscope has not changed much other than we plan to remove the old production packer. Do you need/want an additional Sundry application for this job? Pls let me know as the rig (yep, 4ES) is breathing down my neck and will be on this well in ~3 days....Thanks. Dave Reem 6/19/2008 RE: PBU N-12 (181-014) • • Maunder, Thomas E (DOA) From: Cismoski, Doug A [CismosDA@BP.com] Sent: Friday, October 26, 2007 3:17 PM To: Maunder, Thomas E (DOA); Reem, David C; Roach, Frank Cc: Grimaldi, Louis R (DOA); Regg, James B (DOA) Subject: RE: PBU N-12 (181-014) Attachments: N-12 Wreline Work Request.xls Tom - Page 1 of 2 Coil successfully completed milling a 3.75" hole through the two-way check on N-12. The plug body is still stuck in the tubing hanger area. I've enclosed a work request form that outlines our plan going forward. The positive pressure packoff test (PPPOT-T) on the tubing is to ensure we have two seals in the tubing hanger to act as mechanical barriers from the inner annulus. The inflatable bridge plugs (IBP's) in the tubing are to ensure we have two mechanical barriers in the tubing. With two mechanical barriers in place, we are within BP and the State's policies to nipple down the tree. The procedure currently calls to remove the tree and recover the TWC remains. I need to confer with the rig team and determine if this is necessary. An alternative plan may be to move the rig over the well and spear the TWC/hanger and bring to the floor. We'll forward our plan beyond setting the IBP's to you per Frank Roach's original note in August. Doug Doug Cismoski, PE Wells Team Leader Alaska Drilling and Wells From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, October 06, 2007 8:36 AM To: Cismoski, Doug A; Reem, David C; Roach, Frank Cc: Grimaldi, Louis R (DOA); Regg, James B (DOA) Subject: RE: PBU N-12 (181-014) Doug, et al, With regard to the failed CMIT x IA ... 1. What were the particulars about the pressure test? What pressure was achieved, how did the pressure decline? Were there IA pressure problems noted previously? Is a Cretaceous leak suspected? 2. Is there any pressure on the well now? 3. Again, I would like to receive a copy of the well services report of the work done prior to the rig moving on the well. Thanks in advance. Tom Maunder, PE AOGCC -----Original Message----- From: Cismoski, Doug A [mailto:CismosDA_~BP.com] Sent: Thu 10/4/2007 2:51 PM To: Maunder, Thomas E (DOA); Reem, David C; Roach, Frank Cc: Grimaldi, Louis R (DOA); Regg, James B (DOA) 6/19/2008 RE: PBU N-12 (181-014) • ~ Subject: RE: PBU N-12 (181-014) 1. FasDril was set and tested @ 8505'. . 2. Tubing was PT'd to a 1000 psi immediately after setting the FasDril plug and before cutting the pipe. 3. After cutting the pipe and circulating the well with 1% KCI, a combo-MIT TxIA failed. We are still a couple of days away from this work. The contingency if we cannot rotate the TWC's mandrel is to rig up coil and core the mandrel allowing the dogs to retract. Doug From: Maunder, Thomas E (DOA) [mailtoaom.maund_ er cr,alaska.gov] Sent: Thursday, October 04, 2007 11:23 AM To: Reem, David C; Roach, Frank; Cismoski, Doug A Cc: Grimaldi, Louis R (DOA); Regg, James B (DOA) Subject: PBU N-12 (181-014) All, Not sure who can answer my questions/request. I am informed that the Klondike work platform is presently being mobilized to N-12 to pull the TWC that became stuck in the wellhead when Doyon 14 was on the well in early August. I would appreciate receiving a copy of the planned procedure for removing the TWC as indicated in Frank's email of August 8. Also, I'd appreciate receiving a copy of the pre-rig work that was preformed prior to Doyon 14's arrival. Items I am particularly interested in are ... 1. Was a Fasdrill plug installed in the tailpipe as planned? 2. Has the well (T and IA) passed a positive pressure test during any of the work? 3. Is any IA compromise known? Thanks in advance for the information. Tom Maunder, PE AOGCC Page 2 of 2 6/19/2008 Wireline Work Request Alaska Wells Group weir: N-12 Date: 10/26/07 IOR AWGRS Job Scope: ~ri12006 / J~2007 (TLH N-12 AFE: PBD4P9278 H2S: Engineer: Burnett 10-403? WBL Cat. IOR 10-404? SECURE WELL Problem Description Secure well to recover TWC body which has been milled out. No Data N N Initial Problem Review Remains of TWC to be removed from tubing hanger of N-12 after securing well with 2 IBP's TWC was milled to 3.75" ID with coil on 10-25-07 Remedial Plan - WIRELINE ACTION 1. PPPOT-T 2_ SL to Drift to 8400' with 3.625"(above jet cut at 8475') through milled out TWC with I D of 3.75" 3. EL to set 3-3/8" IBP in first full joint above mandrel #2 @ ~ 8365'. PT to 3500~si ____ _ noting any LLR and volumes pumped 4. __ EL to set 3-3/8" IBP in middle of joint ~ 500' PT to 3500 psi notin an LLR and volumes pumped 5. Ron Doshier to check on any possible problems setting IBP with 60140 methanol (suggested possible use of reservoir tool) Remove tree and recover TWC bod /remains 11/12/07 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wPu .Inh ~ I ,,,, no~~.I..*~,,., n~~.. NO. 4496 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.eay, Lisburne Q~ r,.~,,. nn L3-08 11637143 LDL - C{ 10127/07 1 L3-08 11637143 LDL - 4 10/28107 1 N-12 11626132 LDL ( (-~(G 11/03/07 1 14-18B 11637368 ISOLATION SCANNER '~-- 10/26/07 1 NGI-13A 11637144 CEMENT BOND & IMAGE LOG - <, 10/28/07 1 GNI-04 11676971 USIT (~-- J'a- 11/05/07 1 r ~cMJC r+~.nrvvvYl..GVVC RCNCIr'1 DT JWIVIIVb NIVU RCIUKIVIIVl7 VIVO I..VYY tAlai IU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ,, °~ 900 E. Benson Blvd. Anchorage, Alaska 99508 ,.,~ ~ ~~~tp~~,~ ~ ~ ~ ~9Cs~ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2836 ATTN: Beth ', %i Received by: - N-12 Procedure for TWC rel. Page 1 of 1 • Maunder, Thomas E (DOA) From: NSU, ADW Weli Operations Supervisor [NSUADWWeIiQperationsSupervisorat7BP.com] Sent: Tuesday, October 49, 2447 9:25 AM To: Maunder, Thomas E (DOA) Cc: Cismoski, Doug A; Bixby, Jerry L; Olsen, Clark A; NSU, ADW Weil Operations Supervisor Subject: N-12 Procedure for TWC removal. Attachments: N-12 WWP DRAFT Revision2Milling.ZlP; N-12 BHA Drawings.ZlP; 100_1634.ZIP Mr. Maunder: Doug Cismoski asked me to send you the procedure far N-12. He is currently in the well intervention masters class this week. If you need any additional information, you may get back to us at your convenience. We have complete our BOP test and are working with the drill pipe/running tool at the present time. This corresponds to step 10b, page two, of the attached procedure. Thank you far your assistance. Bob Clump Step up WOS for ADW (For -Jerry Bixby/Clark Olsen) 907 659-5872 Office 907 943-1004 CeN `~ = ~~~ N 0 ~ ~ 20x7 «N-12 WWP DRAFT Revision2Mii[ing.ZlP» «N-12 BHA Dr'awmgsZlP~~~`«100 1634.ZIP» 10/19/2007 • by To: Bob Clump/Jerry Bixby Date: October 5, 2007 Wells Group Operations Supervisors From: Rob Liddelow/Kirk ForcadelMike AFE: PBD4P9278-D Shoemake/Bill Rochin/ GPB Wells Special Projects Engineers c~i Subject: Well N-12 Fish or Mill 6" Type "J" TWC IOR: `D ~ ~~ ~' Revision 2 Obiective: To safely remove and retrieve the 6 3J8" CIW "J" Ptug from N-12. If retrieval fails then go into milling operations with CTU. History: Prior to the rig's arrival a Cameron 6-3/8" CIW "J" BPV was set. Once the rig was over the well, the DSM crew was called to retrieve the BPV and did so without incident. After circulating the diesel from the wellbore the Cameron wellhead hand seta 6 3/8" CIW "J" TWC to prep for tree removal. Four attempts were made to test the TWC from above. Approximately 1 bbl of fluid was pumped past the plug and 3500 psi could only be held for a few seconds on each attempt. The decision was made to pull the TWC and install a new one. While attempting to pull the plug, it was discovered that the lock mandrel which releases the plug dogs would not turn. Extra force was applied on the parmalee wrench used for turning the lubricator's polish rod. This had no effect on the stuck mandrel. The Wells Group went out and rigged up an HO-165 Gray Lubricator and attempted to get the inner mandrel to move with the polished rod. Several attempts were made to rotate the polished rod to the right with no success. The recommendation is to try and get the mandrel to rotate to the right by utilizing the Klondike Wellwork Platform. If moving the mandrel proves to be successful in releasing the dogs and thus freeing the TWC, a Lubricator will be rigged up and the TWC wilt be retrieved. If this procedure is unsuccessful then Milling operations with CTU will commence. CONTACT NAME OFFICE CELL /PAGER BP Klondike Wellsite Leaders Liddelow Shoemake/Rochin 659-5580 229-4596 BP Well O erations Su ervisor Bob Clum / Jer Bixb 659-5872 ADW Wells Pro~ect WSL. Rob Liddelow /Bob Clum 659-5580 ADW Wells Wireline WSL Ken Bulloch / D Varble 659-5541 ADW Wells Tree Re lacement WSL D. Moffitt / D. Kondelik 659-5545 VECO Valve Sho Su ervisor om Dolan / Joe S audlin 659-5046 CAMERON Wellhead Su enrisor C. Renner / M. Kerschion 659-4246 659-3582 • • T1NC Retrieval Ma"or Ste s: 1. Rig up the Klondike Wellwork Platform onto well slot N-12. Utilize a barrel pump to evacuate the tree of any wellbore fluids then RU 7" BOPE on top of the tree. Ensure we have a way to monitor the annulus and the tubing to an open top tank (well control). 2. While the Klondike is RJU and the tree / BOP's are free of fluid, dump 5 gallons of WD-40 on top of the master valve gate thru the BOP stack. 3. Pressure test BOPE to 500 psi low and 3,500 psi high for 5 charted minutes each. Note: SLB to be on location to conduct test. Triplex will be used to pressure up on stack. (Notify AOGCC) 4. Once the BOPS test is complete, rig up a triplex to the Otis connection on the WWP floor/ open the master valve and pump diesel down hole in an attempt to displace the WD-40 thru the TWC valve to aid in lubricating the metal x metal parts of the TWC. Do not exceed 3500 PSI. Pressure up on the plug with the IA casing valve open to take returns. Allow pressure to bleed off out the annulus before pressuring back up to 3500 PSI. Continue this process until -1-2 bbl's have been squeezed away. 5. Rig up T-Bar with with modified equalizing tool that does not thread into TWC. Before running in with T-Bar make sure that choke is open to tank and that a pit watcher will be on the pit while well is open, if any flow is observed at anytime pull T-Bar out and secure well. If no flow is observed run to the top of the 6-3/8" TWC and "off seat" the poppet to confirm there is no trapped pressure under the TWC by monitoring the flow into the tank to make sure there is no pressure. 6. Once the poppet has been "off seated" and no trapped pressure under the plug has been confirmed then rig down the T-Bar. 7. PU 3-1/2" Joint of Dri{I Pipe with 6-3/8" TWC Running Tool already pinned and M/U onto the Joint of 3-1/2" Drill Pipe. 8. Slowly lower the Joint of Drill Pipe to the top of the TWC. Utilize a 5' marking stick to measure and record how far down the TWC is found. Work/Lower the DP until the running tool engages. 9. Ensure that the IA casing valve and the pump-in sub valve are open to the open top tank and monitor for flow before attempting to rotate the 3-1/2" Drill Pipe. Note: Conduct BOPS Drill and Function Bag around drill pipe. 10 . The mandrel is threaded to the set position. The mandrel must be rotated to the right (clockwise) to have it unthread and thus allow the dogs to retract. a.) First attempt at getting the mandrel to rotate with the Joint of 3-1 /2" Drill Pipe should be done by utilizing a single, double or even triple set of chain tongs. This may provide enough torque to get the mandrel to move. Note: Hold PJSM and risk assessment on proper chain tong usage. b.) If chain tongs prove to be unsuccessful, R/U Load Cell and manual tongs. Attempt to rotate the 3-1/2" DP to the right. Note: The Pad Eyes are rated to 5,000-Ibs of force from a horizontal direction. Do not exceed 80% of the rating while operating manual tongs. Baker Fishing will be on hand to assist in operation. c.) If manual tongs prove to be unsuccessful, RU GBR Casing 4-1/2" power tongs. Ensure that the power unit from the truck is RU correctly to provide hydraulic power to the Rig Floor via hoses. Attempt to rotate the Joint of 3-1/2" Drill Pipe to the right. Ensure the Joint of Drill Pipe is snubbed off in the opposite direction so that it stays centered and vertical over the welt. Note: Ensure the hydraulic hoses are tied off so that they do not impede emergency egress. GBR to be on hand to assist in operation. • • 11. If successful on getting the mandrel to move, continue backing out the mandrel 2 full rotations. Once this is accomplished, back the Running Tool and Joint of Drill Pipe off the TWC and POH. • If the mandrel is easy to move, then back the Running Tool and DP off the TWC and prepare to P/U the Lubricator to retrieve TWC. • if the mandrel is difficult to move, close the Annular Preventer then continue to turn the mandrel an additional 5 turns or until it is free. Check for pressure in Tree and open Annular Preventer. POH w! DP and Running Tool. 12. RU the Lubricator and pressure test it to 500 psi (P/T against closed Master). Retrieve the TWC. 13. RD the Lubricator. RD the Klondike Wellwork Platform if TWC retrieved. Contingency If TWC is not recovered proceed with milling operations. MILLING 4PERATI4NS 1. RD the Drill Pipe and ensure well has been secured, rig up CTU for Mi{ling operations. 2. Rig up BOP control lines in a manner that enables functioning from the CTU ops cab and function test BOP's. 3. Ensure flow cross is hooked up thru choke skid to tanks and can be lined up to bleed tubing or pump if required. Ensure IA is tied in to choke skid and pressures can be bled J monitored. 4. Rig up Baker BHA option #2. 5. Pressure test Coil and stack to 500 ! 3500 psi 6. RIH w/ 3.5" mill and tag TWC, mill 12" until no-go contacts top of TWC 7. POOH, Rig down Coil and Rig up Slickline. If OD Running threads from TWC are not recovered on mill proceed to step # 8. If threads are recovered proceed to step #9. 8. RIH w/ ~ 4.2" box tap on Slickline to retrieve OD Running threads of TWC. Have 3.5" taper tap on hand if box tap is not successful. (The box tap and taper tap .are being built. Weatherford Machine) 9. Make up 3.5" Baker tap baited to Baker "G" fishing neck. (Baker "G" neck has hex which enables engagement and rotation if needed to release.) Baker is building tap w/ no-go to control depth of engagement and not interfere w/ the ability of the dogs to retract into the body of the TWC and enable the TWC to release. 10. RIH w/ Slickline accelerated toolstring, GS and baited tap asst'. Plant tap and jar TWC body free. 11. If unable to pull TWC w/ slickline, Coil could be utilized to jar or to engage Baker "G" fishing neck and unscrew tap or the tap could be engaged and unscrewed using 3-112" Drill Pipe. • The Cameron "J" TWC requires 7.25 turns to fully open the plug's dogs. The turns were counted and 7.25 turns was obtained. With the dogs full open the plugs OD is 6.9" and the bore of the tree is 6.3". In addition we have visual confirmation the mandrel is screwed down to the top of the plug which is only possible if the dogs are fully open. It appears at this time that the plug's dogs are set in the lift threads of the tubing hanger. Other than the normal dog profile, the only ID that is big enough for the dogs to be in the full open position is the tubing hangers lifting threads. Baker Machine Shop is building the Running ToollDP tool to be used in this job. Ensure that a lift nubbin is available for handling the 3-1/2" IF Joint of DP and that the proper TIW Valve is available for it. The pad eyes on the Klondike are only rated to 5,000 Ibs of force from a horizontal direction. If these methods prove unsuccessful in achieving the clockwise rotation of the inner mandrel on the TWC, consideration should be made to milling up the TWC. When running T bar to check that there is no trapped pressure, mark the T bar and measure exact distance from the top of TWC and confirm lengths to rams and hydril Top of TWC is 9 inches above base flange. Distance from TWC to Blind rams = 13.6'. Baker Toolstring option #2 = 13.4' to top of lower disconnect. During milling operations, Toolstring option #2 the spaceout places the 2-718" motor across the variable rams and the hydril will close right above the top stabilizer. Base flange to Swab valve = 8'. All baited assys. must be less than 7' to allow for Swab valve closure if bait is left in wellbore. • -~ ~ :. . _ ~.~ .~ E ; ;~, }E • Operator: BPXA Tubing: ^ Well: N-12 CasinglLiner: sAKER Date: Well Fluid NV6ME.S C M MIKE SHOEMAKE Lease: WOA an: o. Job Type: CHECK VALVE M ILLING ASSEM BLY -OPTION #1 Baker Oil Too ls Proposed Equipment 8 Service OD ID Serial Length Totat BHA (inches) (inches) No. ffeeq 1~1 2 2/8" COIL TUBING CONNECTOR 3.38 1.00 ZAF00579 0.95 0.95 2 3/8" REG Pin Fishing neck - 3.13" EXTERNAL 134k# Max Tensile DUAL FLAPPER CHECK VALVE 3.13 1.00 10013428 1.57 2.52 2 3/8" REG Box x Pin 150k# Max Tensile 4,000 ff/Ibs. Max Torque BOWEN JAR INTENSIFIER 3.13 1.25 9711040 7.80 10.32 2 318" REG Box x Pin 40k# Max Overpull to Fire 233k# Max Overpull After Fire 3,000 ft/Ibs. Max Torque HIGH LOAD HYDRAULIC DISCONNECT 3.38 0.81 ZADHD307 1.45 11.77 2 3/8" REG Box x Pin 7/8" Ball - 3,300psi - 3 GS 94k# Max Tensile 4,000 ft/Ibs. Max Torque O RUPTURE DISK SUB 2 3/8" REG Box x Pin 3.13 1.00 BOT 0.56 12.33 CROSSOVER SUB 3.00 1.00 ZAD005 0.49 12.82 2 3/8" REG Box x 2 3/8" PAC Pin • Operator: BPXA Tubing: ~/`^ Well: N-12 Casing/Liner: BAKEER Date: Well Fluid NVGMES MIKE SHOEMAKE Lease: WOA Co. Man: OPTION #2 B Barer Oil Too ls Job Type: CHECK VALVE M ILLING ASSEM LY - proposed Equipment 8 Service OD ID Serial Length Total BHA (inches) (inches) No. (feet) (feet) 2 218" COIL TUBING CONNECTOR 3.38 1.00 ZAF00579 0.95 0.95 2 3/B" REG Pin Fishing neck - 3.13" EXTERNAL 134k# Max Tensile DUAL FLAPPER CHECK VALVE 3.13 1.00 10013428 1.57 2.52 2 3/8" REG Box x Pin 150k# Max Tensile 4,000 fUlbs. Max Torque BOWEN JAR INTENSIFIER 3.13 1.25 9711040 7.80 10.32 2318"REGBoxx Pin 40k# Max Overpull to Fire 233k# Max Overpull Aker Fire 3,000 ft/Ibs. Max Torque HIGH LOAD HYDRAULIC DISCONNECT 3.38 0.81 ZADHD307 1.45 11.77 2 3/8" REG Box x Pin 7/8" Ball - 3,300psi - 3 GS 94k# Max Tensile 4,000 Wlbs. MaxTorque CROSSOVER SUB 3.00 1.00 ZAD005 0.49 12.26 2 3/8" REG Box x 2 3/8" PAC Pin SPIRAL STABILIZER 3.75 1.38 BOT 1.02 13.28 .._ 2 3/8" PAC Pin x Box CROSSOVER SUB 3.13 1.60 ZAF01022 0.52 13.80 2 3/8" PAC Pin x 2 3/8" REG Pin HIGH LOAD HYDRAULIC DISCONNECT 3.38 0.56 ZADHD309 1.53 15.33 2318"REGBoxx Pin 5/8" Ball - 3,300psi - 3 GS 94k# Max Tensile 4,000 ft/Ibs. Max Torque EXTREME "X" MUD MOTOR - 2 7/8" BODY 3.13 / 10324288 10.73 26.06 2 3/8" REG Box x Box Max Flow - 120 GPM Max Speed - 490 RPM Nominal Torque - 620fUlbs Tensile - 80k# - STABILIZER W/BRASS TATTLETALE PADS 6.00 1.00 BO'f 0.65 26.71 a ~ ~~ 2 3!8" REG Pin x Box METAL MUNCHER HOLLOW MILL 3.50 1.00 BOT 0.98 27.69 2 318" REG Pin W/ 1.75" I D x .76' LONG BORE BHA DRAWING PREPARED BY: JOHN MILNE BAKER TOOLS LENGTH 27.69 Copyright ©2006. Baker Hughes Incorporated. All rights reserved. No portion of this material may be copied, transmitted, or stored via any electronic media without the express written permission of Baker Hughes Incorporated. RE: PBU N-12 (181-014) ~ Page 1 oft Maunder, Thomas E (DOA) From: Cismoski, Doug A [CismosDA@BP.com] Sent: Saturday, October 06, 2007 3:17 PM To: Maunder, Thomas E (DOA); Reem, David C; Roach, Frank ~? Cc: Grimaldi, Louis R (DOA); Regg, James B (DOA) ~ b ~ ~ ~ ~ `` Subject: RE: PBU N-12 (181-014) Attachments: WSR-006~N-12~SAUVAGEAU~11Ju12007.Z1P; WSR-007~N-12~BOYLES~05Ju12007.htm; WSR-008~N-12~SAUNDERS~05Ju12007.htm; WSR-009~N- 12~APPLEHANS~28Jun2007.htm; WSR-010~N-12~VARBLE~28Jun2007.htm; WSR-011~N- 12~APPLEHANS~27Jun2007.htm; WSR-012~N-12~ZIMMER~26Jun2007.htm; WSR-013~N- 12~VARBLE~03Jun2007.htm; WSR-014~N-12~VARBLE~02Jun2007.htm; WSR-015~N- 12~VARBLEM01Jun2007.htm; WSR-016~N-12~VARBLE~31May2007.htm; WSR-fl17~N- 12~BILLEC1~08May2007.htm; WSR-OOO~N-12MROSCHtNGER~28Ju12007.htm; WSR- 001~N-12~ROSCH{NGER~27Ju{2007.htm; WSR-002~N-12~BtXBY-JERRY~15Ju12007.htm; WSR-003~N-12~DERR{CK~14Ju12007.htm; WSR-004~N-12~ROSCHINGER~13Ju12007.htm; WSR-005~N-12~SAUVAGEAU~12Ju12007. htm These are the reports of work done prior to the rig arriving. Since the TWC has been stuck and the rig subsequently moving off, the Wells team has pumped 50 bbls of diesel down the tubing past the TWC to ensure the tubing is freeze protected and we have tried to release the TWC with a heavier duty pulling tool. The combo MIT was performed on Jul 11. The failure rate is consistent with the initial pressure approx 3400 psi, 15 min later, the pressure is just below 2000 psi. We attempted a liquid leak rate but it was too small for the LR5 pumps. My personal opinion is that we have a packer leak and not a Cretaceous leak. The facts that I base this opinion on are 1) Normally, the Cretaceous interval is overpressured and for N-12, 1 % KCI brine and diesel freeze was sufficient to reduce surface pressures to zero and 2} the small liquid leak rate. Current readings on the IA and OA indicate zero pressure. The tubing reads zero as well but we will attempt to pump past the TWC again to ensure there is no trapped pressure prior to beginning work. My apologies for not including these reports earlier. I simply didn't read your email close enough. We are developing the coiled tubing mill out procedure and if we need to proceed with that option, I will send that program to you after approving it internally.. Doug 240-8041 From: Maunder, Thomas E (DOA) [mai{to:tom.maunder@alaska.gov] Sent: Saturday, October 06, 2007 8:36 AM To: Cismoski, Doug A; Reem, David C; Roach, Frank Cc: Grimaldi, Louis R (DOA); Regg, .lames B (DOA) Subject: RE: PBU N-12 (181-014) Doug, et al, With regard to the failed CMIT x IA ... 1. What were the particulars about the pressure test? What pressure was achieved, how did the pressure decline? Were there IA pressure problems noted previously? Is a Cretaceous leak suspected? 2. Is there any pressure on the well now? 3. Again, I would like to receive a copy of the well services report of the work done prior to the rig moving on the well. 10/19/2007 RE: PBU N-12 (181-014) i Thanks in advance. Tom Maunder, PE AOGCC -----Original Message----- From: Cismoski, Doug A jmailtaCism_osDA_~13P,_c_om] Sent: Thu 10/4f2007 2:51 PM To: Maunder, Thomas E (DOA); Reem, David C; Roach, Frank Cc: Grimaldi, Louis R (DOA); Regg, James B (DOA) Subject: RE: PBU N-12 (18I-014} L FasDril was set and tested @ 8505'. . 2. Tubing was PT'd to a 1000 psi immediately after setting the FasDril plug and before cutting the pipe. 3. After cutting the pipe and circulating the well with 1% KCI, a combo-MIT TxIA failed. We are still a couple of days away from this work. The contingency if we cannot rotate the TWC's mandrel is to rig up coil and core the mandrel allowing the dogs to retract. Doug From: Maunder, Thomas E (DOA) [m_ailtoaom.maunder@alaska.gov] Sent: Thursday, October 04, 2007 11:23 AM To: Reem, David C; Roach, Frank; Cismoski, Doug A Gc: Grimaldi, Louis R (DOA); Regg, James B (DOA) Subject: PBU N-12 (181-014) All, Not sure who can answer my questions/request. I am informed that the Klondike work platform is presently being mobilized to N-12 to pull the TWC that became stuck in the wellhead when Doyon 14 was on the well in early August. I would appreciate receiving a copy of the planned procedure for removing the TWC as indicated in Frank's email of August 8. Also, I'd appreciate receiving a copy of the pre-rig work that was preformed prior to Doyon 14's arrival. Items I am particularly interested in are ... 1. Was a Fasdrill plug installed in the tailpipe as planned? 2. Has the well (T and IA) passed a positive pressure test during any of the work? 3. Is any IA compromise known? Thanks in advance for the information. Tom Maunder, PE AOGCC Page 2 of 2 10/19/2007 • Page 1 of 1 • WELL SERVICE REPORT WELL JOB SCOPE UNIT N_~ 2 RWO EXPENSE SWCP 4516 DATE DAILY WORK DAY SUPV 6/3/2007 PATCH TUBING /CASING VARBLE COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P9278-D SWCP-DELOZIER ROMBERG MIN ID DEPTH TTL SIZE 2.31 " 8500 FT 3.958 " DAILY 5UM "F"UVSK (;UN I INUtU f KUM 6/L/L007""" (Nfe rwo) ATTEMPT TO PULL 5 1!2" ECLIPSE PACKER @ 8500' SLM WlBRAIDED LINE. UNABLE TO GET ANY MOVEMENT UPHOLE WITH PATCH. 5 1/2" ECLIPSE PULLING TOOL STILL ON PATCH. (USE 4 1!2" GS TO PULL, 18" O.A.L.) RIG DOWN BRAIDED LINE. '"`*"`LEFT WELL SHUT-IN, PAD OP NOTIFIED AND INSPECTED WELL BEFORE DEPARTURE*""* LOG ENTRIES Init Tb IA OA -> 500 500 100 TIME COMMENT 00:01 WSR CONTINUED FROM 6/2/2007. RIH WITH 8' OF 3", 3' OF 2 5/8" STEM, OJ, LSS, AND 4 1/2" GS. 03:44 _...._._......_~_ 03:55 BEAT ON PATCH FOR APPROX. 2 HOURS. SAW NO MOVEMENT. SIBD. _..__e_______________.._____...____...._......______.._______.....______~__.____._.___..__...._....___..__...~._.._._~..._~..___...._..____._____._.~_..........~ .-.~..____.__..~.._______.____.._._..______..... OOH WITH TOOLS. M/U MORE STEM, DOUBLE CHECK TOOLSTRING AND REPIN GS. 04:40 WE CUT 50' OF BRAIDED LINE AND RETIED ROPE SOCKET. RIH WITH 8' OF 3", 8' OF 2 5!8", OJ, LSS, AND 4 1/2" GS. 06:12 _.__........__...... 06:33 LATCH UP a~ 8432' BLM __._....____.____.._...._..__.________.._ ._._~ __..___.._____.._.__._ _ _.._._.__......._...___. _....~_.._.... ......................M___ ~ ____~.______.e___________. _._________ _______.____.__.__ CREW C/O TO NOSKO /HOLD T.G.S.M. /TALK TO BP REP. 06:50 CONT. TO JAR ON PATCH 07:57 PATCH NOT MOVING SHEAR TL P.O.O.H 08:51 OOH WITH TLS. BEGIN RIG DN. 12:11 RIG DN. COMPLETE 13:00 FINISH COMPUTER WORK, CLEAN TLS. FROM JOB Final Tb , IA, OA -> 500 500 100 SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL TOTAL FIELD ESTIMATE: $7,599 $31.642 FLUID SUMMARY N/A file://C:\temp\Temporary%20Internet%20Files\OLKF\blSR-013~N-12~VARBLE~03Ju... 10/22/2007 • • Page 1 of 2 WELL SERVICE REPORT WELL JOB SCOPE UNIT N ~~ Z RWO EXPENSE CTU #9 DATE DAILY WORK DAY SUPV 6/26/2007 FISH ZIMMER COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P9278-D DS-WAGONER FAGNANT MIN ID DEPTH TTL SIZE 2.31 " 8772 FT 4.5 " FISH 5-1/2" ECLIPSE TUBING PATCH, CTU # 9, 1.75" CT: Travel from P2-16 to N-12, MIRU, Perform BOP Test. MU &RIH with WFD 4-1/2" "G" spear. Latch up at 8512' ctmd. Hit 50 jar licks 23-25k over. No luck. POOH for pipe management. ***Continued on 6/27/07 WSR*** LOG ENTRIES Init Tb , IA, OA 462 510 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 06:00 0 Travel from P2-16 to N-12 09:30 11:30 12:54 0 0 0 MU 7" BOP's Start Required BOP TEST __ _..___ _.____.._......_._._._-...______..__....._.___...__..__________~ BOP TEST com lete 13:00 0 Pick u 36' of Lubricator 13:33 0 Safety meeting, discussed how to handle the heavy tools, Some slick surfaces because of drizzle.Also use 2 people to carry tools and also talkded about pinch points and watch out where we put their hands, 13:45 0 MU BHA#1 1.75" CTC 2.875"OD, DFCV 3.125" OD, Dailey Accelerator 3.125" OD, 2 ea. Wt Bar 3.36' OD, Dual action Jar 3.125" OD, Hydraulic Disconnect (3/4 ball , 3500 psi shear, 5000 psi ru ture disc 3.125' OD, 4 1/2" "G" S ear 4" OD. OAL 33.93' 13:50 0 Pull test CTC, 20 k 14:01 0 Fluid ack CT _ 14:06 14:28 _~_ _.0 . 0 .______._....._..... 3500 _.__.._._._......... 3500 _.._.___......_..__. 4 .....__.....____.._.. PT MHA, make u~.rest of the tools________..._._.._____._.._.._._..__....___..._..___.........._._ ..._...._._..._ .__..._.______.._w____._..___ PT Tool strin 14:33 0 Bleed off, MU GS 14:40 0 POP on well 14:44 0 400 400 LPPT Lubricator and well head 14:52 0 4000 4000 6.5 HPPT 14:57 0 bleed off, wait on DSO too en SSV 15:11 0 discovered a h drualic leak on stuffin box, 15:15 17:00 _.______.....___. 17:51 0 0 _.____~__..._..... 0 ._.._._.._ _.-___..... .._.._.._.......___...... ._.......___._._.___. _.._..___..____ _.. .Rig down lubricator,.__.____~_ _.._____..._.__..__...__.._.._......._..___...___...__.___..._.._.__.....__.__~ Pressure test. OK ..__ ___._.___ _........_.__.__....M.___.__.._._._..____...__._......._...__._..__ _..._._..___..._.......__.._.__........_.....__.._......._.__.._.._..___-- Pull test CTC 20 k 18:12 0 3500 Pressure test Tool strin 18:15 0 Stab on Well 18:20 0 Crew chan a out 18:39 0 300 LPPT 18:44 0 4000 4000 9.4 HPPT 18:55 0 455 366 9.4 RIH with BHA #1 to fish Ecli se atch 20:13 20:41 5800 8500 572 579 0 0 0 0 9.4 9.4 Wt Ck = 11 k Wt Ck - 15.5k, RIH - 7.5k 20:46 8512 587 0 0 ~~~ Set down 2k 20:48 8498 Latched. Pull 15k over, hit ~ars 20:50 8491 587 #2 lick, 20K over 20:52 8491 #3 lick, 20K over 20:56 8478 #5 lick, 23k over _ 20:58 0 #6 lick, 23k over _ 20:59 21:00._ 21:02 0 __ __-----......~ . 0 ................_..__.._.... _.____........._. .... _..................---. ....__...._...._.. #7 lick, 23k over ...#..8...lick, 25k~over-......_._.._.......__....._........----.._..__....................._...__...._._.......__..._._._......._........................__._..._.__..........._..__....... #9 lick, 20k over 21:03 0 #10 lick, 23k over file :1/C:\temp\Temporary%20Internet%20F Iles\OLKF\W SR-0l 2~N-12~ZIMMER~26Ju... 10/2212007 • Page 2 of 2 • 21:05 0 #11 lick, 23k over 21:06 0 #12 lick, 23k over 21:08 8478 #13 lick, 23k over 21:11 8481 #14 lick, 24k over 21:12 0 #15 lick, 24k over _2114 21:16 21:17 0 0 0 __.._._~. __ __.__.__...~._.... #1.6lick,_23k over __M_.._.~______~.________.._____.____~..__~_._.._._______.....___..._.~ #17 lick, 23k over #18 lick, 23k over 21:19 0 #19 lick, 23k over 21:20 0 #20 lick, 23k over 21:23 0 #21 lick, 23k over 21:24 0 #22 lick, 23k over 21:27 0 7k down lick 21:28 0 #23 lick, 23k over 21:30 21:31 0 0 #24 lick, 23k over #25 lick, 23k over 21:32 0 #26 lick, 24k over 21:34 0 #27 lick, 23k over 21:35 0 #28 lick, 24k over 21:37 0 #29 lick, 23k over 21:39 0 #30 lick, 24k over 21:40 0 7k down lick 21:41 21:42 _. ~..____. 21:43 0 0 ___.__~_._.__. 0 ___.____.._~. _~____._____. _______.___ ..__.._....._...~___....... #31 lick, 24k over #32 lick, 24k over _...._~......~_____.____.__~ _.__.. ~._.___.___..__.~_._.._e.___.______._.._..._.._._.__.._______.___.__.__. #33 lick, 24k over 21:45 0 #34 lick, 24k over 21:46 0 #35 lick, 24k over 21:48 0 #36 lick, 25k over 21:50 8499 9k down lick 21:51 0 #37 lick, 25k over 21:52 0 #38 lick, 25k over 21:53 21:54 0 0 #39 lick, 25k over #40 lick, 25k over 21:56 0 #41 lick, 25k over 21:57 0 #42 lick, 25k over 21:58 0 #43 lick, 25k over 21:59 0 #44 lick, 25k over 22:01 0 #45 lick, 25k over 22:03 0 #46 lick, 25k over 22:05 _____..._ 22:07 22:08 0 ~_...._ ~...____.... 0 0 __._~__......__._.... __.__.___.__.. ~_.._____..___~_._ __....._._.____.....__ #47 lick, 25k over ....__._.......____._.._.___..._--_-__...._____ ~ _e~._~.._ _ _ ___._..~.__~..._._.._..e..~_____...__~.___..~___ #48 lick, 25k over #49 lick, 25k over 22:10 0 #50 lick, 25k over 22:26 0 28 Pum off and POOH 23:36 0 550 0 0 28 Ta u 23:59 0 L/D tools, and swa out tractor. Continued on 6/27/07 WSR Final Tb , IA, OA 550 590 0 JOB I SERVICE COMPANY -SERVICE I DAILY COST I CUMUL TOTAL I TOTAL FIELD ESTIMATE: I $19.6561 $51.299 FLUID SUMMARY 28 bbls 1% KCL file://C:\temp\Temporary%20Internet%20Files\OLKF\WSR-012~N-12~ZIMMER~26Ju... 10/22f2007 • Page 1 of 2 i WELL SERVICE REPORT WELL JOB SCOPE UNIT N-12 RWO EXPENSE CTU #9 DATE DAILY WORK DAY SUPV 6/27/2007 FISH APPLEHANS COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P9278-D DS-ANDERSON MONTGOMERY MIN ID DEPTH TTL SIZE 2.31 " 8772 FT 4.5 " DAILY Pull 5-1/2" Eclipse patch/ CTU #9. ""`Continued from 6/26/07 WSR"** UD tools, cut pipe, change out packoffs, MU tools.RlH with same BHA - 4-1/2" G spear. Attempted to pull patch with 50 good solid jar licks pulling 24-25K over pickup weight with no luck. POOH with fishing BHA. Break down fishing string, cut 100' of pipe and MU BHA #2 with a 3.625" OD taper tap for pulling the ER packer retrieval tool and RIH. Tag bait @ 8517', pumping. Engage tap, POOH to check fish. Baitlretrieval tool was not retrieved. Continued on 06/28/07 WSR. LOG ENTRIES Init Tb , IA, OA 484 510 0 TIME_ DEPTH TBG _.__ __.. CTP .._.__..___ ___ BPM ___..__....____.___... BBLS _._.__. _..__. _._ COMMENTS _ _ ._ _ __ .. .___ _ ____ ._._____.._____ ____.__v____.._~._._ __ ____ ___ _. -. . 00:01 0 . Y _ e. . _ _ _ __ _,_ _ __ _ _ _ Continued from 6/26/07 WSR 00:05 0 UD fishing tools/ Swap out tractor to see if that cures the ERAD ___. __._..... __ ______..__ .pressure trip_problem. __....___.__..__.____...._..__ __._.______._.___......__._.__.____.__....____.__._ 00:30 0 Cut 150' i e 01:10 0 UD lubricator 01:25 0 Chan a out ackoffs 01:40 0 PU lubricator 02:09 0 MU tools -Pull test to 21 k 02:50 0 PT tools to 3500 si - ood 03:17 0 Go to standby -Pump ERAD not working, UTIM not working. Give SLB time to make re airs durin Co Man Chan eout. 10:30 0 BP Company rep changeout complete, PJSM prior to RIH with WFD fishin tools. 11:21 0 Online down CT to re-pressure test surface lines and lubricator before RIH since PT was done re Chan eout. 11:36 0 484 447 0 2.2/kcl LPPT, HPPT both ood, o en u well and RIH. 11:57 76 484 440 0 2.2 RIH with 2.875" OD CTC, 3.125" OD DFCV, Dailey Accelerator, Sea 3.360" OD weight bars, 3.125" OD Dailey dual action jars, 3.125" OD Hydraulic Disco set for 3/4" ball, 4.00" OD 4-1/2" G spear. OAL of BHA is 33.93'. 12:48 4735 615 0 0 2.2 Continue RIH with 4-1/2" G s ear. 12:54 5112 623 0 0 2.2 Wei ht check. 10K. RBIH. RIH wei ht 6K. 13:30 7810 675 0 0 2.2 Continue to RIH. 13:39 8404 690 0 0 2.2 Wei ht check. 16K. RBIH to latch fish. RIH wei ht is 9K. 13:49 8515 685 0 0 2.2 Tag top of fish, started loosing weight. Set 2K down to confirm we W are latched and be in 'arrin on the atch. Pull 31 K 15K over 13:53 8511 682 0 0 2.2 Attem t a third 'ar lick ullin 17K over icku wei ht. __1400 8494 674 0 0 2.2 20K overpull on the sixth jar lick 15:21 - 8500 _ 667 _ _ 0 _ 0 2.2 50 jar licks attempted with no luck. We consistently pulled 24 to 25K over with good solid jar licks each time. Phoned the coil scheduler of plan forward since we need to trip out, cut pipe and rehead. Plan forward was discussed with town and decision was made to pull the 5-1/2" ER retreival tool with a motor and tapered mill and leave the atch. 15:29 8500 674 1465 0 2.2 Online down CT with KCL to release the "G" spear from the patch and POOH. 15:31 8471 696 0 0 5.3 Offline down CT, we are free of the fish. Install UTIM before POOH __...._......__._ _...._...._..____.._. ..__....... __. ___. __.__....__..... _with fishing. BHA:.._ 15:39 8435 689 0 0 5.3 UTIM is hooked up and WORKING! POOH to cut pipe and change BHA to ull 5-1/2" ER retreival tool. 16:01 6050 674 0 0 5.3 Continue POOH. 16:46 0 550 0 0 5.3 Tag up at surface, close swab valve and pop off to cut pipe and Chan eout tools. file:flC:\temp\Temporary%20Internet%20Files\OLKF\WSR-Ol 1 ~N-12~APPLEHANS~2... 10/2212007 Page 2 of 2 • 17:09 0 0 0 0 0 WFD BHA broke down, begin cutting coil for pipe management before MU new BHA. 17:33 0 0 0 0 0 Donecutting 100' of CT for pipe management. Begin MU new WOT CTC. 17:37 0 0 0 0 0 Pull test WOT CTC to 20K. Good test. 18 :00 _ ______0 _. _~.__.. 0 ______._.0 0.5 5.3. Online with 1 % KCL to pressure test MHA. 18:06 0 0 0 0 16.7 Good pressure test on the MHA, bleed off excess test pressure and make crew Chan e with coif crews. Wa oner for Anderson 18:20 .__.__.____ 0 __._..._.____ 0 _ _ 0 0 16.7 Continue MU BHA. 18:29 0 . ___. ___a.._. 0 ...__.._.._...___ 0 ______..__ 0 .._.___-__...... 16.7 ..._...._......._......_.~..._......_._____.___~__.._._..~._._._._______...__._...._____.__.._ ~.____._.._..........._..... BHA is made u , dro 8' of lubricator before stabbin on. 18:37 0 0 0 0 16.7 Stab on well. Line u to PT. 18:45 0 235 250 0 19 Offline with coil um for a LPPT. 18:49 0 4000 4000 0 19.4 Offline with coil um for a HPPT. 18:51 0 750 750 0 19.4 Good pressure tests, bleed off excess pressure and open swab to RIH. 19:05 0 550 550 0 19.4 RIH with WOT BHA #2: 2.875" OD CTC, 3.125" OD Blank check valve, dual acting jar, 2.875" OD DCV, hyd disco set for 7/8" ball, circ sub set for 3/4" ball, 3.050" OD X-O, 2.875" OD PDM, 3.625" OD to er to . OAL of BHA is 24.16'. 20:09 5860 696 0 0 19.4 Wt ck = 11 k#. Continue RIH. 20:26 7020 726 0 0 19.4 Stop, look @ pipe. 0.103 wall in 0.116 section. Below minimum. Call to Dowell Coil Cell leader. Decision to com lete this 'ob. 21:17 8430 755 0 0 /0 Wt ck 14k#. Lme u KCL down CT. Pum 1 b m, ease into hole. 21:28 8517 828 200 0 5 Tag/stack 3k#. Saw slight increase in CTP. SD pump. Got jar lick. PU to 16k#. Latched. Set down to neutral weight. Bring up pump to 1 bpm. PU to 17k#. SD pump. Set down. Increase rate to 1.3 bpm. PU to 16k#. Saw weight break back. Continue pullin up. SD pump. Isolate fluids, continue ullin out of hole. 21:50 7004 777 0 0 5 Park. Fla bads of on CT. IA=800, OA=100 si 22:53 0 572 0 0 /0 Line u methlwtr down backside to um 2000' freeze rotect. 23:03 0 1500 0 3.3 27 Pumping freeze protect. Have PJSM w! coil crew and N2 pumping crew. 23:25 0 2000 0 0 45 2000' of meth/wtr pumped. SD pump. Close swab. Bleed down. POP off. Final IA=1000 si, OA= 200 si. 23:40 0 Pop off, inspect BHA -bait was not retrieved. Can see marks of tap from engagement. Proceed to remove BHA. 23:59 0 La in down lubricator. Continued. Final Tb , IA, OA 1788 1000 200 CUMUL TOTAL SUMMARY 25 bbls 1 % K( 45 bbl's 50/50 meth water. SAFETY NOTES Job in ro ress. file://C:\temp\Temporary%20Internet%20Files\OLKF\WSR-011 ~N-12~APPLEHANS~2... 10/22J2007 • Page 1 of 1 • WELL SERVICE REPORT WELL JOB SCOPE UNIT N-12 RWO EXPENSE CTU #t9 DATE DAILY WORK DAY SUPV 6/28/2007 RIG DOWN APPLEHANS COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P9278-D DS-WAGONER MONTGOMERY MIN ID DEPTH TTL SIZE 2.31 " 8772 FT 4.5 " DAILY SUMMARY Continued from 06/27/07 WSR. Blow down reel. RDMO. LOG ENTRIES Init Tb , IA, OA 1788 1000 200 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 0 Continued. Dro in lubricator 00:13 ___.___...___. 00:30 .._..._.._. _._...._ 00:44 0 .___.____ 0 ........~....._._....__~.~ 0 ._......_..._..____ _.._.__.........___._-- .__._.._..._... -- ~__.___._ _.___.___ .....______..._.._... 2 __._......_..____ .._. _ _ _._._. Stab onto well. Fluid pack coil/lines w/ Meth/wtr. PT low to 230 psi. High to 3500 psi. Good. Bleed to 0 psi. Blow down surface lines w/ air com ressor_Cool down N2 unit. ____.__.___....P.._ PJSM for N2 blowdown. ~ __e_._._..._._____ _....._...._..___.._.__.__...._.........._._......_.._.__._.____.__..__...__...._.____....._.____.._..__..._._.__.._..._. PT N2 to 3500 si. 00:50 0 Be in blowdown 1500 scf/m for 13 min's. 01:30 0 Reel de ressured. Be in ri down. 04:00 0 Ri down com lete. De art for sho . 05:00 0 Arrive sho .End ticket. Switch to i e swa AWGRS. Final Tb , IA, OA 1788 1000 200 JOB C SERVi I TOTAL FIELD ESTIMATE: I $15,403 I $116,681 FLUID Z bbls meth/wtr gals N2. file://C:\temp\Temporary%20Internet%20Files\OLKF\WSR-009~N-12~APPLEHANS~2... 10/22!2007 • WEAL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT N_~ 2 RWO EXPENSE SWCP 4515 DATE DAILY WORK DAY SUPV 6/28/2007 FISH VARBLE COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P9278-D SWCP-WILSON ELIAS MIN ID DEPTH TTL SIZE 2.31 " 8772 FT 0 " DAILY SUMMARY *** WELL SHUT IN ON ARRIVAL *** (fish eclipse tool) RAN 4.5 GR TO ECLIPSE PULLING TOOL @ 8515' SLM ,SHEARED GR , ECLIPSE TOOL DOESN'T APPEAR TO BE RELEASED ALL THE WAY. ****NOTE: ECLIPSE PULLING TOOL STILL IN HOLE , 4.5 GS TO PULL**** S/I ON DEPARTURE*** LOG ENTRIES Init Tb , IA, OA -> 800 1000 120 TIME COMMENT 05:00 **`* TRAVEL FROM DEADHORSE *** MEET FUELER BP WLB ,THEN TRAVEL TO N-PAD 06:53 ARRIVE ON LOCATION -INSPECT AREA -SPOT EQPT - TGSM 07:22 BEGIN RU W/.125 WIRE , 5' OF 2 5/8 STEM , OJ , LSS 07:59 TAKE CONTROL OF WIRE -CYCLE SSV -STAB ON WELL - PT SURF EQPT W/DIESEL TO 500# LOW , 3000# HIGH 08:17 RIH W/4.5 GR -SLOWLY RUN DOWN HOLE AROUND TOP OF PATCH -START TO SIT DOWN @ 8515'SLM , SPANGS NEVER CLOSED ALL THE WAY -LATCHED UP -START SPANGING UP LIGHTLY -TAP UP LIGHTLY FOR 10 MIN -UNABLE TO PULL FREE -START SPANGING HARDER -PULL FREE - NO WEIGHT GAIN - POOH 09:25 OOH WlSHEARED GR -CONTACT COMPANY REP -BEGIN RIG DOWN 10:59 RIG DOWN COMPLETE -CONTACT PAD OP & 401 -TRAVEL TO PM2 Final Tb IA, OA -> 800 1000 120 ~ JOB COSTS ~ SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL AL FIELD FLUID SUMMARY 1 BBL OF DIESEL TO PT SURF EQPT file://C:\temp\Temporary%20Internet%20Files\OLKF\WSR-0l O~N-12~VARBLE~28Ju... 10/22/2007 . ~ Page 1 of 2 -~ WELL SERVICE REPORT WELL JOB SCOPE UNIT N_~ 2 RWO EXPENSE SWS 2150 DATE DAILY WORK DAY SUPV 7/5/2007 SET MECHANICAL PLUG; TUBING CUT--JET /OTHER BOYLES COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P9278-D SWS-LINK LYNCH MIN ID DEPTH TTL SIZE 4.562 " 2017 FT 5.5 " DAILY SUMMARY INITIAL WHP: 375/700/0. SFT 5 5" BAKER COMPOSITE BRIDGE PLUG AT 8,505'. OVERALL PLUG LENGTH = 1.65', MID ELEMENT TO TOP OF PLUG 0.65 ,MID EL~10f~ -FCD'i"~""PL~JG PRESSURE TESTED TO 1000 PSI FOR 20 MIN. JET CUT TBG AT 8.475' Wl 4.15" POWER JET CUTTER. CORRELATED TO TBG TALLY DATED 02-JUNE- 1981. FINAL W :250/700/120. ***JOB COMPLETE*** LOG ENTRIES Init Tb IA OA -> 375 700 0 TIME COMMENT 02:45 ARRIVE AT LOCATION AND LINE UP EQUIPMENT. 02:50 ___.__......_..... 03:00 BAKER HAND ARRIVED AT LOCATION. _...._.___..._~_.__..___.....____.__.. ~_~..____~_____._ _ _..__.__....___.__~~____~....____~__..._~______________.._____.~ ______......._._..___.~.__...___..._..___~_._-_..___....~.__.___._._.._~.._._ e._______. PJ SAFETY MEETING 03:21 WAITING FOR PAD OP TO COME SIGN PERMIT. 03:39 PAD OP ARRIVED, SIGNED PERMIT. 03:40 BLEED WELL CAP. 03:41 ARM AND ASSEMBLE COMPOSITE PLUG: HEADlPEK-BlCAL-B/CPST/5.5" BAKER COMPOSITE BP. LENGTH _ ,WEIGHT = 300 LB, MAX OD = 4.375" 04:17 PRESSURE TEST WHE, LOW 300 PSI, HIGH 3000 PSI. PT GOOD. 04:52 OPEN SWAB VALVE 34.5 TURNS, WHP = 375/700/0, RIH, CORRELATE TO TBG TALLY DATED 02-JUNE-1981. 06:36 TAGGED TOP OF PATCH AT 8518', BEGAN CORRELATION UP LOG AT 60 FPM. 06:45 CORRELATED ON DEPTH, WAITING FOR PE TO ARRIVE BEFORE BEGINING SETTING PASS. 07:29 PE ARRIVED, LOG DOWN AND GET INTO POSITION FOR 07:38 SET PLUG IN 5.5" TBG AT 8505', CCL TO MID-ELEMENT 11.2', CCL STOP DEPTH = 8493.8'. OVERALL PLUG LENGTH = 1.65' WHP BEFORE 400!700/75 07:55 CHANGE OUT CREW ARRIVE. POOH. 08:38 200' FROM SURFACE. POWERING DOWN UNIT. 09:12 09:32 AT SURFACE WITH TOOL STRING. PLUG SET CONFIRMED. LRS RIG UP FOR PRESSURE TEST ON PLUG. LRS PUMPING 1 BBUMIN, WHP 500PS1, 2 BBL AWAY 09:47 LRS PUMPED PLUG TO 1000 PSI. WILL HOLD FOR 15 MIN. 10:05 PRESSURE TEST COMPLETE. LRS RIG DOWN PUMPING EQUIP. START RIGGING LIP JET CUTTER. 11:20 TEST FIRE ON JET CUTTER GOOD. BEGIN ARMING. 11:54 PRESSURE TEST OTS GOOD. 11:58 OPEN UP SWAB, 34.5 TURNS. START RIH W/HEAD/PEK'BlCAL-B73-3/8" SHOCK SUB/2" SHOCK SUB/4.15" OD JET CUTTER 13:55 CORRELATION PASS COMPLETE. MOVE IN FOR SHOOTING PASS. 14:04 IN POSITION TO SHOOT. PRESSURES ARE: WHP 250, IA 700, OA 120 14:09 JET CUT DONE. 14:19 POOH. 15:13 15:23 AT 200' WITH TOOL. POWERING DOWN UNIT. AT SURFACE WITH TOOL. 15:33 JET CUTTER SHOT CONFIRM. 15:35 PRESSURE CAP IS ON WITH WHP 275 PSI Final Tb lA OA -> 275 700 120 SERVICE COMPANY -SERVICE DAILY COST CUMUL TO_TA_ L TOTAL FIELD ESTIMATE: $37,179 $156,440 FLUID SUMMARY file://C :\temp\Temporary%20Internet°l°20Files\OLKF\W SR-007~N-12~BOYLES~05 Jul... 10/22/2007 • Page 2 of 2 1 BBL DIESEL USED FOR PRESSURE TESTING file://C:\temp\Temporary%ZOInternet%20Files\OLKF\W SR-007~N-12~BOYLES~OSJu1... 10/22/2007 • WELL SERVICE REPORT Page 1 of 1 WELL JOB SCOPE UNIT N-1 Z RWO EXPENSE LRS 68 DATE DAILY WORK DAY SUPV 7/5/2007 MIT-T SAU N D E RS COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P9278-D LRS-SMITH JIM CULPEPPER MIN ID DEPTH TTL SIZE 0" OFT 0" DAILY SUMMARY T/I/0= 450/700/120 ASSIST E-LINE. Pumped 14.6 bbls of crude to test against Plug. Test for 15 min. PASSED. Bled pressure back to 450 psi, FWP= 450/700/120 LOG ENTRt_ES Init-> 450 700 120 TIME ......._..._._......._. 03:00 BPM _._.__..__ BBLs ..__._.._..____ FLUID ___..~_.___e TEMP ..________~._ TBG ._.._.._____~_... IA ...__.~_..__ _. OA .___._.._._._____ COMMENTS _.___...~.__....._.___.__.___.____.....__.. __....____..__...._____.......__.. ~_____...__..~`._ Start the ticket. 03:30 Load crude at GC1. 05:04 Arrive on location. Si n in with SWS E-Line. 05:15 Wait for the lu to be set. 09:00 Sot unit & ri u to um -in-sub 09:24 Pressure test surface lines to 3500 si. 09:28 .5 Ofstart crude 60 500 700 120 Start um in down Tb . 09:38 _......._.._.... 09:45 10:00 1 ___~._______ 0 8 ..__...___ _ 14.6 .._....__.___.._ __..___..____.___ 700 ....___... _.._..._._.. 1000 950 700 ..____..____.._.__., 700 700 120 _._._____....____. 120 120 __._._..__._.._ _.....__.__.___ ____ __.___._ a .__...___.._____.__.__._.____....__..__ St~pum~inc„~down Tk~./ Start 15 min, test 15 check lost 50 psi. Bleed back pressure to 450 si. 11:00 _...._.._......_____... 11:59 __.._._....._ _._ __ Y__...~. _ _._.__.._ ..__._____.m_ _.._.______ _._ _..._._....____ .__._.. _._ __ RDMO _....__._~....___.___._._____..._____.__..__.v.__..._.. _~.. __...__._.___.._ End Ticket Final-> 450 700 120 TOTAL DAILY CUM FLUID SUMMARY 15 bbls crude SAFETY Safe area will be @ pad entrance E/Line has control of well PJSM w/ E/Line file://C:\temp\Temporary%20Internet%20Files\OLKF\WSR-008~N-] 2~SAUNDERS~05... l 0/22/2007 Page 1 of 4 WELL SERVICE REPORT WELL JOB SCOPE UNIT N_'~ 2 RWO EXPENSE LRS 46 DATE DAILY WORK DAY SUPV 7/11!2007 COMBINATION MECHAN{CAL INTEGRITY TEST SAUVAGEAU COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P9278-D LRS-SMITH DAN SPIELER MIN ID DEPTH TTL SIZE 0" OFT 0" DA1LY S T/I/0=200!700/140 [Pre RWO] Circ out. CMIT TxIA FAILED, MITOA PASSED. Pumped 5 bbls neat meth, 1102 bbls 1 KCL, followed by 150 bbls diesel down Tubing taking returns up IA through jumper line down F/L. U-Tube T x IA to Freeze protect. Freeze protected Flowline per WOA procedure w. 7 bbls neat meth and 114 bbls DSL. CMIT TxIA FAILED 5 attempt's in first 15 minutes MITOA PASSED to 2000 psi- on 1st try. Pressured up w. 2.2 bbls DSL. OA lost 60 psi in first 15 min & 40 psi in second 15 min for a total pressure loss of 100 psi over 30 min. bled OAP. **"Continued on 7-12-07*** LOG ENTRIES Init-> 200 700 140 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 04:00 Road to location- stage equipment, travel to meet Pad o for ermit 05:15 S of e ui ment- PJSM- Ri u 06:00 PT surface lines to 3500 psi- call Pad op/ PCC for ermission too en rove and ~um er line 06:15 2 start meth 40* 350 700 140 Start down Tubin with 'um er line shut 06:18 2 5 600 750 140 SD- swap to 1 %KCL, open jumper line to take returns down flowline 06:23 2 start 1 % 120" 300 650 140 Continue down tubin 06:28 5 11 1200 650 140 06:34 5 45 1600 700 160 06:43 5 90 2000 750 400 06:53 ___...___..__ 07:01 4.5 .____.....___ r_ 4.5 137 ....__..___ 152 _______ ____...._.._..___. 2350 _.._..__._..__..........._ 2350 1400 __..____.__._...__ 700 .__..____.....____.. _______..__...._______._._.___....____...._.________.__..__.__....___.._._..___.._________._ SD- CAT overheatin 07:08 4.3 152/St 1% KCL 500 1000 380 RESTART, Bled OAP 07:17 4.75 200 2400 1000 480 07:22 4.75 219 2450 1000 Call PCC too en choke 07:29 3.9 245 1500 750 650 07:42 3.9 280 1900 1000 900 Bleed OAP, Have PCC o en choke more 07:57 4.2 323 1900 1050 200 08:09 _...______.e__. 08:10 08:23 4.2 ._ .~..__._....~... 5 5 373 _._._._.._~ 373/st 433 1% ._..____..._..__...._... KCL 1750 _..---..__....._..._.. 2200 2200 ._._......__._........__.._ 1050 1000 .. ___.__. ___. _ 300 400 SD, Swap_to 2nd UR__.._..___._...__..._.___....___...._.._.._...._.._....._.__......_.____ ... Restart 08:28 5 455 2700 1450 Reduce rate, TBG, IA & F.L. si increasin 08:42 4.2 515 1900 900 450 08:57 4.2 575 1950 850 500 09:03 4.3 600 2000 900 600 Bleed OAP 09:14 4.2 650 1900 900 300 09:27 4.2 700 1950 950 400 09:35 __.....__.__._... 09:36 4.2 _..__....__.._. 4.2 734 __._ . _ 734lst _.w._.__r._..__ 1% ._.__________ KCL 1950 ._.__....__._.___. 1200 _...._.___.._..____..... ._.....v _. ___ ._ Swap to 3rd _UR___~__ ___......_______._.._....___.._..___......__._.____.._ _......_... Restart down TBG 09:47 4.2 775 1900 800 400 09:53 4.2 800 1850 800 400 10:04 4.2 850 1900 850 350 10:17 4.2 900 1850 850 300 10:29 4.2 950 1850 850 300 10:41 4.2 1000 1900 850 400 10:52 11:05 _.__....___...__ 11:08 4.2 4.2 .__....______..... 4.3 1050 1102 ....._._._._._____ Start ...___......__....._..__. DSL .....__. _. _. _. 45* 1900 .. . ..._1900.. 1600 850 ..__. ......---...._._.__ . 900 400 ..............._ e._ _ 500 SD, Swa ._to DSL_.. ._.._____..._..__._...._..P _ . _ ___...__..._._..._.____.__...__.._.._...._.._.._........__._.._......._......._._ Restart down TBG 11:23 4.3 50 2200 900 500 file://C:\unzipped\WSR-006~N-12~SAUVAGEAU-~-11 Ju12007\WSR-006~N-12~SAUV ... 10!22!2007 Page 2 of 4 11:36 4.2 100 2350 900 500 11:47 150 2450 900 500 SD. line u to F/P F/L 12:06 4.0 start METH 1200 Start down F/L s ear in 2 bbls meth 12:09 4.0 2 50" 1200 switch to DSL 12:10 4 start DSL 45* 1200 12:18 12:19 12:20 4.4 4.4 4.4 41 start 3 neat 50* ~ 1200 1200 1175 Swa to neat Swa to DSL 12:21 4.4 start DSL 45* 1175 12:33 4.4 66 1125 Swa to neat 12:34 4.4 start neat 50* 1125 12:35 4.4 2 1125 SD, Call PCC to S/I Divert, RD from TBG & RU U-Tube line 13:01 PT line to 4000 si. 13:07 Start U-Tube, RU Flan e to OA 13:30 Standb to finish U-Tube 14:00 Still U-Tubin 14:43 14:.53 15:04 ___ _~6 .5 start 9.0 DSL 45* 0 3400 ~ 100 3500 _ 50 250 Lined to pump down IA~U_Tube completed _ Start~umpin~ down IA _ _ ~SD. Start lest 195 si S-riser ~~~ _ ~ ~~ -~~~ 15:19 1980 2150 200 Fail, Bum u 15:20 .6 start DSI 45" 2200 Restart 15:29 min 5.2 3400 3500 200 SD, Start 2nd test w. rove S/I 15:44 1840 2040 200 Fail, F.L.' psi =240 psi, Call grease crew, Bleed IA &TBG si. to 1000 si. 16:01 RD from IA , RU to OA 16:22 PT line to 2500 si. 16:26 .7 start DSL 45* 0 0 100 Start um in down OA 16:29 .5 2.2 0 0 2000 SD, Start first test 16:44 .16:59 17:12 0 0 ~_ ~_0 .0 _1940 1900 15 min pressures ~_____~ ~ ___ ___ .____.__..___. 30 minpressures, PASS, Bleed O_AP RD OA Flan e , RU to IA~~~ ~~ 17:25 Grease crew on Loc. to ressure lock win . 17:43 PT line to 4000 si. 17:49 .7 start DSL 45* vac vac 20 Start. well sucking fluid off of tanker through unit at .7 b m 800 si on S-Riser 18:01 .3 6.3 40 Start um in into IA w. centrifical um 18:05 .7 8.1 100 Kick in tri lex 18:10 .6 10.9 540 900 120 18:20 .6 16 2200 18:24 .6 17.9 2320 2500 120 SD, Out of DSL 800 si si on F.L. 18:26 CIO Mork/Smith 18:35 _..._.____..._..._.... 19:11 _._..____.._..__......... ._.__..________ ___.__~_.. .___....__._._.._ 1500 __...___....__......__ 0 1620 __.._...._......_._..__ 0 220 ________......_. 80 .........__.._..._____.._.._._....._.______._.._...w__.___~___....._.____.___....____..._._..__... Send trans ort for diesel 22:00 .8 17.9 DSL 60" vac vac 60 Continue down IA with centrifical um 22:12 1.5 26 0 100 60 Kick in tri lex to increase rate 22:17 1.25 35 600 800 80 22:23 .75 40 2300 2500 200 22:30 .4 44.4 3360 3500 240 Start CMIT TxIA F/L= 600 si 22:45 1940 2080 140 15 min readin s- FAILED 22:47 22:55 .5 .5 44.4 48 1620 2280 1700 2500 140 200 Pressure up 23:00 .5 53 3320 3500 220 Start CMIT TxIA 23:15 1920 2080 140 15 min readin s- FAILED 23:19 .8 53 1860 1980 140 Pressure u 23:29 .5 60 3360 3500 220 Start CMIT TxIA 23:44 1820 2020 120 15 min readin s- FAILED 23:59 660 840 60 30 min readings as per PE- Continued on 7-12- 07 Final-> SERVICE COM DAILY COST ~CUMUL TOTAL 9521 $177 file://C:\unzipped\WSR-006~N-12~SAUVAGEAU---11 Ju12007\WSR-006~N-12~SAUV... 10/22/2007 Page 3 of 4 FLUID SUMMARY 12 bbls meth 1103 bbls 1°1° KCL 324 bbls diesel MIT TEST WELL TYPE PROD GAS LI TEST #1 REQUIRED TEST PRESSURE 3,500 TEST TYPE CMIT TXIA FLUIDS USED TO TEST DIESEL START TIME: 15:04 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL TUBING 0 3,400 1,980 IA 100 3,500 2,150 FAIL OA 50 250 200 COMMENTS Pressured u w. 9 bbls DSL TEST #2 REQUIRED TEST PRESSURE 3,500 TEST TYPE CMIT TXIA FLUIDS USED TO TEST DIESEL START TIME: 15:29 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL TUBING 1,980 3,400 1,840 IA 2,150 3,500 2,040 FAIL OA 200 200 200 COMMENTS Pressured u w. 5.2 bbls S-Riser si increased b end of test. TEST #3 REQUIRED TEST PRESSURE 2,000 TEST TYPE MlT-OA FLUIDS USED TO TEST DIESEL START TIME: 16:29 _ TUBING__._...W_._._______..__..__..._._._.._._____.__ ~~ PRE TEST PRESSURES O._...~_______._._. INITIAL PRESSURES O___._._..______.._..__ 15 MINUTE PRESSURES 0 ____._...__._ ................. 30 MINUTE PRESSURES O___.._____._..__. PASS OR FAIL ...___._._______.....__ _.____....._..._..._.____.._ IA 0 0 0 0 PASS OA 100 2,000 1,940 1,900 COMMENTS Pressured u w. 2.2 bbls TEST #4 REQUIRED TEST PRESSURE 3,500 _ _ __ START TIfVIE: 22:30 ~-~~~ J~ TEST TYPE FLUIDS USED TO TEST CMIT TXIA_ ___ DIESEL _ __ ___ _ _ _.. PRE TEST ~ INITIAL~~ry~ 15 MINUTE 30 MINUTE PASS OF2 FAIL ~ ~ ~-~~ PRESSURES PRESSURES PRESSURES PRESSURES TUBING IA OA .___....___......__...._.._......._.....___....._..._.......__.____.._.._-__.__ 0 0 _40._________._______-_- 3,360 3,500 80 _._._.__...___...._. 1,940 2_,080 _140_.__..____....._..._ ........... ...__........._.._...__...__._...____. FAIL COMMENTS TEST #5 _ __ _ _ _ REQUIRED TEST PRESSUF2Ey~ TEST TYPE ~ ~~~--~ ~~~ ~~~ FLUIDS USED TO TEST 3,500 CMIT TXIA DIESEL START TIME: 23:00 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL TUBING 1,620 3,320 1,920 IA 1,700 3,500 2,080 FAIL OA 140 220 140 COMMENTS TEST #6 REQUIRED TEST PRESSURE 3,500 TEST TYPE CMIT TXIA FLUIDS USED TO TEST DIESEL START TIME: 23:29 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL TUBING 1,920 3,360 1,820 660 IA 2,080 3,500 2,020 840 FAIL OA 140 220 120 60 file:fJC:\unzipped\WSR-006~N-12~SAUVAGEAU~ll Ju12007\WSR-006~N-12~SAUV... 10/22/2007 Page 4 of 4 COMMENTS file://C:\unzipped\WSR-006~N-12~SAUVAGEAU~ 11 Ju12007\WSR-006~N-12~SAUV ... 10/22/2007 N-12 workover suspension e e Page 1 of2 Maunder, Thomas E (DOA) From: Roach, Frank [Frank.Roach@bp.com] Sent: Wednesday, August 08,20073:54 PM To: Maunder, Thomas E (DOA) Cc: Reem, David C Subject: RE: N-12(181-D14)workover suspension Attachments: 181-014 N-12 Operations Summary.ZIP Mr. Maunder, Attached is the Operations Summary Report for the work done on N-12. In short, the rig was spotted over the well, pulled SPV, circuated out freeze protect, set and tested TWC (failed), attempted to pull TWC with no luck, suspended operations and moved to Y-10. One day later, the wells group freeze-protected the well again. I forwarded the below e-mail to Doug Cismoski and the plan to remove the stuck two-way check will be forwarded to you as soon as it is finalized. Let me know if there is anything else needed in regards to N-12. Regards, -Frank Roach stAa~NED AUf) 0 9 2007 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] sent: Wednesday, August 08,200711:00 AM To: Roach, Frank Cc: Reem, David C Subject: RE: N-12 (181-017) workover suspension Frank, I presume this is the work authorized by sundry 307-219. Could you please provide the operations summary of the work that actually occurred? This will give us a record of the activities. 307-219 should remain valid for the eventual work unless there would be some major change in the well condition that would prompt altering the work scope. Also, please have the wells group provide a copy of their plan for removal of the stuck valve. Also, when sending a message regarding a well please include the permit number in the title. That helps with looking up information and eventual filing. I look forward to your reply, Tom Maunder, PE AOGCC ---~------_._~~------ From: Roach, Frank [mailto:Frank.Roach@bp.com] sent: Wednesday, August 08, 2007 10:51 AM To: Maunder, Thomas E (DOA) Subject: N-12 workover suspension Mr. Maunder, The RWO on N-12 has been suspended due to a stuck two-way check valve in the wellhead. The wells group is 8/9/2007 N-12 workover suspension e e Page 2 of2 working on a plan to remove the plug and allow us to move back over the well. However, due to budgetary constraints, we may not be able to complete the workover until the beginning of 2008. Please call myself or Dave Reem if there are any questions. Regards, -Frank Roach 8/912007 e e BP EXPLORATION Page 1 of 2 Operations Summary Report Legal Well Name: N-12 Common Well Name: N-12 Spud Date: 5/13/1981 Event Name: WORKOVER Start: 7/28/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/2812007 18:00·00:00 6.00 MOB P PRE Prepare rig to move off of MPH-17 - Skid rig floor· Move off of wetl - Position rig on pad - Remove 20w Diverter bag from from cellar - Remove BOP Stack from cetlar 7/2912007 00:00 - 06:00 6.00 MOB P PRE Install front and rear boosters - Move rig fl Milne point H-Pad to Texaco pad - Let traffic by 06:00 - 14:00 8.00 MOB P PRE Resume moving rig fl Texaco pad to approx. 1 mile past guard shack turn off onto spine road - Road caved in I stuck rig 14:00 - 00:00 10.00 MOB P PRE Attempting to get rig un-stuck and backed onto mat boards 7/3012007 00:00 - 01 :30 1.50 MOB P PRE Cont. to get rig backed onto mat boards I @ approx. 0130 hrs rig is backed up onto mats and no longer stuck 01 :30 - 00:00 22.50 MOB P PRE Cont. to move rig and two step wI double mats 7/3112007 00:00 . 06:00 6.00 MOB P PRE Cont. moving rig wI two step system. using double mats to approx. L - V turn off 06:00 - 10:00 4.00 MOB P PRE Cont. rig move to Z-Pad turn off 10:00 - 22:00 12.00 MOB P PRE Remained @ Z-pad turn off - Due to security 22:00 " 00:00 2.00 MOB P PRE Cont. moving to GPB IN" 12. Rig at W-pad turn off at report closing. 8/1/2007 00:00 - 07:00 7.00 MOB P PRE Cont. moving rig. Rig arrived on N-pad at 07:00 8-1-07 07:00 - 08:30 1.50 MOB P PRE Pull boosters off and starwarz 08:30 -10:30 2.00 MOB P PRE Spot rig on wetl N-12. Shim up, lay herculite and spot rock washer 10:30-11:00 0.50 MOB P PRE Skid rig floor to drilling position. Berm rock washer 11:00-12:00 1.00 RIGU P PRE Hook up water. air, steam and mud lines. Adjust valve in pits. Accept rig at 12:00 8-1-07 12:00 - 16:30 4.50 RIGU P DECOMP RU wing flange on tree, double valve on annulus and circulation lines to hard line. Fill pits wI heated sea water. RU lines to tiger tank and test wI air. 16:30 - 18:00 1.50 RIGU P DECOMP RU DSM lubricator. Pull BPV. RD lubricator 18:00 - 00:00 6.00 CLEAN P DECOMP Proceed to displace freeze protect out of well: pump 30 bbls of sea water down the annulus without retum. Pump 28 bbls of sea water down tubing obtaining return. Swap and pump 85 bbls sea water down the annulus taking diesel (freeze protect) returns to tiger tank. Pump 150 bbls sea water down tubing taking diesel (freeze protect) returns in tiger tank. Wait for diesel migration. Cont. pumping sea water down the tubing and taking returns in tiger tank until displacing all diesel out. Pump total 570 bbls down tubing. Confirm well is dead. 812/2007 00:00 - 01:00 1.00 EVAL P DECOMP Test IA to 1,000 psi. Pressure bleed off to 500 psi in 5 min. Check surface lines and equipment. Test IA to 1.000 psi again and pressure bleed off to 0 psi in 15 min. 01 :00 - 02:00 1.00 WHSUR P DECOMP Install TWC. Attempt to test to 3.500 psi from top. Does not hold. RU rig test pump. Attempt to test again to 3,500 psi. Does not hold. 02:00 - 05:00 3.00 WHSUR N SFAL DECOMP Waiting on DSM to pull and change TWC (crew on job at rig 7ES) 05:00 - 12:00 7.00 WHSUR N DECOMP RU lubricator and test to 500 psi. Attempt to pull TWC. Change retrieval tool and attempt again to pull TWC without success. Work to tighten TWC without success. 12:00 - 17:30 5.50 WHSUR N DECOMP Analize steps to follow and wait on Instructions. Attempt to pull TWC without sucess. Decide to suspend operations on well N-12 and prepare to move rig to well Y-10. 17:30 - 21 :00 3.50 RIGD P SURE RD lines in cetlar. Suck fluids from pits. Unload DP from pipe shed Printed: 81812001 3:31 :03 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 81212007 81312007 814/2007 e e Page 2 of 2 BP EXPLORATION Operations Summary Report N-12 N-12 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/28/2007 Rig Retease: Rig Number: Spud Date: 5/13/1981 End: Description of Operations 21:00 - 00:00 From ~ To Hours Task Code NPT Phase SURE RU little Red. Pump (bull head) 100 bbls of diesel down IA @ 2 bpm - 500 psi. Attempt to bull head down tubing. Pump 0.7 bbIs and pressure to 3,500 psi. Cannot pump down tubing. RD Utile Red. C/O pump in flanges and install blanks on tree Preparing site on well Y-10. Rig down and preparing rig to move to well Y-10 Finish rig down. Skid rig floor to rig move position. Move rig off well and position on pad. Close & suspend ops. on N-12. 00:00 - 01 :00 01:00 - 00:00 00:00 - 06:00 3.00 RIGD P 1.00 WHSUR P 23.00 RIGD P 6.00 RIGD P SURE SURE SURE Ptlnted: 81812007 3:3t:03 PM . ~1f~1fŒ (ID~ ~~~~[\~ . A)'4ASIi.&. OIL AlQ) GAS CONSERVATION COltDllSSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 5CANNED JUL ,0.52007 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU þJ-12. '" Sundry Number: 307-219 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal à Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~8day of June, 2007 Encl. 115 (- 6{L( & 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension MIII..IIUI aye o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. IZI Development D Exploratory 181-014 - 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20557-00-00 / 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 N-12 Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): , 11. Field / Pool(s): ADL 028283 - 79.6' Prudhoe Bay Field / Prudhoe Bay Pool 12.···· //. ..... PRESENT WELt CONDITION SUMMARY .. .... Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10070 - 9271 ' 10010 9217 None None Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 110' 30" x 20" 110' 110' Surface 2681' 13-318" 2681' 2681' 4930 2670 Intermediate 9243' 9-5/8" 9243' 8526' 8150 5080 Production Liner 1316' 7" 8744' - 10060' 8090' - 9262' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): I Tubing Size: Tuþing Grade: Tubing MD (ft): 9713' - 9750' 8948' - 8981' 5-1/2",17# x 4-1/2",12.6# L-80 8803' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker packer I Packers and SSSV MD (ft): 8692' 13. Attachments: 14. Well Class after proposed work: IZI Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: July 17, 2007 IZI Oil o Gas D Plugged o Abandoned 17. Verbal Approval: Date: o WAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Frank Roach, 564-4373 P,;nted NamW Reem Title Engineering Team Leader Prepared By Name/Number: Signature I ./ ~ 11 ~ Phone 564-5743 Date (, .. ]!/<>"'l Terrie Hubble, 564-4628 Commission Use On Iv I Sundry Number:t':() l'" ólltt Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test o Location Clearance Other: "3>500 fe;, ~ðÇ> ~+- Subsequent Form Required: YO~ (á(iIMISSIONER APPROVED BY b~K ,ð1" Approved By: THE COMMISSION Date Form 1 0-403 Revised 06/2006 V~c./ "- Submit In Duplicate ø &~~, STATE OF ALASKA .. ~ RECEIVED ALASKA OIL AND GAS CONSERVATION COM"ION kf.(fi .JUN 2 5 2007 APPLICATION FOR SUNDRY APPROVAL ;:¡¡""ka Oil & Gee " 20 MC 25 280 d" as ons. ommlSSlon ORIG1~'A' ~~tfÍ7 . . N-12 Rig Workover Scope of Work: Pull 5-W L-80 completion, cut and pull 9-5/8" casing above TOC, tie-back wlnew 9-5/8" casing, replace 9-5/8" hanger with emergency slips and primary pack-off, and run 4-W' 13Cr80 completion. MASP: 2266 psi Well Type: Producer Estimated Start Date: July 17, 2007 P R" re- Ig: 0 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well is NOT secured at this time. PPPOT-T & IC. SIC 2 Pull DFV from BAL-O nipple @ 2017' md. Pull Eclipse tubing patch from 8537' md. Pull 2- 7/8" XX Plug. Pull reducing nipple from XN Nipple @ 8772' md. Drift for 5.5" chern cutter to X/O @ 8692' md. E 3 Set Fasdrill plug in middle of first full joint of 4-1/2" tubing below the packer. Shoot string shot and tubing punch for chemical cutter. Chern cut 5-1/2" tubing in the middle of the first full joint of tubing above the packer. F 4 Circulate well with seawater and FP wi diesel thru the cut. CMIT TxlA to 3500 psi. Bleed WHP's to 0 psi 0 5 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-W' tubing string to the cut. 3. Run 9-5/8" RTTS and test 9-5/8" casing above tubing cut. 4. Run 9-5/8" RBP and set at deepest passing RTTS test. PT RBP to 1000 psi to confirm barrier. 5. RU wireline and run US IT from packer to surface. 6. Run 9-5/8" RBP and set at -1000'md below TOC determined from US IT. PT RBP to 1000 psi to prove up barrier. Stack -50 ft of sand on RBP. 7. Mechanically cut 9-5/8" casing in 2nd full joint above TOC. Circulate out Arctic Pack. Pull casing thru stack. Note: VBR's will not be changed to 9-5/8" pipe rams as the well has two tested barriers (2-RBP's) to the reservoir. 8. RIH with new 9-5/8",47#, L-80 casing and sealing casing patch, latch onto casing stub and land on new emergency slips with new primary pack-off. PT 9-5/8" pack-off to 3800 psi. Cement new 9-5/8" casing to surface. 9. Run 4-%" 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -8580' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TV D = 6" CrN GRAY OTIS 79.6' 45.75' 3200' 33 @ 6200' 9638' 8800' SS . N-12 ~NOTES: I PBTD 2017' 1-15-1/2" CAM SSSV LAND NIP, ID - 4.562" . GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 12 2989 2989 3 OTIS DMY RK 0 01/01/07 11 5035 4853 28 OTIS DMY RK 0 2680' j ~ 10 6119 5795 33 OTIS DMY RK 0 9 6261 5914 33 OTIS DMY RK 0 01/01/07 8 6836 6404 31 OTIS DMY RK 0 7 6976 6526 29 OTIS DMY RK 0 72' U 6 7390 6891 27 OTIS DMY RK 0 5 7534 7020 26 OTIS DMY RK 0 R 4 7877 7326 27 OTIS DMY RK 0 3 8021 7454 28 OTIS DMY RK 0 2 8395 7783 29 OTIS DMY RK 0 1 8542 7912 28 OTIS DMY RK 0 03/02/05 ~ ~ , Ì'i8537'- 8574'1-15-1/2" ECLIPSE PATCH, ID-2-992" I I I I 8610' -15-1/2" CAM SLIDING SLV, ID = 4.5" I i ":I I 8675' -1 BKR SBR SEAL ASSY I . " I rx J~ 8692' - 9-5/8" X 5-1/2" BKR PKR, ID - 4.0" I 8692' ì-I 8692' -15-1/2" X 4-1/2" XO I \ I : I 8739' -14-1/2" OTIS X NIP, ID = 3.813" I R 8744' I . ~ . !! .J 8772' -14-1/2" OTIS XN NIP, ID - 3.725" -, 8772' 1-14-1/2" X 2-7/8" NIP REDUCER, ID = 2.31" (04/21/05) " I 8802' 8802' -14-1/2" TBG TAIL ID - 3.958" I I 8796' H ELMD TT LOGGED 07/01/82 I " I 9241' I ~ ~ RY 9644' 1-17" MARKER JOINT I 05/29/81 I @ 9678' storical perf data I /Sqz DATE S 02/23/92 0 01/13/96 [ I 10010' I " 10060' I 113-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.31" @ 87 2-7/8" NIPPLE REDUCE 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892 I TOP OF 7" LN 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958 I 9-5/8" CSG, 47#, L-80, ID = 8.681 ÆRFORA TION SUMMA REF LOG: SWS-BHCS ON ANGLEATTOPÆRF: 24 Note: Refer to Production DB for hi SIZE SPF INTER V AL Opn 3-1/8" 4 9678 - 9700 3-3/8" 12 9713-9750 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184 DATE 06/02/81 OS/24/05 07/19/05 08/20/05 09/25/05 09/19/06 REV BY COMMENTS ORIGINAL COM PLETION JNA/PJC ECLIPSE PATCH RWL/PJC GL V C/O RPH/TLH WAIVER SFTY NOTE DELETED WTSffiH PULLED XX A..UG (06/30/05) DRF/TLH NIP REDUCER (04/21/05) DA TE REV BY COMMENTS 12125/06 RMHlPA G CORRECT NIP REDUCER ID 01/01/07 RCT/TLH GLV C/O PRUDHOE BAY UNIT WELL: N-12 ÆRMIT No: 1810140 API No: 50-029-20557-00 SEC8, T11N, R13E BP Exploration (Alaska) ... ' . ... . TREE: waLHEAO: ACTUA TOR '" KB. ELEV '" B K Ma Da Da 6"CW GRAY OTIS 79.6' N-12 PROPOSED NOTES: 14 F. ELEV '" 45.75' OP'" 3200' 1-14-1/2" HES X NiPPlE, 10 = 3.81 X Angle '" 33 @ 6200' I . I turn MD '" 9638' turn TVO: 8800' S5 19-5/8" CSG. 47#. L-80. 10 = 8.681" I I GAS LIFT MANDRELS 113-3/8" CSG, 72#, L-80, ID '" 12.347" I 2680' ~ ~ ST MD TYPE VLV r - 4 3406 4-1/2" 1-1/2" I 3 6006 4-1/2" 1-1/2" ~ 2 7512 4-1/2" 1-1/2" 1 8490 4-1/2" 1-1/2" Minimum ID = 2.725" @ 8772' 4·1/2" OTIS XN NIPPLE I 1-14-1/2" HES X NIPPLE, 10 = 3.813" I 8 ""S? .J -19-5/8" X 4-1/2" BKR S-3 PKR, 10 = 3. ---- I . 4-1/2" HES X NIPPLE, 10 = 3.813" 1 _1/2" TBG, 12.6#. 13Cr-80. .0152 bpf. 10 = 3.958" I I I -14-1/2" MULESHOE I I . . 8675' -1BKR SBR SEAL AS5Y I 15-1/2" TBG, 17#, L-BO, .0232 bpf, ID = 4.892" "S2" J~ 8692' -19-5/8" x 5-1/2" BKR PKR, ID '" 4.0" , 8692' ~ 8692' -15-1/2" x 4-1/2" XO I \ . : 8739' -14-1/2" OTIS X NIP, ID = 3.813" I TOPOF 7" LNR I 8744' I . I -I 8772' -14-1/2" OTIS XN NIP, ID '" 3.725" I -1/2" TBG, 12.6#, L-80, .0152 bpf, ID '" 3.958" I 8802' 8802' -14-1/2" TBG TAL ID '" 3.958'" I 8796' HELMDTTLOGGED07/01/82 I I 9-5/B" CSG, 47#, L-BO, ID = 8.681" 9241' I ... ~ PERFORA mN 5UWMRY 9644' 1-17" MARKER JONT I REF LOG: SWS-BHCS ON OS/29/81 ANGLE AT TOP PERF: 24 @ 9678' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/5qz DATE 3-1/8" 4 9678 - 9700 5 02/23/92 3-3/8" 12 9713 - 9750 0 01/13/96 [ I PBTD , 10010' I 7" LNR, 29#, L-80, .0371 bpf, D'" 6.184" I 1 0060' I 3" 875" I 14 DATE 06/02181 OS/24/05 07/19/05 08/20/05 09/25/05 09/19/06 REV BY COrvtÆNTS ORIGINAL COMPLETION JNA/PJC ECLIPSE PATCH RWlJPJC GLV C/O RPHiTlH WAWER SFTY NOTE DB.ErED WTSITLH PULLED XX PLUG (06/30/05) ORFITLH NIP REDUCER (04/21/05) DA TE REV BY COWMENTS 12/25/06 RMHIPAG CORRECT NIP REDUCER 10 01/01/07 RCTITLH GLV C/O PRUDHOE SA Y UNIT waL: N-12 PERMIT No: 1810140 API No: 50-029-20557-00 SEC8, T11N, R13E BP Exploration (Alaska) N-12 (PTD #1810140) Classified as Problem Well ) Subject: N-12 (PTD #1810140) Classified as Problem Well From: " Anders, Joe L" <anders22@BP .com> Date: Sun, 20 Feb 2005 13:54:12..0900 1:~: ",'OPE, GC2"Area'Mgr", <GPBGC2TL@BP.com~,"Warren,:Mike ;(Orbisy' <Wme11M@))3P~Çorn>,I"N'StJ"ADWW~119peråtiòi1s''SuperVi,sòr'''c.. '..," , <N;SUÞil)WW ellOpe(atl()nsSupe~ispr@BB.com>,: '~GPB, Wells Ûpt'Eng~' <GPBW ellSOptEn8@jBP ~c()m>,"NSp~.ADrwWL& COnw1etiOri~~\Ìpervisor'" <NSUADWwL&C9tppleti6nSup~rvi~pr@:sP.coin>, ~'G~B,,~JdÖP~'~~å4" :.' .'" I .' " <;:QPBFldOpsLead@BP.com>, :"Gl>B; ",ØpSJ\t1gr": <GPBOpsMgr@BP.com>, .",Rossberg, ~Ste;yenlf, ': . <~()ssbëR:$@~P .co~>, :"AJ?GÇCWi~to~Auqert "(E~Ii1~H)" . ~~i~tÖl1' ~u~ert<ãfaø~n~s!at~.åk.us>,: . "AQQCC '~il1lReggCE~mail)"<jìm~regg@admin,stat~.ak;.u~?-,'''G~B~GÇ2.Wef1þad.tea~'~.; "'.'. <S!PBGC2W~lIpadLead~BP.cpm?,,~'GPB~ WeUPads:NyP'" o<GPBW ellPadsSUN@~~.~~rn?>'\,.., " .,',' C<Ç: "NSV)I ÄDW. Well Integrity :angineeru' <NSUA.DW'YellIilte~ityEngineer@BP ~cdm~,': "R,eev~s'," I , . '. " " ,I " , I, I ' "'I" ,', ''''',' I ",' 'I I I ". DqnaldF" <ReevesDf@BP~com> ' ". " " .' . ) ttòt:~'D~lt. He 110 all. Well N-12 (PTO #1810140) has sustained casing pressure on the IA and has been classified as a Problem well. The well failed a No-Flow test on 2/19/05. The plan for this well is as follows: 1. SL: Run OGL V's 2. DHO: Re- TIFL Attached is' a well bore schematic. Please call if you have any questions. «N-12.pdf» Joe Anders, P.E. Well Integrity Coordinator BP Exploration (Alaska), Inc 1-907 -659-51 02 anders22@bp.com SCAN,NED MAR 1 0 2005 1 of 1 2/22/2005 3:37 PM 6"CIW GRAY OTIS ..'W''''WY,^^M..\ "''''.A,WW 79.6' 45.75' 3200' 33 @ 620()' '''''' ,. '9638' 8800' SS ) TREE :: WELLHEAD == ",""''''~W''I'MW^ "'w"""",, .W'''''' ,^^ .,,\\"- . .. ACTUATOR :::: ,,, v w" ,;. vw.'" KB. B..EV = 'BF~ äBi :: KOP"~ Max Angle :: Datum MD :: Datum TVD= r 13-3/8" CSG, 72#, L-80, ID :: 12.347" 1-1 2680' ~ Minimum ID = 3.725" @ 8772' 4.1/2" OTIS XN NIPPLE I 5-1/2" TBG. 17#, L-BO, .0232 bp"f, ID = 4.892" l-i 8692' 1 ' I TOP OF 7" LNR l-i 8744' 14-1/2"T8.G, 12.6#,L-80..0152bpf", ID=3.~5a," 1-1 8802' 19-5/8" CSG, 47#. L-80, ID= 8.E>81" 1-( 9241' ~ ÆRFORA TION SUMMARY REF LOG: SWS-8HCS ON OS/29/81 ANGLE AT TOP PERF: 24 @ 9678' Nate: Refer to Production DB ~or historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-1/8" 4 9678 - 9700 S 02/23/92 3-3/8" 12 9713-9750 0 01/13/96 I PBTD l-i 1 001 0' 1 17" LNR, 29#, L-80, "0371 bpf, ID:: 6.184" l-i 10060' I DATE 06/02/81 11/06/01 08/04/04 12/10/04 COMMENTS ORIGINAL COM PLETION RN/TP CORRECTIONS KS8/TLP GL V C/O RDJrrLH WAIVER SAFETY NOTE OA TE REV BY REV BY i n N-12 8 L I I í ~\ I 18 I l ~ COMMENTS SAF. )NOTES: ***TxIAxOACOMM. OPERATING LIMITS: MAX lAP = 2000 PSI, MAX OAP = 2000 PSI (11/17/04 WAIVER)*** 2017' 1-i5-1/2" CAM SSSV LAND NIP, 10:: 4.562" 1 ~ GAS LIFT MANDRB..S ST MO TvD òEV ìYÆ VLV 'LATCH PORT"' DATE 12 2989 2909 4 OTIS DOME RK 16 11 5035 4774 28 OTIS DMY RK 0 10 6119 5715 33 OTIS DMY RK 0 9 6261 5835 32 OTIS DOME RK 16 8 €>836 6325 31 OTIS DMY RK 0 7 6976 6446 29 OTIS DMY RK 0 6 7390 6811 27 OTIS DMY RK 0 5 7534 6940 26 OTIS DMY RK 0 4 7877 7246 27 OTIS DMY RK 0 3 8021 7374 28 OTIS OMY RK 0 2 8395 7703 29 OTIS DMY RK 0 1 8542 7833 29 OTIS SO RK 0 08/04/04 8610' 1-15-1/2" CAM SLIDING SLV, ID = 4.5"1 8675' l-i 8KR SBR SEAL ASSY I 8692' 8692' 1-i9-5/8" X 5-1/2" BKR PKR, 10:= 4.0" 1 1-i5-1/2" X 4-1/2" XO I 1-i4-1/2" OTIS X NIP, ID = 3.813" I 8739' I 8772' 1-(4-1/2" OTIS XN NIP, ID:= 3.725" J 8802' 1-[4-1/2" TBG TAil 10 = 3.958" I 8796' . J-i ElMD IT LOGGED 07/01/82 I I.. 9644' 1-i7" MARKER JOINT I PRUDHOE BAY UNIT WB..L: N-12 ÆRMIT No: 1810140 API No: 50-029-20557-00 SEC 8, T11 N, R13E BP Exploration (Alaska) STATE OF ALASKA ALASKA ")_ AND GAS CONSERVATION COt )ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P;O. Box 196612, Anchorage, Alaska 99519-6612 []Operation Shutdown [~Stimulate [] Pull Tubing r-]Alter Casing [] Repair Well I-]Other t5. Type_Q[ well: IX] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 1144 NSL, 543' EWL, SEC. 08, T11N, R13E, UPM At top of productive interval 236' SNL, 2170' WEL, SEC. 17, T11N, R13E, UPM At effective depth 412' SNL, 1991' WEL, SEC. 17, T11N, R13E, UPM At total depth 430' SNL, 1973' WEL, SEC. 17, T11N, R13E, UPM [] Plugging E~ Perforate 6. Datum Elevation (DF or KB) KBE = 79.60' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number N-12 (31-17-11-13) 9. Permit Number / Approval No. 81-14 10. APl Number 50-029-20557 11. Field and Pool 12. Present well condition summary Total depth: measured 10070 feet Plugs (measured) true vertical BKB 9270 feet Effective depth: measured 10010 feet Junk (measured) true vertical BKB 9216 feet Casing Length Size Structural Conductor 76' 20"x30" 8 c.v. Surface 3647' 13-3/8" 3808 c.f. Intermediate 9209' 9-5/8" 1457 c.f. Production Liner 1316' 7" 360 c.f. Cemented MD TVD 110' 110' 2681' 2681' 9243' 8526' 8744'-10060' 8090'-9261' Perforation depth: measured 9713'-9730'; 9730'-9750' (open) 9678'-9700' (Sqz) true vertical 8948'-8963'; 8963'-8982' (open) 8916'-8936' (Sqz) Tubing (size, grade, and measured depth) 5-1/2", L-80 to 8692 with 4-1/2" tailpipe to 8803' Packers and SSSV (type and measured depth) 9-5/8" Baker SAR packer at 8692'; 5-1/2" SSSV at 2018' 13. Stimulation or cement squeeze summary Intervals treated (measured) See attachment Treatment description including volumes used and final pressure OR G NA 14. Prior to well operation: Subsequent to operation: Representative Daily Average Pr0d~JCti¢n or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 780 801 543 0 327 15. Attachments 16. Status of well classifications as: [-1 Copies of Logs and Surveys run [] Oil [] Gas [] Suspended [--I Daily Report of Well OperatiCjls 17.1 hereby ce.r~y tl~ the,{16reg¢~g i,s true an/d ,CCC-oct Service to the best of my knowledge Title Technical Assistant IV Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Submit In Duplica~ N-12 DESCRIPTION OF WORK COMPLETED Stimulation Operation 10/13/99 A Acid Stimulation Treatment was performed using the following fluids: SUMMARY MIRU CTU. RIH w/BHA #1 while pumping down backside to kill. Dry tag fill at 9,727' and begin pumping 10 bbl acid displace w/2% KCI. With acid at nozzle open backside line and pump down both the coil and the annulus while jetting down over perfs to 9,750' (no tag). Shut backside and open wing to lay in remaining 5 bbls. Allow to soak for 30 minutes. Pump remaining 30 bbls of acid and displace with KCI. Jet acid from 9,700' to 9,770' (CTMD) in one down/up pass. With all the acid out of the nozzle continue pumping 30 bbls to displace acid into perfs. POOH filling voidage and freeze-protecting coil. On surface with coil- RDMO Dowell. POP well. Fluids Pumped BBLS. Description 340 Freshwater w/2% KCI & friction reducer. 40 Acid 33 Meoh 413 Total Pumped BP Exploration(Alaska), Inc. N-12 Prudhoe Bay Pressure (psia) GAS LIFT SURVEY lOO0 2000 3000 4000 5000 6000 7OO0 8000 90OO 100 300 500 700 900 0 I I i FBHP = 692 PSIA PEeAe~ I,. Temperature (deg F) 80 120 160 200 240 280 D Temp -1 0 I GLM 1 2 3 4 5 6 7 8 9 10 11 12 I I r i Test Data DATE FLUID OIL GAS WATER GOR LG CSG P TGOR TGLR CHOKE MP MT W CUT August 28, 1999 0.91 MBD 0.74 MBOD 1.06 MMSCFD 0.16 MBWPD 1458 SCF/STB 2.43 MMSCFD 1028 PS~G 4729 SCF/STB 3871 SCF/BBL 96.0 DEG 179 PS~G 96 DEGF 18.1 % ' Wellhead Data WHP - WHT Ia oa 2OO 8O 1040 52O psig deg. F. psig psig Depth (MD) 8,542 8,395 8,021 7,877 7,534 7,390 6,976 6,836 6,261 6,119 5,035 2.989 Depth (TVD) 7,832 7,703 7,374 7,246 6,940 6,811 6,446 6,325 5,835 5,715 4,773 2,909 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 12 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL R-34 (13-34-12-13.) DESCRIPTION 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 CCL FINAL BL+RF ECC No. Run # 1 1393.06 Run $ 1 1414,~05 Run $ 1 6083.11 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: ~/ / ~ /Y / Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 CN FINAL BL+RF 1 CN FINAL BL+RF 1 PDK FINAL BL+RF i'PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 1390.11 Run # 1 1393.05 Run # 1 4352.02 Run # 1 4590.03 Run # 1 5853.04 Run # 1 6308.02 Run # 1 6444.05 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Received Suite 201 Anchcrage, AK 99518 AX to (907) 563-7803 Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 December 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: / ECC No. 1 .1393,04' i 5972.02 , / Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 3-7803 Received by: Date: RECEIVED JAN O~ 1996 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE A/<, 99501. Date: 12 December 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: N-15 (14-05-11-13) DESCRIPTION iCN'FINAL BL+RF i GR/CCL FINAL BL+RF 1 CN FINAL BL+RF i CN FINAL BL+RF i PFC/PERF FINAL BL+RF i PLS FINAL BL+RF i PFC/PERF FINAL BL+RF ECC No. Run ~ i 1390.10 Run # i Run # 1 1393.04 Run # 1 2384.02 Run # i 4904.01 Run # I 5791.06 Run ~ I 6063.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services ... '5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Date: STATE OF ALASKA ~. ~ AL' '~)A OIL AND GAS CONSERVATION COMMISr REPORT 'OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate 3( Plugging Perforat~ Pull tubing Alter casing Repair well 2. Name of Operator I 5. Type of Well: BP Exploration (Alaska)/nc. I Development X Exploratory 3. Address Stratigraphic P. O. Box 196612, Anchorage, Alaska 99519-6612 service 4. Location of well at surface 1144'NSL, 543' EWL, SEC. 08, T1 IN, R13E, UPM At top of productive interval 236' SNL, 2170'WEL, SEC. 17, T11N, R13E, UPM At effective depth 412'SNL, 1991' WEL, SEC. 17, T11N, R13E, UPM At total depth 430' SNL, 1973' WEL, SEC. 17, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical 10070 feet BKB 9270 feet Plugs (measured) Other X Datum elevation (DF or KB) KBE = 79.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number N-12 (31-17-11-13) PBU 9. Permit number/approval number 81-14 / 10. APl number 50- 029-20557 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 10010 feet true vertical BKB 9216 feet Junk (measured) Casing Length Size Structural -- ConduCtor 110 20 x 30 Surface 2647 13 3/8 Intermediate 9209 9 5/8 Production -- Liner 1316 7 Perforation depth: measured 9730'- 9750' Cemented Measured depth 144 2681 9243 8 c.y. 3808 c.f. 1457c. f. 360 c.f. 8744-10060 Sqzd 9678'-9700', 9720'-9730' True vertical depth BKB 144 2681 8526 8090-9261 true vertical subsea 8883L8901'(three~tervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8692' with 4 1/2" tailpipe to 8803' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8692'; 5 1/2" SSS Vat 2018' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1999 19501 1356 0 1109 3264 26 1220 Tubing Pressure 1049 194 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby ~ertify that the foreg.q~g is true and correct to the best of my knowledge. Signed(~~~(/ ~/~ Title Senior TechnicalAssistant II Form 10-404 Rev 06/15/88 ~'- ' ' Date SUBMIT IN DdPLI~:ATE 10~5~4 12/2/94 12/14/94 WELL N-12(31-17-11-13) NRW O/A d dperf/S timula tion Operation A NRWO Chemical Squeeze was performed using the following fluids: SUMMARY: GLT line was hot with IAP = 2000 psi on arrival. Shut in GLT line and IA slowly bled off. Shot fluid level at 5005', and concluded that tubing and IA were in communication. Bled IA back to 250 psi, in preparation to fluid pack tubing and IA. IA climbed back to 980 psi in 2.5 hours. Shut in well at 1340. Killed well down backside of coil with 330 bbl SW. RU IP and Petredat outside gauge with carrier, spotting valve and TIH. Located the TT and made 17' correction. Set packer at 9710 ft and open the spotting valve. Fluid packed the IA with 91 bbl of recycled diesel and 110 bbl of filtered SW. Conducted injectivity test down the CT at 2.5 bbl/min at 1190 psig. Pumped 25 bbl of With 6.5 bbl of SW behind, the N-3390 was at the perfs. The pressure increased from 1100 to 1850 and the rate was reduced from 1 to 0.5 bpm. When the diesel was at the peffs the pres. dropped and the rate was increased. With 26 bbl SW, the N- 3374 was at the perfs. The rate was adjusted to keep it at 1800 to 1900 psig. At 32 bbl SW behind the treatment, the pressure increased to 1880 psi. All of the treatment was placed in the perforation at 9678' to 9700' Shut down Unset packer and POOH. FP CT with 33 bbl, RD tools and recovered all of the IP element FLUIDS PUMPED 497 Bbls Sea Water 40 Bbls Diesel 91 Bbls Recycled Diesel The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9735 9745 MD A HCL Acid Wash Treatment was performed using the following fluids: SU~RY: PUMPED 55 BBLS OF DIESEL AND 100 BBLS OF DEAD CRUDE AS DISPLACEMENT FOR TBG WASH. THE WELL WENT ON VAC WHILE PUMPING DIESEL STAGE AS DISPLACEMENT. HAD TROUBLE PUMPING DIESEL AND MONITORING THE RATE DUE TO AN ICE PLUG IN VAC TRUCK'S CONNECTION HOSE. REGAINED ABILITY TO MONITOR RATE AND REGAINED SOME PRE3SURE WHEN SWITCH TO DEAD CRUDE WAS MADE. HOWEVER, DID MANAGE TO ACHIEVE 15 MIN. CONTACT TIME Page 2 WELL N-12(31-17-11-13) WHILE PUMPING ACID FOR TUBING WASH. PUMPED EXCESS DEAD CRUDE AND DIESEL DOWN THE FLOWLINE. ACID STAYED IN THE TUBING A LITTLE LONGER THAN DESIRED PRIOR TO FLOW BACK DUE TO THE FLAPPER VALVE CLOSING. HAD TO CALL OUT GREASE CREW TO PUMP OPEN FLAPPER. THE WELL FLOWED BACK OK AFTER THE VALVE PROBLEM WAS RECTIFIED. PUMPED THE REMAINDER OF THE JOB AS PER PROGRAM. DISPLACEMENT VOLUME FOR STIMULATION PORTION OF PROGRAM WAS A TAD BIT MORE THAN REQUESTED. FLUIDS PUMPED DOWNHOLE SEA WATER: 150 BBL 15 % HCL/10 % XYLENE 44 BBL TOTAL = 194 BBL RECEIVED ~aska Oil & Gas Cons. Commi~i~ll- Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 15 March 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL \' '~"~::~'~:~ N- 12 z- o DESCRIPTION PLS/STP FINAL BL+RF GR/CCL FINAL BL+RF GR/CCL FINAL BL+RF Run # 1 Run ~ 1 Run # 1 ECC No. 1393.03 6237.01 6273.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 9 July 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL N-12 B-27 B-14 (43-32-11-14) H-07 (22-11-13) E-12 ~ DESCRIPTION /'1~ PDK/GR LDWG TAPE+LST /1 CN/GR LDWG TAPE+LIST ,.,~ CN/GR LDWG TAPE+LIST ---1 CN/GR LDWG TAPE+LIST jl CN/GR LDWG TAPE+LIST ECC No. Run # 1 1393.01 Run # 1 5603.04 Run # 1 5073.03 Run # 1 4096.01 Run # 1 1291.01 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: ~ ~~ Date: Please s f.g~ and return to: .Petrotec~ical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99508 Received by JUL 7 ? !99 Date AlaSl~ 011 & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 June 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL N-12 R-28 (44-31-12-13) DESCRIPTION PDK/ R/OOL FINAL PDK/GR/CCL RF SEPIA PLS FINAL BL PLS FINAL RF SEPIA C-06 (30-11-14) B-29 (32-31-11-14) /1 DTEMP/GR FINAL BL 1 DTEMP/GR RF SEPIA 1 COLLAR/PERF FINAL BL 1 COLLAR/PERF RF SEPIA ECC No. Run # 1 1393.01 Run # 1 Run # 1 5707.04 Run # 1 Run # 1 6221.00 Run # 1 Run # 1 5818.04 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by D~e STATE OF ALASKA AL "'~(A OIL AND GAS CONSERVATION COMMIS"- REPORT OF SUNDRY WELL OP=I::IATIONS 1. Operations performed: Operation shutdown Stimulate x Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1144'NSL, 543' EWL, SEC. 08, T11N, R13E, UPM At top of productive interval 236'SNL, 2170'WEL, SEC. 17, T11N, R13E, UPM At effective depth 412°SNL, 1991'WEL, SEC. 17, T11N, R13E, UPM At total depth 430'SNL, 1973'WEL, SEC. 17, T11N, R13E, UPM 5. Type of Well: Development X Exploratory Stratigraphic Sewice 6. Datum elevation (DF or KB) KBE = 79.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number N-12 (31-17-11-13) PBU 9. Permit number/approval number 81-14 / 10. APl number 50- 029-20557 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 10070 feet BKB 9270 feet Effective depth: measured 10010 feet true vertical BKB 9216 feet Casing Length Size Structural -- Conductor 110 20 x 30 Surface 2647 13 3/8 Intermediate 9209 9 5/8 Production -- Liner 1316 7 Perforation depth: measured 9678'- 9700', 9720'- 9750' Plugs (measured) Junk (measured) Cemented 8 c.y. 3808 c.f. 1457 c.f. 360 c.f. Measured depth 144 2681 9243 8744-10060 True vertical depth BKB 144 2681 8526 8090-9261 true vertical subsea 8836'-8901' (two intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8692' with 4 1/2" tailpipe to 8803' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8692'; 5 1/2" SSSV at 2018' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 860 1778 1455 1738 1700~ '/' 2492 2997 1775 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the foregoi.~l is true and correct to the best of my knowledge. Signed ~'~/~,~.~ (/;)~ D,.~,,~ ~ TitleSeniorTechnicalAssistantl Form 10-404~Rev 06/15/88 ~ JdN 1 4 1994 ~i.~a o~i & Gas Cons. Cot Annhnmn~, Tubing Pressure 317 302 Service SUBMIT IN DOPLi~ATI~ ~ission 1/16/93 WELL N-12(31-17-11-13) Stimulation Operation A HCL Acid Wash Treatment was performed using the following fluids: JOB SUMMARY 1/16/92- SI GLG AT 0100. PERFORM WEEKLY BOP FUNCTION TEST. OK. LIQUID PAK WELL WITH 90 BBLS SW. RIH WITH BHA LISTED BELOW. DROP 1/2" BALL TO SET PKR. NO LUCK. SURGE PUMP AND WORK COll. NO LUCK. DROP SECOND BALL. SURGE PUMP AND WORK COll. NO LUCK. POOH. ALL BHA OOH. BOTH BALLS ON SEAT. SEAT IS PROPERLY SHIFTED. BREAK OFF HYD TEL AND PKR. PT REST TO 3000 PSI. OK. THE PROBLEM IS IN THE HYD TEL OR PKR. POP, RDFN. NOTE: INSPECTION SHOWED THAT THE PACKER BLADDER WAS RUPTURED AND NEVER ATTEMPTED TO INFLATE. 1/17/92- RIH WITH BHA LISTED BELOW. LIQUID PACK BACKSIDE WITH 100 BBLS SW. SET PACKER. SET DOWN WEIGHT ON PACKER- GOOD SET. RIG UP BJS. AFTER WORKING OUT FREEZE LIP PROBLEMS, PUMP TREATMENT PER PROGRAM SCHEDULE. RATE METER WAS NOT FUNCTIONING PROPERLY DURING lOB. VOLUMES WERE DETERMINED BY STRAPPING TANKS, AND THEREFORE STIMULATION/DIVERSION EFFECTS WERE AMBIGUOUS. POP, RI)MO. COORDINATE FOR HOURLY PH SAMPLING DURING FLOWBACK. FLUIDS PUMPED 1/16/93 91 FILTERED SEA WATER (Bbls) DOWN COIL 45 METHANOL FLUIDS PUMPED 1/17-18/93 280 BBL FILTERED SEA WATER (Bbls) DOWN COIL 75 BBL METHANOL 38 BBL 15% HCL WITH ADDITIVES 35.7 MSCF NITROGEN fjh 6/10/94 RECEIVED JUN 1 4 i994 Alaska Oil & Gas Cons. CommissJor, Anchorage REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1144' NSL, 543' EWL, SEC. 08, T11N, R13E, UPM At top of productive interval 236' SNL, 2170' WEL, SEC. 17, T11N, R13E, UPM At effective depth 412'SNL, 1991' WEL, SEC. 17, T11N, R13E, UPM At total depth 430' SNL, 1973' WEL, SEC. 17, T11N, R13E, UPM 5. Type of Well: Development X Exploratory Stratigraphic Service I 6. Datum elevation (DF or KB) KBE = 79.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number N-12 (31-17-11-13) PBU 9. Permit number/approval number 81-14 / 10. APl number 50- 029-20557 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 10070 feet BKB 9270 feet Effective depth: measured 10010 feet true vertical BKB 9216 feet Casing Length Size Structural -- Conductor 110 20 x 30 Surface 2647 13 3/8 Intermediate 9209 9 5/8 Production -- Liner 1316 7 Perforation depth: measured 9678'- 9700', 9720'- 9750' Plugs (measured) Junk (measured) Cemented 8c.y. 3808 c.f. 1457 c.f. 360 c.f. Measured depth 144 2681 9243 8744-10060 True vertical depth BKB 144 2681 8526 8090-9261 true vertical subsea 8836'-8901'(two intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8692' with 4 1/2" tailpipe to 8803' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 8692'; 5 1/2" SSSV at 2018' 13. Stimulation or cement squeeze summary 14. See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED S E P 1 0 199; Alaska 0il & Gas Cons, C0mmiSs't0it Representative Daily Average Production or In!ection D~ta Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 730 1000 635 2560 309 770 'j'~ 1371 2345 1560 347 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X: Gas Suspended Service 17. I hereby certify that the foregoing[s, true and correct to the best of my knowledge. Signed ~ .4('j.,~ a 0,~,,., ~_.J ~P/'~.,-,.~'~ Title SeniorTechnicalAssistantl Form 10-4~R~v06/15/88 ' -~ ..... Date 8UBMIT IN DUP'LIC"ATE WELL N-12(31-17-11-1~) NRWO/Reperf/HCL 2/23/92 A NRWO was performed using the following fluids: FLUIDS 378 BBLS PW TO LOAD WELL 61 BBLS PW TO CIRC WELL (NO RETURNS) 127 BBLS PW TO COOL SUMP 288 BBLS PW TO LOAD WELL 112 BBLS PW MEOH 5 BBLS EW(PREFLUSH) 16 BBLS CEMENT 17 BBLS EW (SPACER) 27 BBLS PW(DISPLACEMENT) 25 BBLS PW (REVERSE OUT) 26 BBLS DUO POLYMER(CONTAMINANT) 36 BBLS PW(DISPLACEMENT) 208 BBLS PW(REVERSE OUT) 83 BBLS RECOVERED(GLG DISPLACEMENT) 35 BBLS MEOH(FREEZE PROTECTION CT) WELL CLEANED OUT TO 9877' 640 BBLS LOAD FLUID BEHIND PIPE(CUMULATIVE APPROXIMATE TOTAL LOAD FLUID BEHIND PIPE IS 640 BBLS) 9 BBLS CEMENT RECOVERED(DOES NOT INCLUDE CEMENT NOT PUMPED) CEMENT: 15.5 PPG CLASS G CEMENT CONTAINING, .2% CFR-3, .3% HR-12, .15 GAL/SK HALAD-344L so_z#1 3/O2/92 The following interval were reperforated using 3 3/8" guns,6 SPF, random orientation and 60° phasing. 9730' - 9750' MD 4/17192 A HCL Coiled Tubing/Packer Stimulation was performed using the following fluids: 306 BBLS Filtered Seawater 63 BSLS MEOH 25 BBLS 15% HCL ACID 2 BBLS DIVERTER 6/28/92 A HCL Coiled Tubing/Packer Stimulation was performed using the following fluids: 257 8BLS Filtered Seawater used to load hole and set packer 36 88LS 15%HCL. AG-12.4% ACI274(CI), .6% NE41 (NON-FE SURF.) .2% MS-10(MS); 24#/1000GAL F210(FE SQ) HCL 32 8BLS Filtered Seawater NE-18 10GAL/1000GAL 4.5 8BLS 75 Quality Foam Using 18,562 SCFN2 4125 SCF/SBL; .4 F^W-1 6 Foaming Agent 33 8BLS Filtered Seawater 9/15192 fjh 5/20/93 A HCL Coiled Tubing/Packer Stimulation was performed using the following fluids: 24 BBLS 15%HCL 28 BBLS Treated SW(for Spacer) 21 BBLS Methanol 172 BBLS Plain Seawater 24 BBLS SW for foam 100,00 SCF Nitrogen Alaska Oil & Gas Cons, .C.0_mmissic~., AnchoraffO BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 05/04/93 T9 84544 BP/PBU CH LOGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at A-Ii _ f~,,INJ/TEMP ~A-32 ~'~'~LEAK DET -077~-o~ PFC B-347 ?ROD-F .c-08 ~7~ '~ODUC~O. ~OG C-ll 7~.~4 ~ODOC~O~.~OG ~.c-26 ~ ,~-027~..~$ ~o~uc~zo~ ~oG E-29 ~7.~3 PROD-F ~'.G-06 ?~-~_ ~EA~ DET I~H-19 ~2-~I3PRODUCTION LOG --s-3~ ~-U~ e~c 04/29/93 91 04/21/93 91 04/28/93 91 04/27/93 91 04/27/93 91 04/30/93 91 04/30/93 91 04/28/93. #1 04/28/92 #1 04/28/93 91 04/23/93 #1 04/27/93 91 04/23/93 #1 05/01/93 91 04/29/93 91 Information Control ~ell Records below. If you have any (907) 564-4004. 9350.00-10062.00.ATLAS 5 " 2200.00-10332.00 ATLAS 2+5" 11414.00-11768.00 ATLAS 5 " 11500.00-12054.00 ATLAS 5 " 11500.00-12054.00 ATLAS 5 " 9800.00-10232.00 ATLAS 5 " 9500.00- 9970.00 ATLAS 5 " 11500.00-11680.00 ATLAS 5 " 9600.00- 9994.00 ATLAS 5 " 11950.00-12214.00 ATLAS 5 " 9350.00- 9590.00 ATLAS 5 " 11100.00-11525.00 ATLAS 5 " 9600.00-10225.00/ATLAS 5 " 9500.00- 9842.00 ATLAS 5 " 10230.00-10511.00 ATLAS 5 " o~, STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COMMIS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1144'NSL, 543'EWL, SEC. 08, T11N, R13E, UPM At top of productive interval 236'SNL, 2170' WEL, SEC. 17, T11N, R13E, UPM At effective depth 412'SNL, 1991' WEL, SEC. 17, T11N, R13E, UPM At total depth 430' SNL, 1973' WEL, SEC. 17, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Stimulate Plugging Alter casing Repair well 5. Type of Well: Development :X Exploratory Stratigraphic Service Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured lO070feet Plugs (measured) BKB 9270feet lO010feet Junk (measured) BKB 9216feet Perforate X Other 6. Datum elevation (DF or KBE = 79.60 7. Unit or Property name Prudhoe Bay Unit 8. Well number N-12 (31-17-11-13) PBU 9. Permit number/approval number 81-14/9-629 10. APl number 50- 029-20557 11. Field/Pool Prudhoe Oil Pool Length Size Cemented .. 110 20x 30 8 c.y. 2647 13 3/8 3808 c.f. 9209 9 5/8 1457 c.f. .. 1316 7 360 c.f. 9678'- 9700', 9720'- 9750' Measured depth 144 2681 9243 8744-10060 True vertical depth BKB 144 2681 8526 8090-9261 true vertical subsea 8836~8901'(two ~rvals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8692' with 4 1/2" tailpipe to 8803' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. 9 5/8" Baker SAB packer at 8692'; 51/2" SSSV at 20_~_' F C ~ ~ V £D Alaska Oil & Gas Cons. Comm'tss'to~ Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure **Job waa Cancelled** Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations ' 17. I hereby qertify that the fore_aj3J.ng Form 10-404 Rev 06/15/88 / 16. Status of well classification as: Oil )~ Gas Suspended Service is true and correct to the best of my knowledge. ~' D,/v~ Title Senior Technical Assistant I SUBMIT IN DU'PL{CATE ' ~ WELL N-12(31-17-11-13) ADDPERF Approval#9-629 The proposal to perform a additional perforation was sent to you for N-12. The job was not performed. fjh 2/23/93 RECEIVED Alaska Oil & G~.~ Cons. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03/10/92 T# 83313 HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. H-08 ~-Z) PERF 02/27/92 F-40 ~/'WJF PERF ~/--//~ 02/28/92 N-12 8/'/~ PERF 03/02/92 F-41~/-/~FPRODUCTION LOG 02/26/92 E-10~f-/~ TDT-P 02/29/92 .Z-16 ~' CBT 03/04/92 X-17 $/-~&~ PRODUCTION LOG 03/04/92 Z-16 ~-/~ULTRASONIC IMAGER -- 5 " 9100.00- 9432.00 SCH 5 " 9675.00-10654.00 SCH 5 " 9600.00- 9854.00 SCH 5 " 0.00-11561.00 $CH 5 " 11050.00-11727.00 SCH 5 " 7700.00-11514.00 SCH 5 " 9390.00- 9812.00 SCH 5 " 03/04/92 91 7700.00-11542.00 SCH Information Control Well Records Adrian J. Martin RECEIVED MAR 2 4 1992 Alaska 0II & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/13/91 T# 83O05 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. PRODUCTION LOG 11/08/91 #2 9550.00- 9850.00 SCH Information Control Well Records Adrian J. Martin BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, A, laska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 07/12/91 T#:82626 FROM: Information Control Well Records LR2-1 SUBJECT: BP ~.ASED HOLE FINALS Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. A-15 A-18 F-12 F-24 J .,.~-F-42 f~-F-44 -O3 N-12 P-06 P-16 P-16 U-07 U-11 LEAK DET 06/22/91 #1 2158-10385 CAMCO GAS LIFT SURVY 06/30/91 #1 100-10000 CAMCO PROD-F 06/19/91 #1 9300-9590 CAMCO PROD-F 06/29/91 #1 11800-12165 CAMCO GAS LIFT SURVY 06/19/91 #1 10400-10600 CAMCO PROD-F 06/21/91 #1 9350-9792 CAMOC INJ 06/21/91 #1 10600-10964 CAMCO GAS LIFT SURVEY' 06/26/91 #1 0.0-9800 CAMCO P ROD-F 06/19/91 #1 9950-10381 CAMCO GR/LOG 06/26/91 #1 10000-10579 CAMCO COLLAR 06/22/91 #1 9994-10613 CAMCO TEMP/GAS LIFT SUR 06/27/91 #1 0.0-9741 CAMCO TEMP/GAS LIFT SUR 06/27/91 #1 0.0-10177 CAMCO 1 "/5" 2"/5" 5" 5" ! 2 ~/5 ~ 5" 2"/5" 2"/5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO. Box 196612 Anchorage, Alaska 99519-6612 (907) S61-5111 TO: DISTRIBUTION Date :10/19/90 T#:81751 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. ..~-24 Pmd-F 10/12/90 #2 9000-9585 Sch 5" r--"N- 12 Pmd-F 10/14/90 #1 9550-9721 Sch 5" ,....-N-15 Perf 10/14/90 #1 9650-10161 Sch 5" ....-S- 23 CBT 10/15/90 #1 2700-11550 Sch 5" ..... S-23 CET 10/15/90 #1 2700-11573 Sch 5" ......S<23 CNL 10/15/90 #1 7650-11528 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED OC. q 19~ ! ~mmission BP EXPLORATION July 14, 1989 BP Exploration (Alaska) Inc. ~, 900 East Benson Boulevard RO. Box 196612 ~ Anchorage, Alaska 99519-6612 ~ (907) 561-5111 ~, Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well N-12 (31-17-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. Yours very truly~, B. J. P°licky ~ Supervisor Waterflood/Miscible Flood BJP:JAM Enclosures (9) cc: L. Burke (MB12-1) Well File RECEIVED 1 8 ]989 Alaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ~ KA OIL AND GAS CONSERVATION COMMb,~ N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Alter casing Repair well Change approved program ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1144' NSL, 543' EWL, SEC. 08, T11N, R13E, UPM At top of productive interval 236' SNL, 2170' WEL, SEC. 17, T11N, R13E, UPM At effective depth 412' SNL, 1991' WEL, SEC. 17, T11N, R13E, UPM At total depth 430'SNL, 1973'WEL, SEC. 17, T11N, R13E, UPM 1.2. Present well condition summary Total depth: measured 10070 feet true vertical BKB 9270 feet Operation Shutdown ~ Plugging Pull tubing ~ Variance ~ 5. Type of Well: Development x Exploratory Stratigraphlc Service Re-enter suspended well Time extension Stimulate Perforate x Other 6. Datum elevation (DF or KB) KBE = 79.60 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number N-12 (31-17-11-13) PBU 9. Permit number 81-14 10. APl number 50- 029-20557 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 10010 feet Junk (measured) true vertical BKB 9216 feet Casing Length Size, Cemented Measured depth Structural -- True vertical depth BKB Conductor 110 20 x 30 8 c.y. 144 S u rf ace 264 7 13 3/8 3808 c.f. 2681 Intermediate 9209 9 5/8 1457 c.f. 9243 144 2681 8526 Production Liner 1316 7 360 c.f. 8744-10060 8090-9261 Perforation depth: measured 9678'. 9700', 9720'- 9750' true vertical subsea 8836'-8901' (two intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8692' with 4 1/2" tailpipe to 8803' Packers and SSSV (type and measured depth) 9 5/8" Baker SAD packer at 8692'; 5 1/2" SSSV at 2018' RECEIVED ! 819 9 Alaska Oil,& Gas Cons. C0mm/ssl0 : Anchorage 13. Attachments Description summary of proposal × Detailed operations program BOP sketch 14. Estimated date for commencing operation July/August 1989 16. If proposal was verbally approved Oil X Gas~ Name of approver Date approved Service 17. I hereby cert~ that the for~ijloinxg is tr~,l~ and correct to the best of my knowledge. ,~.~_.~.,/~~. Title Supervisor Waterflood/Miscible Flood Si~lned FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance ~ Mechanical Integrity Test~ Su-"---~equent form required 10- ~ ORIGINAL SIGNED BY Approved by order of the Commission LONNIF C. RMITH Form 10-403 Rev 06/15/88 15. Status of well classification as: Suspended __ Approved Copy Returned Commissioner Date '7 - I?'' ~'~ SUBMIT IN TRIPLICATE WELL N-12 (31-17-11-13~ ADD*L. PERFORATION PROPOSAL We propose to perforate the following additional interval during July/August 1989: 9760' - 9813' MD BKB (Ref. BHCS, 5/29/81) A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations, then tested. jm 7/12/89 BOWEN PACKOFF FLOW TUBES & PACKOFF HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE FLOWLINE VALVE GREASE LINE RISER GREASE / ~: MANIFOLD GREASE PUMP .,-'GREASE RESERVOIR BOP SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 May 9, 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 B-16,~Y-3, Y-5 and Y-6 PBU Wells Attention: Mr. C. V. Chatterton Gentlemen: Enclosed, in duplicate is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our subsequents to performing EDTA treatments on these wells. Yours very truly, J. A. Bragg District Petroleum Engineer (Acting) cc: A. E. Leske Well Records (LR2-1) Drilling Well File ~17 RECEIVED MAY 1 5 1985 Alaska 011 & Gas Cons. Commission Anchorage ALASKAO(L AND GAS CONSERVATION CC,',/i'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. .DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of operator 7. Permit No. Sohio Alaska Petrole-m Company 81~14 3. Address 8. APl Number P.O. Box 6612, Anchorage, rAlaska 99502 50-029-20557 4. Location of Well 9. Unit or Lease Name Prudhoe Bay Unit At Surface: 10. Well Number 4136' SNL, 543' EWL, Sec. 08, TllN, R13E, UPM N-12(31-17-11-13) PBU , 11. Fieldand Pool Prudhoe Bay, 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 79.60' AMSLI ADL 28282 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). The following intervals in this well were treated with 75 barrels EDTA solution on January 3, 1985 and April 13, 1985. The treatments were condQcted through coiled' tubing as single stage jobs and the well was shut in for 24 hours after the treatments. The SSSV was removed prior to stimulation and reset after the job at 2018' ' 9678' - 9700' BKB (Ref. BHCS/GR 5/29/8,1.) 9720' - 9750'-BKB (, " ) RECEIVED MAY 1 5 1:985 Alaska 0il & Gas Cons. Commission Anchorage _ lZ~ I hereby certify that the foregoing is true~34~d, correct to the best of my knowledge. Title Petroleum Engineer Date ~'--"--'/'~:~ --~'~f... '~,~e space below for Commission se Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission. Date __ _ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Tri[ and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 December 20, 1984 Alaska Oil & Gas Conservation Co~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton WellS~;i~ and N-13 PBU Gentle~: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perform EDTA matrix treatments on these wells. Enclosures A, E. Leske Well File 917 Yours very truly, James A. Bragg District Petroleum Engineer' (Acting) RECEIVED ~laska O# & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA(ii .- AND GAS CONSERVATION C(~i~,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~D OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address P.O. Box 6612, Anchoraqe, Alaska 9)502 4. Location of Well At Surface: 4136' SNL, 543' EWL, Sec. 08, TllN, R13E, UPM 5. Elevation in feet (indicate KB DF' etc.) KBE = 79.60" ~L I 6. Lease Designation and Serial No. ADL 28282 12. 7. Permit No. 81-14 8. APl Number 50- 029-20557 9. Unit or Lease Name Prudhoe Ba~v Un~ ~-_ 10. Well Number N-J2 (3]-17-1 ]-] _q) 1 1, Field and Pool P~-~zd~oe :Ba7 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 [] 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 pertiner~t details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals in this well will be treated with a 75-bbl (60 gal/ft) EDTA solution in December 1984. The trea~t will be condUcted using a coiled tubing Unit. The SSSV will be removed prior to the treatment and reset after the job at 2018'. 9678'-9700' BKB (Ref. BHCS/GR, 5/29/81) 9720'-9750' BKB ( " ) RECEIVED Alaska Oil & Gas Cons AnChorage' Commis~ioA 14. I hereby certify that the foregoingj.%.true and correct to the best of my knowledge. The space below for Commission use Date / ,~/-~,/~,~ Conditions of APproval, if any: GRIG..~.,~L SIGN[II 61' [D~ll~lE C. SMII~' Approved by '"' COMMISSIONER Retu/rr~e~l the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON 31 11 "C" STREET ANCHORAGE. ALASKA TELEPHONE {907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO: SFO/UNIT/STATE: (-Mara tho n) GET%Y MOBIL PHILLIPS ,? STATE OF AK BPAE (Transmittal Only) CENTRAL FILES(CC#' s-Transmittal Only)_ Date: 10/6/82 Trans. #: 2703 CC#: 55703 REFERENCE: ~//~HIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-12 / A-14--' A-15j A-18-- G-12--~ G-13 -' M-15 --~ N_12~' N-12 -- N-14 N-14 N-15 R_7-~ DDNLL 7/27/82 #1 Dres 8800-9714 5" DDNLL 8/10/82 #1 Dres 9300-10135 5" Spinner 8/27/82 #1 GO 10600-11000 5" Spinner 8/29/82 #1 GO 9900-10250 5" DDNLL 7/20/82 #1 Dres 9750-10686 5" DIINLL 7/23/82 .#1 DRes 8600-9418 5" TDT-M 8/15/82 #1 Sch 8750-9596 5" DEk'~,T, 7/30/82 #1 Dres 9200-9997 5" Spinner 8/18/82 #1 GO 9550-9800 5" Spinner 8/16/82 #1 GO 9459-9800 5" DDNLL 8/3/82 #1 Dres 9250-10146 5" TDT-M 8/14/82 ' #1 Sch 9300-10329 5" TDT-M 8/12/82 #1 Sch 9450-10426 5" TDT-M 8/13/82 #1 Sch 10850-11455 5" ,/82) RECEIVEO OATE ......................... 19 Victoria Aldridge Development Geology Well Records TP1-5 SOHIO ALASKA PEIROLEUM COMPANY SF0 ARCO - CHEVRON 311 1 "C" SIAEET ANCHORAGE. ALASKA TELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 EXXON GETTY SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) . CENTRAL FILES (CC#'s - Transmittal Only) Date: .9-24-82 Trans.#: 2670 CC#: 55670. REFERENCE: .,. ~FINAL DATA - PRESSURE SURVEY DATA. The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-15~' GO Pressure Survey and BHPD 8/27/82 N-15-~ Otis Pressure Survey and BHPD 8/28/82 A-19 Sch. Pressure Survey and BHPD 8/29/82 A-18 ~ GO Pressure Survey and BHPD 8/29/82 G-19 .... Camco Pressure Survey 8/27/82 E-15~ GO Pressure Survey and BHPD 9/3/82 E-10 GO Pressure Survey 9/14/82 E-1 .... GO Pressure Survey 9/14/82 E-20~' GO Pressure Survey 9/7/82 N-14 ~' GO Pressure Survey and BHPD 8/16/82 R-7 ~ Otis Pressure Survey and BHPD 8/19/82 N-12 '~ GO Pressure Survey and BHPD 8/18/82 X-7 '" Otis Pressure Survey and BHPD 8/9/82 M-16~ Camco Pressure Survey and BHPD 9/10-12/82 R.8~ Otis Pressure Survey and BHPD 9/13/82 E~ll-'~ Otis Pressure Survey 9/1/82 E-11~ Otis Pressure Survey and BHPD 9/11/,82 82) RECEIVED DATE Al~sk,~ 0ii & G~s Cons. Commission A.nchora§e Karen Mestas Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET .-~ ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 July 26, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive . Anchorage, Alaska 99501 Attent ion: Mr. C. V. Chatterton Gentlemen: Wells ~~ N-13 and N-14 PBU Enclosed, in duplicate, are the following forms for the above-named wells. 1. Form 10-407, Compl et ion Report; 2. Form 10-403, Sundry Notice and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. GJP: JLH: pj s EnclOsures cc: J. D. Hartz Geology Well File ~17 -...~/ J. _Plisga istrict .n ineer E £ E ,! V E O Oil & Gas Cons. Co'nmission Anchorage ' ' ...... ' ( STATE OF ALASKA n I r, I , · ALASKA ~,,~ AND GAS CONSERVATION CO~,.4/IlSSION" ' -- WELL COItIII LI=TIO# O1=1 I E;COIIIII LE;TIO# I EI OI T I.O ' 1. Status of Well Classification of Service Well ,. . OIL3~-I GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petz:oleum Company 81-14 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20557 4. Location of well at surface 9. Unit 6r Lease Name 4136' SNL, 543' EWL, Sec. 08, TllN, R13E, UPM Prudhoe Bay Unit At Top Producing Interval' 10. Well Number 1~1' S.NL, 2214' WEL, Sec. 17, TllN, R13E, OPM N-12 (31-17-11-13) At Total Depth 11. Field and Pool 430' SNL, 1973' WEL, Sec, 17, TllN, R13E, UPM Prudhoe Bay .5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 79.60' AMSLI ADL 28283 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 5/13/81 5/29/81. 6/2/81I feet MS LI one 17. Total Depth (MS+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalS~rvey I 20. Depth where SSSV set ] 21. Thickness of Permafros't · '10070'MD 9270'TVE10010'MD 9216'TVD YES~ NO[] 2017 feetMD 2045' 22. Type Electric or Other Logs Run DIL/GR/SP/BHCS, FDC/CNL/Cal, HUT, CBL/VDL/GR/CCL, g~.roscopic survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ' . 20"x30" Insulated Conductor3urface 110' 36- 8 cu.¥ds, concrete . ~.13. 3/8" 72# L-80 Surface 2681' 17 1/2'." 3808 cu.ft. Permafrost II 9 5/8" 47# 'Soo-95 ·surface. ~. 9243,, 12 ~1/4" . t327,.Cu..ft. Class G . 130 cu. ft. Permafrost C 7" 29# L-80' 8744' 10060' 8 1/2" 360 cu.ft. Class G ' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD . interval, size and number) i.~MD ..... TVDss SIZE, DEPTH SET (MD) pACKER SET (MD) Prudhoe Oil~.,.Po°l top 9678 ' 8836' 5 1/2" 8803 ' 8692 ' Bottom 9750 ' 8901.' ... 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9678.. '. - 9700 ' .BKB, (',8,836· ' .-' 8856,!.. ,TVDs,s),. . "DEI~TH INTERVAL. (MD) AMOUNT & KIND OF MATERIAL USED 9720., - 9750' BKB (1.8874' _ 8901' TVDss) · ; ' . ," ...~ , , ,.. ' ,>.'..,..' ~ ' ~., . ..~.,, ..,. -;-:, .: · , . ., ~ ,. . - ,. " .. ' ' , . - ." ' '-.'~ ~ ,~ '.i:,.': ... ' ~ : 27. PRODUCTION TEST Date~Firs.t Production · . I, Method .,o.f Operation (Flowing, gas lift~,etc.) · I ' : ' ";" :" ' "' ';'-' "" ' ;: July 1, 1982 I lOW± , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE' IGAS-OILRATIO I ,. ...... ,. ~. . ~ TEST ,PERIOD · .,, ;, ; ;~ · · ,' .. · :¢ · , ,, . Pressure CALCULATED_i~ OIL-BBL . GAS-MCF WATER'BBL. OIL GRAVITY-APl (corr) "' Fiow Tubing Casing AT'i:=Fc " ' '~' ' "' ":' ' ' ': 24-HO u ri R 28. CO R E DATA '-Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' 'I ECEIVED ~ ' ~ . . ~ . ' ~ k~ ~' r~ . , .' ~' ~,' '~' ~ · .jUL291982 '. , Alaska 0il & Gas' ..... ' . '" .'" -' , .'" .. -,.',', '.~' . , . Con...__Comr~.slo-. ': ,. · Anchora.~e _ Form 10-407 Submit i n duplicate Rev.~7-1-80 CONTINUED ON REVERSE SIDE 29. , 30. GEOLOGIC MARKERS " FORMATION TESTS · , NAME Include interval tested, pressure data, all fluids recovered and gravity), MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST. 9282' 8480' Shublik 9321 ' 8514 ' Ivishak 9416 ' 8599 ' 31. LIST OF ATTACHMENTS ..... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ./)Signed '~. Title District Field Date ' ~L, G/~. Plisqa ,~/,~ .... En~inle'er __ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and tog 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), §o 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 supplementai.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". I:nrm I STATE OF ALASKA[ ALASKA ,L AND GAS CONSERVATION CO,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL i-fi: OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612: Anchorage, Alaska 99502 4. Location of Well 4186' SNL, 543'EWL, Sec. 08, TllN, R13E,UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 79.60' AMSL I 6. Lease Designation and Serial No. ADL 28283 7. Permit No. 81-14 8. APl Number 50~29-20557 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number N-12 (31-17-11-13) 11. FieldandPool Prudhoe Bay Prudhoe 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). The foll°~ing intervals were perforated July 1, 1982 using Dresser Atlas 3 1/8" carrier 'guns at 4 spf. A lubricatdr' was installed and tes%ed to 4000 psi on all well work. 9678' - 9700' BKB (Ref. BHCS/GR,. 5/29/81) 9720' - 9750' BKB C " ) An -SSSV was' set and tested in the BVN at 2018'. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~.~,~ ./Z~,~,/, Title District Field Engineer The spac/~//~f~r Corem ission use U0 ConditiC~ns/of Approval, if any: V J U L 2 9 ]982 Alaska 0il & Gas Cons. Commission tmch0rag0 Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ' ' ......... ' STATE OF ALASKA ALASKA (~"_ AND GAS CONSERVATION C(~" .vllSSlON' MONTHLY REPORT OF DRILLING AND WORKOVER OPERATI 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 81-14 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20557 4. Location of Well at surface 4136' SNL, 543' EWL, Sec. 08, TllN, R13E, UPM 5. Elevationinfeet(indicateKB, DF, etc.) KBE = 79.60' AMSL 6. Lease Designation and Serial No. ADL 28283 For the Month of. July ,19 82 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. N-12 (31-17-11-13) 11. Field and Pool prUdhoe Bay Prudhoe Oil Pool "12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run 6. DST data, perforating data, shows of H2S, miscellaneous data See Attachment 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SIGNED TiTLE District Field Engineer DATE NOTE--R/irt on this form is requir~¢c~/each calendar month, regardless of the status of operations, and must be/filed i~ duplicate with the Alaska Oil and ~i'a~/Conservation Commission 5y the 15th of the succeeding month, unless otherwise directed. Form 1~4 Submit in duplicate Rev. 7-1-80 PERFORATING DATA - Well N-12 June 25, 1982 July 1,. 1982 July 1 ,1982 Ju!y~/ll, 1982 Ju~yl 13,1 1982 July 15, 1982 Pressure tested tubing and inner annulus Rigged up Dresser Atlas and perforated the following intervals using 3 1/8" carrier guns at 4 spf: 9678' - 9700' BKB (Ref. BHCS/GR, 5/29/81) 9720' - 9750' BKB ( " ) Put well on production Shut well in to prepare for static pressure survey. Ran static pressure/temperature survey at 8800' TVDss. Set and tested SSSV in ball valve nipple at 2018'. Well on production J U L 2 9 Oil & Gas Cons. Co~r]m~ssior~ SOHIO ALASKA PETROLEUM COMPANY SF0 3111 "C" STREET ANCHORAGE. ALASKA ARCO CHEVRON EXXON TELEPHONE (9071 265-0000 MALL: POUCH 6-612 ANCHORAGE, ALASKA 99502 To:SFO/UNIT/STATE: GETTY (-Marathon) MOBIL '- PHILLIPS BPAE (Transmittal Only) CENTRAL FILES (CC(/'s -Transmittal Only) REFERENCE: SOHIO FINAL DATA- PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this .letter and returning it to this office:-- ~O &, .-/4,'.- ~..~ 7-/,~ - ~ 2__ 7.-/0 - 8' 7-×0- 7- /~ - g;l- - 7 --/o 82) SOHIO ALASKA PETROLEUM COMPANY 3111 'C STREEt' ANCHORAGE. ALASKA TELEPHONE (907) 276-5111 MAIL POUCH 6-612 ANCHORAGE. ALASKA 99502 January 14, 1982 Alaska Oil & Gas Conservation Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: Wells A-10, H-15, M-9, M-11,'?N~I2~ R-7, Y-11 Enclosed,-in triplicate, are Forms 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These reports contain our proposals to perfo~e the wells. District Field Engineer GJP: JLH: ja Enclosures cc: Well File #17 F.E. File J. D. Hartz Geology STATE OF ALASKA ALASKA OIL AND.GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS' ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company' 81-14 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 s0-029-20557 4. Location of Well At surface: 4136' SNL, 543' EWL,.Sec. 08, TllN, R13E, UI~ 5. Elevation in feet (indicate KB, DF, etc.) KBE = 79.60AMSL 12. 6. Lease Designation and Serial No. ADL 28283 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number N-12 (31-17-11-1'3) 11. Field and. Pool Prudhoe Bay 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 [] Alter Casing [] , Perforations [] Altering Casing E] Stimulate [] Abandon L-] 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 e~ch 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). The following intervals will be perforated during February/March 1982, using Dresser Atlas 3 1/8" carrier guns at 4 spf: 9678' - 9700 ' BKB (Ref. BHCS/GR, 5/29/81) 9720' - 9750' BKB ( " ) A SSSV will be set and tested in the 'ball valve nipple ca. 2000'. Subseque=t Wo~l~ here rtif e forego ~ is true and correct to the best of mg knowledge.. The~;e below f{C~mmission use ~ J. Plisga Title District Field mqineer RECEIYEI) .. JAN 1 q 1982 Alaska 011 & Gas Cons. C0mmissi0~ Anchorage Conditions of Approval, if any: Approved Copy, Date Approved by ORJG':N,~[ SIGNED BY [ONNIE IL SMIT~ Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "SubseQuent Reports, in Duplicate SOHIO ALASKA PETROLEUM COMPANY July 2, 1981 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well N-12 (31-17-11-13) Enclosed, in duplicate, is Form 10-407, Completion Report, for the above-named well together with the Well History, Well Logs, and Directional Surveys. This well has been suspended pending perforating operations. RHR:ja Enclosures cc: Well File #17 Geology Yours very truly, R.H. Reiley District Drilling Engineer ' ,~ STATE OF ALASKA ~ .... ALASKA~ .AND GAS CONSERVATION C ,.,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL J~ GAS [] SUSPENDED [] ·ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum C~y 81-14 3. Address 8. APl Number R)uch 6-612, Anchorage, Alaska 99502 50-029-20557 4. Location of well at surface 9. Unit or Lease Name 4136' SNL, 543' EWL, Sec. 08, TllN, R13E, UPM Prudhoe Bay Unit At Top Producing Interval top Sag R. SST. 10. Well Number 191' SNL, 2214' WEL, Sec. 17, TllN, R13E, UPM N-12 (31-17-11-13) At Total Depth 11. Field and Pool 430' SNL, 1973' WEL, Sec. 17, TllN, R13E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 79.60 ' AMSLI ADL 28283 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. ,15. Water Depth, ifoffshore 116. No. of Completi0ns 5/13/81 5/29/81 6/2/81I Ifeet USE one : 17. Total Depth (M D+TVD)10070 'MD 9270 '~Vl) 18. Plug Back Depth (MD+TVD)10010 'MD 9216 'TVD YES19' Directional Survey[] NO [] i20' Depth where sSSV 2et2017 feet MD I21' Thickness Of PermafrOst2045 ' 22. Type Electric or Other Logs Run DIL/GR/SP/BHCS, FDC/CNL/Cal, HDT, CBL/VDL/GR/CCL, qyroscopic survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20"x:q0''' [nsulatedConductoz Surface 1]0' 36" 8 cu.vds, con~r~_te I q q/R" 72~ T~R~ Surfac~_ 268]' 17 1/2" 3808 cu. ft. Permafro. Bt II , '9 5?8- 47~ S~.95 surface . 9243', 12.1~4" 1327 cu, ft. Class G . 130 cu. ft. Permafrost C 7" 29# L-80 8744' 10060' 8 1/2" 360 cu. ft. Class G 24. Perforations open. to Production (MD+TVD of Top and Bottom and 25 .... TUBING RECORD i,n~terval, size and..number) . . SIZE DEPTH SET (MD) PACKER SET (MD) 5 1/2" 8803' 8692 ' None " · ~ , ~.'. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ , . . DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ' · · . · 27. PRODUCTION TEST Date F rst,. Production..... . ' ~ r~' Method. of Operatien (Flowing,. gas lift, etc.). I · . : Date of Test Hours Tested PRODUCTION FOR Gl L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO ~. .... . . .. :. ~. . TEST PERIOD.. JJ~ . · ., ..... : Flow;Tubing: Casi, ngPr, essure CALCULATED__. OIL-BBL : GAS:MCF .WATER-BBL' QIL.GRAVITY-API (corr) ' Press..: ,. .. ',.. , 24~-HOUR RATE"F ... . ; . ... . 28. CORE DATA "Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ': -' . None · :... ~ . · · ( : ' ' JUL 0 ? 1981 , ., ,.. . .~. '. .. .... ' . .' . , AlaskaOii&,, .,,.._Gas Co~s. Comrrliss, ' I,mu.ora.~e' . - Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' ' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST. 9282' 8480 ' Shublik 9321' 8514' Ivishak 9416 ' 8599 ' .. 31. LIST OF ATTACHMENTS .... ~11 History, Well Logs,Directional Survey .... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ Title District nri]]i_lqgDate /~. H. Reiley ~% Enqineer 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 comple, tion), 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 thee 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". Ferrn 1 O-4¢)7 Well N-12 (31-17-11-13) HISTORY Spudded well at 2130 hours, May 13, 1981. Drilled 17 1/2" hole to 2700'. Ran 68 jts. 13 3/8" 729 L-80 Buttress casing to 2681'. Cemented with 3720 cu. ft. Permafrost II cement followed by top job with 88 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2638'. Tested casing to 3000 psi, okay. Drilled out to 2760', ran leak-off test to 0.72 psi/ft, gradient. Directionally drilled 12 1/4" hole; twisted off drillpipe while drilling at 4649'. Recovered fish. Continued directionally drilling at 9250'. Ran open hole logs. Ran 237 jts. 9 5/8" 479 Soo-95 Buttress casing to 9243'. Cemented in two stages: First stage with 1327 cu. ft. Class G cement; second stage through D.V. packer at 2592' with 130 cu. ft. Permafrost C cement preceded by Arctic Pack. Drilled out D.V. plugs, RIH to 8000' and tested casing to 3000 psi, okay.. Directionally drilled 8 1/2" hole to 10070'. Ran open hole logs. Ran 33 jts. 7" 299 L-80 Buttress liner to 10060'. Cemented with 360 cu. ft. Class G cement. Cleaned out to 10010' tested liner and liner lap to 3000 psi, okay , · Changed well over to NaC1. Ran CBL. Ran 212 jts. 5 1/2" 179 L-80 IJ4S tubing to 8803'. Landed tubing with ball valve at 2017'. Installed and tested tree. Displaced tubing to diesel, set packer at 8692'. Tested tubing to 3500 psi, okay. Released rig at 1800 hours, June 2, 1981. JUL 0 ? 1981 Alaska Oil & Gas Cons. Commission Anchorage SOHIO ALASKA PETROLEUM CO. PAD .N (31 · 17. II. 13 ) N'I2 Controlled Drilling Consultants LES HENDERSON 349-3114 CONTROLLED DRILLING CONSULTANTS 7608 Highlander Drive Anchorage, Alaska 99502 (907) 349-3114 Mr. Brian Rose Sohio Alaska Petrole~ Cc~y Pouch 6-612 Anchorage, AK 99502 June 4, 1981 Magnetic Single Shot Survey Job No. A0581-029 Well N-12 (31-17-11-13) Prudhoe Bay Field North Slope, Alaska Date of Survey: 5/15/81 to 5/29/81 Dear Mr. Rose: Please find enclosed the "Original" and six (6) copies of our Magnetic Single Shot Survey on the above well. Radius of Curvature was the method in calculating this survey. The depth interval of the survey was 2680 to 10,070. Thank you for givin~ us this opportunity to be of service. Yours very truly, Controlled Drilling Consultants Cecil W. Harrington Directional Supervisor CO~PLE~,~N REPORT SOHIO A~.,SKA PETROLEUM ,::-~A6~E~C $iNGL~ SHOt RADIU~ OF CURVATURE M~THOD OF COMPUTATION COHPUTED FOR CDC BY FM LINDSEY & ASSOC. ~ JUHE 81 ~ELL N-12(~1-17-11-13! ~'--B-~O RECORD OF SURVEY TRUE NEAS' DRIFT VERTICAL. SUB · DRIFT OEP'TH'ANGLE .... DEPTH SEA O IREC D H DEG, TOTAL COORDI~ATE$ CLOSURES DISTANCE ANGLE D ~ DOG LEG DEG/IOOFT SECTION 0 '0 .... 0 O*Ob-----~Yg,60 ASSUMED VERTICAL TO 2680. 0,00 S 0.00 ~ . : 0'00 $ 0 0 0 W 0,000 0.00 2680' 0 0 2680,00 2600,¢0 N O,OOE . 2728 1 15 2727.99 26q8.39 $81.OOW ......... 282I .... 2 0 '2820~9~-~ 6~E 2911 1 ~0:2910,91 · ':~*: ?~OO& :4 0 !i~003"80::: ~187 9 15 ~185,~4 3105.94 $74.00E 0.00 0.29 6.81 'S 9* 96""S 3,6.1. 0 0 0 ~ ~9 29 S9 W 0.000 2.606. 0.00 48 30 9 H 10 21 35 ~ .6 '3~' '~4 "E .... ,58 ~6 56 E 0.814 0.~56 2,691 3.023 -0.85 1.23 13.96 26,21 3309 12' 45 3~05,28 3225.68 STT.00E 19.~3 S 44.99 E 49.01 :~400':= 14: -:' 0:':::: ']39:~*:8'1'::'~"331~:,,21~*:57I'-00E ........ 25d2:3 5 ...... 6'5~1'-E ...........69~3-' 3525 ::: 36*84 $ 97,09 103.8~ ~6~7 20 ~5':~::~:~629'~5 :: .: ..; ~2'4~ S '1~3.87 E :: .143.78 3768"23"~- 37~'e32 - 3661,72"":""$69~.'00E ........ 70*35 5 - ~76e0~ E 3891 26 45 3852,~6 3772,96 569.00E 89.15 S 225.01 E 2~2,03 S 66 37 57 E S 69 1~ 16 $68 36 15 E $"68 12' 59' S 68 23 11 E 2.871 2,804 2.696 2.439 48.87 69.48 14 92 1'68~57 2~0.68 4333 30 .... 4az6 29 5287 28 · 5648 30 6430 32 0 4241,40 4161.80 $68.00E 166.12 S 420.42 E 452.0~ S 68 26 21E ;~:S4S.67 $ 848.86 E ' 9~6,54 S 67 50 SS E ::~ ;:.416"8~..:$ ..... :..:.Z:OO8'?~ £ !::ii!'.109~'~7 $ 67 SZ `50 E 30 5651.90 ~72~0 $64'0~E 4~.i9 $ ~X~2.00 E 1250.00 S 67 9 37 E 15 6053,91 5974.31 S64.00E 596.92 S 1381.08 E 1504.56 $ 66 37 31E 6900 30 4S 6454.64 6375.04 ' $66.00E 700.69 $ 1603.63 E 1750.03 $ (~6 23 50 E 737~' 27::'15 '-'686'Te'~O'";~16787~8'O~/~6;6'~OOE' .... :-:'7~~:: S::-'~8X2*64 E':':~.1978e8~'S-"66 21 ' 5'-E ' ' 0.7:~7 0'160 0.271 0.822 0,053 0.538 4,49.49 . 692.19 912.31 1086,95 124~.56 1~00.33 17~+`5.62 197~.9`5 ....... SOH'IO-'WELL. N-12 $ ~JNGL..E' SHOT .SURVEY RECORD OF *%URVEY TRUE ,-~irT-'VERTTCA-lj------SUB DEPTH ANGLE DEPTH SEA D M DIREC DEGe DISTANCE ANGLE D M $ DOG_I. EG ............ SEVER[ TY SECTION DEG/IOOFT DISTANCE 7837 28 0 ?2?9.39 7199,79 564.00E 884'87 S 2008,04 8245 28 30 7638,79 7559,19 S59,00E 976,98 5 2177,70 9i82 29 45 8~58.79 8379.19 *%50.00E 1228.68 S 2554,12 10010 25 30 9192.23 9112.6~ S47.00E 1482.99 S 2841.57 . . 2609,8! .%65 12 Z6 E 2834.29 5 64 18 34 E 3205,28 S 62 26 24 E 0.07~ 2606.53 0.'b72 28~2,.60 0.5!8 ' :~Z05,27 THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD BOTTOM HOLE CLOSURE 3230.18 FEET AT S 62 19 5 E 3230'18 $ 62 19 5 E 0,000 ':'.' SOHI. O WEL. I. N-12 SINGt. E SHOT SURVEY ' z dUNE 81 ~ MEASURED .DEPTH AND "OTHER DATA FOR EVERY EvEN 100 FEET OF SUB .SEA DEPTH,, MEASURED DEPTH TRUE VERTICAL SUB MD'TVO · VERTICAL DEPTH SEA DIFFERENCE CORRECTION' TOTAL ' COORDINATES 180 280 ~,80 580 180. 100 0 0 280* 200 0 0 480. 400 0 O 580. 500 0 0 O,00.$ O,00 W 0,00 $ O,00 W 0,00 $ 0,00 W 0.00 $ .O*O0 W 0.00 5 0,00 W 680 7;80 880 1080 1180 1280 1380 1480 1580 1680 1780 18'80 1980 2080 2180 2280 2380 21~8"0 2580 2680 2780 2880 2980 680, 600 780. 700 8BO. 800 1080, 1000 1180. 1100 i280. 1-200-- 1380. 1300 1480, 1400 IS~----1-~O 1680. 1600 1780. 1700 i-B8Uo .......... i~00 1980. 1900 2080e 2000 218~; .... 2T~O 2280, 2200 2380, 2300 2580. 2500 26~0. 2600 27EO* ........ 2~0 2880. 2800 2980* 2900 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.00 $ 0,00 W 0,00 S 0.00 W 0,00 $ 0,00 W 0,00 $ 0,00 W 0,00 $ 0,00 W 0,00 $ 0,00 W 0 0 0 0 0.00 $ 0,00 W 0.00 S 0,00 W 0.00 $ 0.00 W 0'00 $ 0,00 N 0,00 S 0,00 W 0.00 5 0,O0 ~ 0'0'0'"$ 0".'0~ w 0.00 S 0.00 W 0.00 S 0,00 W 0 0 0 O 0 0 0 0 0 0,00 $ .. 0,00 W 0,00 $ 0.00 W 0.00 S 0,00 W 0,-00-'$ 0,00 W 0,00 S 0,00 W 0.00 $ 0,00 W 0,3'9 $ l,~i W 3,38 S 1,25 W 3080 3080. 3000 9e38 .S 8,89 E 3181 3283 3489 3180. 3100 3280. 3200 3380. ..... 3300 3~80. 3400 1 3 9 13.34 S 21,5~ E 18,12 5 39,51 E 2~', 10" $ 61,80 E 33,13 5 87.,Z5 E ,t.s~_~K ~. 11"/.,2~1 Il' SC)I'Ll 0 WE~J..,,N- 12 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB .SEA DEPTH., 2 dUNE 81 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL. DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL. COORDINATES 3701 3810 3921 4034 /+147 3680. 3600 3780. 3700 21 ? 30 9 41 67 13 3980. 3900 40,~0, 4000 60,50 S 76,53 S 151,87 E 192.15 E 94.01 112.80 132.42 $ 237,66 · ,% 286,10 336.06 4262 4377 4~92 4.180. 4i'00 /+28.0. 4200 4380. /+300 8'2 97 15 112 15 152.99 174.39 196.07 3ST,T6 E 440.83 E 493.95 E 4.722 4837 5066 5179 5406 5636 5752 5869 '598'7 6105 6224 6342 6460 6578 6696 6813 6929 7'0~ 5 7159 727~ ~86 498 7611 4480. 4400 4580. 4S00 142 · 4680. 4600 471Jl)' ~ 470-0----i-71 4880, 4800 186 4980, 4900 199 ~180, 5100: 226 5280, 5200 24! 5480. 5400 271 5580. 5500 289 56~ ...... 5600' .......... ' ~780, ~700 5880, 5800~ 6080e 6000 6180e 6100 S98 '~ 6380, 6300 ~:~; ~; 6~80. 6~00 449 6580. 6~0 465 6680. 6600 ~79 6780. 6TO0 493 : 6940. 6900 7o00 15 14 1~) 217,73 239.56 261.49 283.20' 304.65 368,09 ~90e67 5 546,39 E $ 598,64 E .`% 650.S3 E $ 701.70 E 5 752.21 E 5 802.08 E 851.31 900,84. 15 18 19 18 18 17 14 I3 414.25 5 1003.13 E 439.25 .`% 1056.40 E 465.47 5 1111.29 E 492~2"S" 1-1-~-7.85 E 520,71 5, 12;'-4.84 E 548,60 $ 1282,02 E 57&,32"S ...... ~338.85 E 603e91 S 1395eq6 E 6~0e98 $ ~&~e89 E 6~8 $ 1~07.5T E 68~ $ ~562e66 E 706e70 S 1617,1} E 7~0.29 S lb70.11 E 751.0~ 5 1721.29 i 775.0B $ 1770.70 E 79'$,*~-818'-38 E 817.b~ 5 186~.42 i 8~9.4~ $ 1912.86 E :SOHIO. SHOT SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE MEASURED VERT I CAL- SUB MD~,TgD VERT I CAL, DEPTH DEPTH SEA DIFFERENCE CORRECT[ON* TOTAL, COORDZNATE$ 7724 7180. 7100 7837 7280. 7200 ?;50 7~0,, 7~300 806~, 7~,80. 7400 8178 7580. 7500 ~2~ 7'~o. v6oo 8405 77B0. 7700 8519 7B80. 7800 ~ 8633 7980, 7900 8747 8080, BO00 8862 8180, 8100 ........... 8~7'~~8z~o.--8~oo 909Z 8380, 8300 9206 8480e 8400 557 13 86~,,89 S 884,87 $ 1960,~0 E 2008,04 E 611 13 625 ' 639 14 960,67 S": 2150,07 .E .......... 2196,51. E 22~3,11 E 2289,6_8 E 988-31 1016, 55 1045,05 667 14, 681 696 15 711 726 :1073,80 S 2336,22 E n 1133,62 S 2429,09 E 1236,, 24,74,35 E 2563 ,ZO E 9435 9548 9773 9885 9996 8580, 8500 ' 941 8680. 8600 755 8780. 8700 768 s98o. e9oo 793 90808 9000 805 91~0.- '9t00 1272.66 $ 2606,07 E 14 12 1308,45 $ 2647,67 13&3,67 S 2688,02 1412,42 S 2765.00 1445,93 S 2801,68 1478,87 S '28~7,X~ SOHIO WELL SINGLE SHOT SURVEY TRUE MEASURED VER T I CAL SUB JUNE DEPTH DEPTH SEA 1'000 1~'00, 920, 2000 2000- 1920. 3000 2999. 2920. 400~ 9949. 5000 4822, 6000 5690. 5611. ?~00 65'~'0, 64,61 TOTAL COORDINATE$ 0,00 0,00 6-68 0.00 W 0.00 W 2.50 E 107.07 S 292 .:~5 496,02 271.41 E 117~+.20 E 721.26 S 16~+9.83 E 8000 ~, 742~. 7343. 9000 8300, 8220. 10000 918~. 9105, 919.72 $ 2076.k5 E 1172.92 S 2483.78 E 1480.05 S 2838,42 E Sl er -sun June 8, 1981 A. O. Etchelecu Mr. Gary Plisga Sohio AlAska Petroleum Company 3111C. Street Anchorage, Alaska 99503 Re: Our Boss Gyroscopic Survey Job No. Boss-16820 Well No. N-12 (SEC8 TllN Ri3E) Prudhoe Bay Field North Slope, Alaska Survey Date: June 6, 1981 Operator: . Tom McGuire Dear Mr. Plisga: Please find enclosed the "Original" and seventeen (17) copies of our Boss Gyroscdpic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, KA/pr Enclosures SPERRY-SUN, INC. Kirk Afflerbach Supervisor COtItRD RF. CF. IVED JUL 0 ? ]~8~ Oil & Gas Cons. A,'lchorage · S P E-R"R'~'-SO'N W ELL;<~ SUR. VEY ING~' :]i:i :. ANCHORAGE'm ALA~ SOHIO ALASKA PETROLEUM C~OMPAN¥ ~i .; .]i~·]:~:]];i~ PRUDHOE BAY dUNE 8e 1981 ALASKA · :" ?" INTERPO ' PAGE 5 i E OF SURVEY dUNE &,~ 198Z ......... '-_~ dOB NUMBER BOSS'16820 .,KELLY BUSHING ELEV. = '/9.60 FT. OPERATOR'TOM MCGUIRE.i~ TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RE CTANGCLAR COORDINATES' MD-TVD VERTICAL DEPTH . . DEPTH::;;; ~.' o .o.oo ......... 1000 1000o00 920.~0 1.97 S 1-50 W .00 -00 2000 1999.99 1920.39 2.q'9 S 2.q9 W .01 r~3000 2999,81 2920.21 9.36. S 1,09 E .19 o18 ~ . GO00 5694~'7 ~::::~ 4~'7 27 ....... : L: · ~ ..... · · - - --. -.....~.. ~ ~.. :-:. :: :-:.'::.'::.':.. ~~~.~<:,:..~c:.:::.:.::c.:-.:::c:.:: :.:~.; ,, ~.~ .: .. :..:.: ,:....: ... .... :,~, ,~j~. ~ ........ ,: :: ...... ..:..~= ..... .. 7000 6546.16 6qGG.5q 773,70 S 161~.54 E 453,8G 148.60 8000 74~4.65 7355.05 978.55 S 2024.G3 E 565,35 lll 9600__ 8315,3G 8233,76 124q.32 S '2fl20.31 E 68G,6~ 121.29 N- 1~ S£-C'8-e-Ti-J~'~R'I-'3~~ PRUDHOE BAY dUNE Be 1981 ALASKA ,JOB NUMBER BOSS-16820 KELLY BUSHING ELEV, : 79.60 FT, TRUE SUB-SEA· TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ~--~PTH: , · .: ;. 'D'EPT[ : '.'::::.:.D :¢0RRF-c[ :: :: :': ' : : : .:':::':%2:::: ~:'<':: .':: ::2:::::<: :::':': .:>..:':: /:" )::.:>~: :.::: :: ~ :: :: o o.oo :' ::o?o. :: :... ',' ?'9' '~-,'6'o o-;-o-0~~~-s':,-' ......... ?' :": .~'~.".:~>:'~:::"~::::?~¥~:':-'" ::::~:~"::~-~'~:o~-': :::':'":'- ~o o'" ....... ;': ' 179 179.60 100.00 ,57 S ,27 W ,.~.0 279 279.60 200.00 .90 S .~1 W ,0~ 3 79 ~79,60 ~-0~~'~.'.~; ,:'.:.::'~:: ~..~;l~i--S: ;: :~; ' *~ : · 0"O'~.~:?~,:,::;': ': .,::..:r::.::'.:. 579 :00 779 779.60 700,.00 1,70 S 1,21 W ,~0 ,00 879 879.60 800,00 1,81 S 1,37 W ,DO ,00 : :zo79 ~o 7~. ~ .:o 7 s.::.::?~::~'~::~;~:?~:r~:~ .:~ ::::::::::::::::::::: : ~'e r~7~;-eo ..... ':; r~o;-o~..:.-:.':~:.:.:~.:~.~,::. .:':..~ ~z,~.:'';~::':,:?~'.:-:.?¥~:~?'':,:<r;'o s"::~'~:~ ~::~.:?.~ ::'~'~:~::~:::~':" ~':~:~:~':~?~':::,~.:.~.::': :-~ ......... ....... ...: .~.-"- ....................... .... ' eUU 1379 1379.60 1300,00 2,33 S ,89 ~ ,~1 .00 lq79 1~79,60 1~00,00 2,37 S ,87 W ,.01 .00 ','. _. :: ...... ::. ..... : ~....... ~ :.: : .::::..f~. ,::.;:,%:....:.: :;, ::. 'c.. :~ t.:.:,:: ' :? :: ::'::' :i-,:.':~..:,::,..::.:::>.:.:. ~:"~.~;;~:~b~.~;~f:: ;:: ?~:i::::.t~::J:: ~; .:<:i<J':':~;: ~::d ...: ..... :: ....~ , .... : ....... :...~.: : :...::.2'..: .... : ,.i.: .:::~ .'::?:; ':?;~;.: . .: ... SOHIO ALASKA PETROLEUM COMP~AN¥ PRUDHOE BAY ALASKA :' ::': SURVEY dUNE 6-v '1983. .c_O_t~.~ .O-~.~~A~T, ~ :.: ..: ~...:. ~....~ ........................ . ........... ~ dUNE 8v .3.983.. ~IOB NUMBER BOSS-16820 KELLY BUSHING ELEV. = 79.&0 FT. · :::: :i.: : ::: OM M C G U I.R E.i:' ::,:: :. :.:: : ..: :;:'..' .:..':: :..:-..! MEASURED ~'~--~'~-T'-~ TRUE SUB-SEA VERTICAL VERTICAL · · TOTAL RE CT ANGULAR COORDINATES MD-TVD VERTICAL 1879 19'7'9 1979,60 :I. 900,00 2,53 S . 2,/+5 2079 2079,60 2000,00 2,z~z+ S 2,57 W ,0:3. 2179 2179,60 2100,00 2,53 S 2279 2379 2479 2579 2679 2779 2879 2979 3080 33.80 3282 3385 .00 .01 .02 .0~ °3/+ 2579.60 2500.00 2.65 S .8i W .Ol 2679,60 2600.00 2.~5 S .86 W .~2' 2779,60 2700,00 .'5./+3 S 2,21 W "-2'g?'~':;-~'O:i "::': 2 8 0 0.0 0:./:-:::::'~:i::.':::::::' .: '. :. -6.0 2 s ~::: ..:!~.:-:?~:.:'i: !i;~:ii:.ii!i!?2~~ ~: 3179.60 3100.00 16.2G S 19.95 E 1.38 3279.60 3200,00 21.05 S 57,81 E 5,09 3379.60 3300.00 28,~0 S 59,37 E 5.66 .71 .57 LSOHIO ALASKA PETROLEUM COMPANY PRUDHOE BAY dUNE 8e 198! dOB NU~IBER BOS$-16820 ALASKA KELLY BUSHING ELEV. : . TRUE SUB-SEA TOTAL NEASURED VERTICAL VERTZCAL RECTANGULAR COORDINATES ND-TVD VERTICAL q034 5979.60 5900..00 126.82 S :279.77 E 54..62 1~.78 41~9 4079-~0 ~000.00 15~.~ S 332..03 E G9.81 15.19 'q379 ~279. 96'78:'.S : A723 ~579.60 qSO0.O0 266.92 S 588.82 E lq5.95 1~.27 ~837 q679.60 4GO0.O0 29~.16 S 638.55 E 156.02 l~.08 )' 5~03 5179.G0 5100.DO 407.52 S 875.G1 E 223.71 12.51 5516 5279.6~ 5200.00 ~31.ql S 923.27 E 237.04 13.33 '5-~-i .... 53~';-~0'~';~'~0%0~.~..' : "~ 5'G;~GS--S? .:~E:~.~:.:::.L~,:~:.::::.:~;::~;;:;:::;2 ~::.~.~?~::~-.?.~::.~ ..~...: ::;..::?: 1'~ 3';:. :~ FT. SOHIO ALASKA PETROLEUM COMPANY N=12 SEC8 9TllN,R15E PRUDHCE BAY ALASKA SPERRY-~-ON WELL ~ SURV~:YIN · ANCHORAGE,< MEASURED DEPTH ' 5982 SURVEY dUNE PAGE 1981 dUNE 8e .1981 dOB NUMBER BOSS-l&820 .KELLY BUSHING ELEV. : 79.60 TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL D E P TH ~, i i.': ': OEP T H N O RT ~"~'0~"'~ ~6100 5779.60 5700-00~ 568.89 S 1191,9~ E 321,21 18,75 6219 5879.60 58~.00 598.98 S 1249.25 E 3~.5~ 19.13 6338 5979.60 5900,00 628.45 S 1305,91 E 35~,99 18.&5 ~-~ '~'~?~;~,o<'~' .......... ~'~-'o"ovo~~ ..... ~'~4~-~ ' 6923 6~79,60 6~DO,OG 758.5~ S ~579,97 E ~3.88 16,06 7038 6579.60 6506.00 781,25 S 1631,65 E 45&.73 14,85 ~ 7265.:~ 6779'60~; ::~ 700.00 · :~ S; :':~:~.~ 7600 7079,60' 7000,00 891,6~ S i66~,69 E 521.~9 11.6~ 7712 7179,60 7100.00 915,05 S 1909.~ E 55~.~8 11.99 i ..... ~ os o..~. 7.~.!,~,,t,,~ o:~:~.. .:':.~!~.~_°3.- o o ':]~',' ~ .. 22 o ~o].S..'.~...~.... ..... FT. SOHIO ALASKA PETROLEUM cOMpANY PR UDHOE BAY ALASKA dUNE 8~ 1981 dOB NUMBER BOSS-l&820 KELLY BUSHING ELEVo = 1981 79.60 FTc MEAS · .. TRUE SUB-SEA TOTAL URED VERTICAL .VERTICAL. RECTANGULAR COORDINATES MD-TVD VERTICAL . .:.. ::. '~-~ 7-~'7'~0 ..... ~9~ 7~79.60 7700.00 ~.07~.7~ s 2~2.~2 E 6~.~3 ~.07 B505 7879.60 7800.~0 9075 8~79.60 8~00.00 [268.25 S 2~8.8[ E 6.96.38 [~.7~ 9190 8~7~.60 8~0~.0~ [~05.~7 S 2~90.~5 E 7[0.76 [~.~8 ~~gT0~ .... --':' ~-5'7:9T6-0'":;.: ...... ~ ~-~-8-~7 9;-~o::~ :'~.- 97~-8 8979.60 8900.00 1~78.49 S 266,7.18 E 9858 9079.60 9000,0{2) I510.35 S 2699.11 E ' 9-9-~'9' .' 'i~:~ :: 9'i7,9-.-~-0 ::'.i :~:~.:: 9~1-0'~8'07~:~ ~:~?~ ?:~:~ ~:I~32~ THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS Z~, --:5 x~ ~h ×~ ~SOHIO ALASKA PETROLEUM PRUDHOE BAY ALASKA coMPANY:.. SURVEY dUNE:G,': 1981 ' co z~ c su~<'-¢~~' ,JUNE 8e 1981 ,JOB NUMBER BOSS=16820 KELLY BUSHING ELEV, : 79.60 FT, [ TRUE : SUB SEA :' COUR TOTAL ~`~r~A-su~v~RTIc-AL---vERTzc~A~L---~Nc~L-rN~AT~N-~DTR~E~R~rY.~?~?`~a?~;c.~A~rG~rL-A~-~R~TN~ ~ s : yE CA' ~* ~. R'TT L DEPTH DEPTH DEPTH DEG NIN DEGREES DEG'/iO0 NORTH/SOUTH EAST/WEST SECTION 100 200 400 500 7 O0 800 9-$0 lO00 llO0 1600 1599,99 1520.39 0 11 S 88.70 W' .15 2./49 S 1.12 1700 1699,99 1620.39 0 13 S 80.10 W ,05 2.53 S 1,48 19OO 1899.99 : 1820'39 0 ' <<::~. 2.60 S .: 2000 199~,~9 ; 1.92'0'59 , 0:9~:;;.~::~ N:/47'l'O:::W?:< :~;~:~:~:~<':~:'~:~:?':10~'.;~. : 2,q9 S 2'qg'U ~-oo .... ~o9'9~'9~ ~ ' '-2o-~o~'-~9 ' : o '-5~~~~::;''~-~::.':':~':~'~:~:~'''?'''::~'~5::''?~':<: :-:~ ....... z~-~"6~ ........ :':":::=' ........ ~'-5'6~ ~ ~2 N 85.50 E .~8 2.52 S 2.3~ ,02 ,12 - --16 .30 2200 2199.'99 212O,39 2300 2299,99 2220,39 2q-0'0---'23'9<)-~ 9 ::; ::..:: 2500 2.499.99 ' 2~20, ~9 2600 2599.g9 2520'59 2800 2799.95 2720,~5 29 00 2899,92 2820,32 : , ..;. · . .'~ *. . .26 -.67 -.95 - 1-.-00 -,79 0 13 S 60,30 E .13 2,61 S 2.00 W 'Cr---I'5,~~~:;. . : 2 ,'2,2 S.: :::. :. i%-67 ii 0 !9 N:' 2.85 S'.' :.'.1,25 ' ' ":" ':!'?:<" :':<':?":~:<::'" :? 7 S :'" :: ::, 65. :' 0 2~ N 57...9;::E.: .13. 2.5 0--5 5 .... 2vs-n-s ................ ~" ;'~'~ '"~ 1 37 S 15,79 W 1,49 3.99 S 2.37 W 1 ~6 S 25,89 [ 1.10 6.~8 S 2,21 W -.'05 .32 ,'2'1 -,09 1,29 " c.o~,~m~T:O~:~:~':~:Y'E::'~':'::::~:::~::::::: ........ :~'"::':': ..... ~o-ss--~ osco,~ :C- PRUDHOE BAY ,JUNE 8) 1981 dOB NUMBER BOSS-16820 ALASKA . KELLY BUSHIN~ ELEV. = 79.60 FT. · .: s:U.'sE : :C0U. ...... DEPTH DEPTH DEPTH DEG HIN DE6REES DE6/~ O0 NORTH/SOUTH EAST/~EST SECTION 3500 3490.ql 3/410.61 16 30 S 62. 9 E 2.7/4 41,44 S 86.07 E 28 46.79 95.30 3600 3585.46 3505.86 .19 40 S 64.30 E 3.25 .55.39'S 113.80 E 1.26.30 ': 73'~7 9 · 04' 35 9 ~ · 4 4.:... : '..: i 4 5. ~..~::~:.E:,:i::::.:.::>...: ~o oo s'~ ~eg:~~~'~To::o--~-~ ..... ....... '" ..... z~':;'~:o':':-J 4100 4036.75 5957.75 29 51 S G6. 0 E .79 140.00 S 309.55 E 338.27 ~200 4123.47 ~0~3.87 29 5~ S &6. 9 E .05 16~.2~ S 355.05 E ~ ~ '4~'.i47777'::':' :~so4 s ':'s :::::::::::::::::::::::: · ~'o ....... : ~-~'-r~-4-~~~'z~-lv~-~:::'::::::: :::::::::::::::::::::::::::::::::<::::::::::;: :~: s: ...... 574--'5'~"'E 470O 4558.99 4479,39 28 5G S 65. 9 E ,05 262,12 S 578,~9 E 652,~0 4806 4646,60 4567,00 28 q2 S 64.89 E .25 282,50 S 622.19 5 i oo ·: ~: 4 si o' :: 2'7' : :.::'~' s9 s 750.58 5400 5176.67 5097.07 27 31 S 63.50 E .49 406.84 S 874e24 E .. 961.01 5600 : 5352':52::: 29 21-:.: :::959 s~-o'o .... 5~:,-o'-~-~-~-~ ............. ~~-~2"" .... :' ~'~:,-~,'z'::~::::::::::::::::::::::::::::o:~ ,: ~ .~ ': A_ :~: .: .::.: 5900 5610.12 5530.52 3158 6000 5694.74 5615.1q 32 2G ~i-0-0-: ::::: ':: · .. S 63-19 E °59 519-~+~+ S 1096,24 E 1209.65 S 62-59 E .57 543,72 S 11~+$,G8 E 1262,89 "N~-i-2-'~'E'~'a-'-Y¥i-~';A-~ CO~PUTA T I ON O ATE BOSS GYR OSCOP I C SURVEY PRUDHOE BAY dUNE 8, 1981 dOB NUMBER BOSS-16820 ALASKA KELLY BUSHING ELEV. = 79.60 FT. MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH BEG MIN DEGREES DEG/IOO NORTH/SOUTH EAST/WEST SECTION ~ o o : ~ o ~--?~ :.: :: s ~:~-':::, :?_~ 15~ i?~?:~'~:.,:~'~:?:s'.!:~ :~ ~ ~ ~". ~ 8' ~ :: ' 6500 6116,6`+ 6037.0/+ 31 ~+5 S 63,39 E .25 667,04 S 1381.96 E 6600 6700 6800 i:'6~oo ::,/AO_O. 7100 7200 7300 7500 77' O0 6201,86 6122.26 31 19 S 64.38 E .64 690,10 S 1/+28,91 6287.4/+ 6207.84 31 0 S 65.39 E .65 712.09 S 1475.75 30 50 S..: 6 &..:: :~: 0 ~::~i:' E . 1522.58 6633.53 6553,93 28 57 S 65. 0 E ,63 793,78 S 1658,80 6721,5~ 66~1.98 27 37 S 6~,30 [ 1,37 8~4,06 S 1701,6~ 6810.42 6730,82 27 0 S 64,89 [ ,68 833,75 S I7~3.10 1371.1/+ 1`+25.10 1/+78.,30 1530.97 1583,18 1634.76 1685.92 1'736.51 1785,86 183/+.26 1881.52 1927,29 78 O0 7257.03 2151 -67 79 00 73~+5.95 2197./+2 800U 7/+34 81043 7523 8200 761.1 8300 7699 8/+ O0 7787 85013 7871~ .65 .06 ,51 .65 .27 .90 7177-/+5 27 19 S 61,89 E 7266,35 27 8 S 60,59 E :355'0:51!:-.~i:::::::i~: !'::i.:'~:27.. 51 ~ii~?!:~?:: ;!?~ 7 ::: 7620~05 28 5~ S 58~ 0 E 7707.67 29 1 S 58. 0 E 7795.30 28 3~ S 56.80 E .,/+0 933.78 S 19/+/+,35 · 62 955,78 S 198~./+7 ~i~i~.i~:'2~;i;ii:i~ii!ii:. ::::: :. :;:: 9'78 ':55..::: :S ::::iii~:~.:::~:'ii:iF~:: 202:/+:. 63, o 1.8,+ ::.s::::::::::::::::::::::::::: :2 o65-i ~ · 89 1050.~5 S 21~5.~6 .43 1075.99 S 2186.33 .7¢ 1101.9~ S 2226.91 2243.59 2290.31 2336.96 238/+.16 2~32.32 2~80.~3 8800 8138,86 ';;::.::8:05:9':2 23/+3-2622.26 9000 8313.36 8233.76 29 2& S 50.&O E .70 12~.32 S 2~20.31 E 2716.95 ~100 8~00.59 8~20.99 29 6 S 48.80 E ,9~ 1275.9~ S ' 2~57.60 E 2766.99 SOH!O ALASKA PETROLEUM COMP ANY. ' :::':. :i:~: F :'sURVEy dUNE G, 1981 PRUDHOE BAY JUNE 8e 1981 JOB NUHBER BOSS-16820 ALASKA . KELLY BUIHING ELEV, = 79,60 FT, DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/1 O0 NORTH/SOUTH EAST/~EST SECTION . 9506" 875:3 o81 .':". :: 8674.21': :::':~: :: ~:~ '~:q5.:(~:]~5:0'~{~: E:~::~;:~.:~]]~.~ :~:.:: :': 259 3:'20": 29q 8.85 ,~ ~ ~-~-o-o~~:-'~-~"~T~-o'---~ ~"-~-o ':":'"'~:~'" ~'~" ' ~"~:~::':'::~'::::~s~;~E'::'::'~:~:?:~::~:~?'~''::::'~:'~ ..... ~: :~' ':"' '~' z~~ ~'~ o '::: ~' ':'~'~ ":::'-'"':'z ~ 9 ~-~- ~-~ ~00 ~5.~ ~55.5~ ~ 0 s ~s.~ E ~.~ ~.~9 s ~s2.~ E ~0~0.~ 9800 9026.~6 8946.86 2~ 12 S ~5. 0 E .~2 1~93.3~'S 2682.08 E 3069.65 9950 {~ 9162.~3.::~..:.: :.9082~:'8'3:.:~::~:?::~'::. ;25 ?:':::~8::::: :~:~:::'~.:: :272:7:"0'3~:~:5 3130.78 ~ O070 ~ 92 70, ~6 :;9t90"8'6'; ~:.~ ::::'::::'~:: 2:5:;:';::':3181.33 :~ HORIZONTAL DISPLACEMENT : ~181.3~ FEET 'AT, SOUTHe 60 'DEG. 20 MIN. EAST AT MD : 10070 . · 2. Suggested form to t~ insertcd in each "Active" well folder to check for timely compliance with our regulations. Olmrator, Well Name and Numker Reports ~and Materials to be received by: 7-~)- ~/ Date Required Date Received Ccrapletion Report . Yes ~._ ~._ ~/ Well HistOry .. Yes, , , Mud L~ .-, / .... · ... ~re ~ips ,,, , , , Core ~scription Registered Su~ey Plat ' ~ _ ff--g / Inclination Su~ey Dire~ional Su~ey Drill Stm Test Re. ms ~O.~Z." ,. Digitiz~ ~ta ,, e SOH I 0 CONF I DENT IAL SOHIO ALASKA PETROLEUM COMPANY ~~ ii iii i -- TO: SFO/UNIT/STATE: Mo~ .......... ' ,~ - I · Imm · _ -- Logs Indexed_ ~, 31 11 "C'° STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 6/17/81 # 8'65 N-12 N-12 N-12 N-12 N-12 N-12 REFERENCE: SOHIO, FINAL DATA The follow!rig material is being '~ubmitted 'herewith. ~Please acknowledge receipt by signing a copy of thi~ letter and returning it.to this office:-- , SFO/UNIT/STATE: OPEN HOLE 'FINAL LOGS DIL/SFL (Sch) 5/25/81 & 5/29/81 #l&2 BHCS (Sch) 5/29/81 #2 FDC " (Sch) 5/29/81 #2 FDC/CNL (Sch) 5 / 29 / 81 # 2 FX ID Log .. (Sch) 5/29/81 #1 2" & 5" 2" & 5" 2" & 5" ' 2,, & 5" .', STATE ONLY: DIRECTIONAL 'sORVEYS _ Magnetic Single Shot' surVey Gyroscopic Survey 5/15-5/29/81 6/6/81 , Job#A0581-029 Job#16820 '' -. ,-- _R. EcE VED o,~,E - ' ,,, JUL"O-? 19~1. ,, 19 Naska 0ii & Gas Cons. Commission Anchorage Development Geolggy Well Records ,:' -j l lis :~:,.': ?, SOHIO ALASKA PETROLEUM COMPANY ?-j~7~:~(iG- I ARCO TO: EXXON 31 11 "C" STREET ANCHORAGE, ALASKA TELEPHONE I907) 265-0000 i I STa'T"r~'iC MAIL: POUCH 6-612 [?l.F: .~ate: 6/23/81 # 873 PHILLIPS' SFO ' SOHIO MAGNETIC LIS TAPES The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- Magnetic LIS Tape & Listing (Sch) ~/1 5/29/81 " " " " (Sch) t/2 5/27/8:1 " " " " (Sch) Itl-2 5/29/81 Magnetic LIS Tape & Listing (Dres) NLL 6/2/81 " " " " (Sch) t/2 4/24/81 " " " (Dres) NLL 5/28/81 ~/61666 ~/61663 f/61664 ECC6927 f/61576 ECC6929 RECEIVED 19 Carol Krieter Development Geology Well Records HQ 4-5 SOHIO ALASKA PETROLEUM COMPANY 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 June 9, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well N-12 (31-17-11-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of May, 1981. RHR:ja Enclosures cc: Well File ~17 Yours very truly, District Dr illing Enginee~r .~ ' STATEOFALASKA ALASKA (~"," AND GAS CONSERVATION CO( AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 4. Location of Well at surface 7. Permit No. 81-14 99502 8. APl Number 50- 029-20557 9. Unit or Lease Name Prudhoe Bay Unit~ 10. Well No. 4136' SNL, 543' EWL, Sec. '08, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 79.60' AMSL 6. Lease Designation and Serial No. ADL 28283 N-12 (31-17-11-13) 11, Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of May ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well at 2130 hours, 5/13/81. Depth at monthend: 10070' (10010' PBTD) Footage drilled: 10070' See attachment for further details. 13. Casing or liner run and quantities of cement, results of pressur9 tests See attachment : 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP @ 9229' DIL/BHCS/G~SP @ 10058' FDC/CNL/GR/Cal @ 10058' Dipmeter @ 10058' 16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. iSiGNED ~ TiTLEDistrict Drilling EngineerDATE C' '~"~ NQTE--Report on this form is required for e~J~;h 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. F~orm 10-404 Submit in duplicate ..... Rev. 7-1-80 Well N-12 (31-17-11-13) WELL HISTORY Spudded well at 2130 hours, May 13, 1981. Drilled 17 1/2" hole to 2700'. Ran 68 jts. 13 3/8" 72% L-80 Buttress casing to 2681'. Cemented with 3720 cu.ft. Permafrost II cement followed by top job with 88 cu.ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2638'. Tested casing to 3000 psi, okay. Drilled out to 2760', ran leak-off test to 0.72 psi/ft, gradient. Directionally drilled 12 1/4" hole to 4649'. Torqued up bushing jumped out of table. Lost pump pressure and weight. Left 10 jts. drillpipe, 38 jts. HWDP, and BHA in hole. Top of fish at 2377'. RIH with 3 drill collars, 6 3/8" overshot, jars and bumper subs six times, changing grapple each time. RIH with 6 7/8" grapple and 11 3/4" guide. Jarred off three times. RIH with 6'5/8" grapple control guide and extension. Recovered fish. Inspected all joints. Laid down 46 jts. over- torqued drillpipe and HWDP. RIH with replacement pipe and drill collars. Directionally drilled 12 1/4" hole to 9250'. Ran open hole logs. Ran 237 jts. 9 5/8" 47% Soo-95 Buttress casing to 9243'. Cemented in two stages: First stage with 1327 cu. ft. Class G cement; second stage through D.V. packer at 2592' with 130 cu. ft. Permafrost C cement preceded by Arctic Pack. Drilled ou~ D.V. plugs, RIH to 8000' and tested casing to 3000 psi, okay. Directionally drilled 8 l~2~..~o~e_tO_10~TQ~_ _Ra~ope9 hol~logs,~Ran 33 jts. 7" 29% L-80 Buttress liner to 10060'. Cemented with 306 cu.ft. Class G cement. Cleaned out to 10010', tested liner and liner lap to 3000 psi, okay. Thru: ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hami chairman /~: Lonnie C. Smith/ Commissioner Ben LeNorman Petroleum Inspector May 28, 1981 B.O.P.E. Test on SOHIO'S N-12 Sec. 8, TllN, R13E, UM Prudhoe Bay Unit. Friday, May 15, .1981: I departed my home at 2:00 pm for a 2:30 PM' SHowup and 3"30-PM departure via the Sohio charter for Dead- ~horse arriving at 5~00 PM. Weather: +18"F, light wind, high overcast. saturday., May_ .16, 19~8~: B.O.P.E. tests on N-12 began at 5:20 PM and were cOmpleted a~ 8:20 PM. B.O.P.E. inspection report is attached. Sunday' May 17, 1981~ Witnessed inspection of $ohio's strainers a% Pump- S~'ti°~ #~i~-~ the subject of a separate report. B.O.P.E. test on Sohio's G-9 completed, the subject of a separate report. Monday, May 18, 1981: Retested low pilots and SSSV's on Arco ~'~i'i'i "sites #'2' ~3;' and 9, the subject of a seParate report. Inspect Arco's injection pad #3, the subject ..of a separate r epo rt. Tuesday: May 19, 1981: B.O.P.E. test on Sohio's ~{-14 Completed, the'' s~ject of~'a Separate re~rt· Wednesday~, May 20, 1981: I departed Deadhorse via Wien flight -~76 atl .... i'30 PM ~arri~ing in Anchorage at 3:10 PM and at my home at 3:40 PM. In summary, I witnessed successful B.O.P.E. test on~' Sohio's N-12. February 9, 1981 Mr. R. H. Re iley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Re: Prudhoe Bay Unit N-12 Sohio Alaska Petroleum Company Permit No. 81-14 Sur. Loc.: 4136'SNL, 543'EWL, Sec 8, TllN, R13E, UPM. Bottomhole Loc.: 297'SNL, 1775'~L, Sec 17, TIIN, R13E, UPM. Dear Mr. ~iley: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys 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 subject to AS 16.50. 870 and the regulations promulgated thereunder (Title 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. R. H. Reiley Prudhoe Bay Unit N-12 -2- February 9, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this pe rmit to dri 11. 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 abandov~aent, please give this office adequate advance notification so t.hat 'we may have a Very truly yours, ~. Bamilt~ ORDER OF TH~ CO,~~ON~ ~ ,e~ ~i~n of Alas~ Oil & ~s Conser~tion C~ission Enclosure cc~ Department of Fish & Game, ~bitat Section w/o encl. Department of Environmental COnservation w/o/encl. Depart'.~.~nt of Labor~ Supervisor, Labor Law Compliance Division w/o encl. SOHIO ALASKA PETROLEUM COMPANY January 30, 1981 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine'Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well N-12 (31-17-11-13) Enclosed are the following documents, in triplicate, along with our check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Blowout Prevention Diagram, 4. Surveyor's plat showing well location, 5. Directional plan. RHR:ja EncloSures cc: Well File ~17 Yours very truly, District Drilling Engineer RECEIVED FEB-.: 1981 Alaska Oil & Gas Cons. Commission Anchorage "' STATE OF ALASKA O~, ALASKA - AND GAS CONSERVATION C ,MISSION PERMIT TO DRILL 20 AAC 25.005 F la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL ~--1 SINGLEZONE~---I DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 9. Unit or lease name 4136' SNL, 543' 5WL, Sec. 08, TllN, R13E, UPM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 190' SNL, 1995' WEL, Sec. 17, TllN, R13E, UPM N-12 (31-17-11-13) At total depth 11. Field and pool 297' SNL, 1775' WEL, Sec. 17, TllN, R13E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Pruc~oe Oil Pool Est. KBE = 70' AMSLI ADL 28283 12. Bond information (see ~0 AAC 25.025) Type :Blanket surety and/or number Sabeco Ins. 29?538? Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed NW of Deadhorse 10 miles south of ADL 28282 408 feet well N-2 NE 2389 feet . , 16. Proposed depth (MD & TVD) 17. Number of acres in'lease 18. ApProximate spud date 10140IMD 93101TVD feet 2480 April 15, 1981 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 333U psig@ Surface .... KICK OFF POINT 2800 feet. MAXIMUM HOLE ANGLE 29 ° l (see 20 AAC 25.035 (c) (2) 4480 psig@ 9200 ft. ~(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) 36" 20x30 Insulated Conductor 110 Surface 1101 110 8 cu,yds, concrete I I 17 1/2 13 3/8 72# L-80 Butt. 2680 Surlface 26801 2680 3720 cu. ft. PermafroSt 12 1/4 9 5/8 479 L-80 Butt. 9110 Sur'~face 91101 8410 1260 cu. ft. Class G;... ~ I 130 cu.ft. PermafroSi .8 1/2 7 29~ L-80 Butt. 1530 8610 ~, 7977 1014011 9310 290 cu. ft. Class G 22. Describe proposed program: W/18% salt See attached proposed drilling program outline. RECEIVED FEB - 3 1981 Alaska 0i~ & Gas Cons. Commission Anchorage ' . 23. I hereby certi~r[y that the foregoing is true and c~.Erect to the best of my knowledge SIGNED TITLEDistrict Drilling Enginee~ATE The space below for CommiSsion use ~ ' ' ' ' CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I Apl number []YES ~.NO F-JYES (~O J~YES []NOI 50- ~ Permit number Approval date ' ~t-I~ 02/09/81 I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE February 9, 1981 by order of the Commission Form 10-401 Rev. 7-1-80 Submit in triplicate PROPOSED DRILLING AND COMPLETION PROGRAM WELL N-12 Dry bucket 36" hole to 80' below ground level and cement 20" x 30" insulated conductor to surface using 8 cu.yds, concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 725 L-80 Buttress casing to surface using 3720 cu. ft. Permafrost II cement. Blowout Preventer Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottom hole pressure is 4390 psi at 8800' TVDss (based on original reservoir pressure). Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVD. Directionally drill 12 1/4" hole to 8414'~ TVD. Run 9 5/8" 475 L-80 Buttress casing to 8414' TVD and cement first stage with 1260 cu.ft, cement. Cement second stage through D.V. packer collar at 2600'~ with 130 cu.ft. Permafrost I cement. 9 5/8" casing will be hung at surface, the 9 5/8" x 13 3/8" annulus will be Arctic Packed. Drill 8 1/2" hole to T.D. at 9310'~ TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe With 290 cu. ft. Class G cement with 18% salt. Run 5 1/2" IJ4S tubing with 6 gas lift mandrels and a production packer assembly at 7977'~ TVD. A subsurface safety valve with dual control lines will be placed at 2065'. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed per- forations to be submitted on Sundry Notice to follow. RECeiVED F£8 - 1981 AlaSka Oil & Gas eons. Commission ~Chorage B.O.P. STACK CONFIGURATION 5000 PSI WP DRILLING I ii ANNULAR PREVENTER PIPE RAMS BLIND RAMS CH ECK 2:" KILL LINE DRILLING SPOOL GATE GATE GATE 4" CHOKE LINE HYDR. ASST. GATE PIPE RAMS t~EC~'i VED F£~ _ ~ ]981 Alaska Oil & ?~ Cons. Co~l'ni$$ior~ ~c~orag~ N-2 5247 ' TVD S64° 03'E 3915 ' i . ' 1/ ., '. I 4 i }I~ 4,,5 j . {~o~ed~ ' ;N-9 ' oh ~ 1 I I I .................... ........ ! .......... T- .... : .... 1 ! CERTIFICATE OF SURVEYOR I! t IFLARE · PiT 4.,6o' 300' PAD DETAIL SCALE !"= $00' PORTION T. il N.,R. 13 E. SCALE I"= I/2 MILE I hereby certify that lam properly registered Io practice lend surveying in the Sro'to of Alaska and that this plot represents a location survey of the wellpad shown end the wells therecn. This survey wes mode by me or under my supervision end all dimensions and other details ore correct. Bottom hole locations are furnished by others. Dote Sur ye ye'/ ~DDED PROPOSED BHL N-128 N-IS =EVISED PROPOSED BHL N - tt .DDED PROPOSED BHL N-II _ IDDED PROPOSED BHL N-lO __ i ii i L iii iiii J i illlJll i PJR I DHO ~/4/eO DHO 11/3 /80 PJR 8/13/80 ii i i iu i L' '~. 5: ;, '. - 981 PAD ""',N" E.XTENSION Located in 5~' I/4 PROTRACTED SEC. 8, T. II N.IR.13 E.i UMI.AT MER~ALASKA Surveyed for SOHIO ALASKA PETROLEUM CO. .. i i i Surveyed by EM. LINDSEY & ASSOC.' - LAND ~ HYDROGRAPNIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska ii il ii i CHECK LIST FOR NEW WELL PERMITS Item Approve Date (1) Fe~e C/~ / . (3) (4) ~sg~ Yes ( 5 )BOPE -~. Is well located proper distance frcm other wells ................ ....~. / 6. Is sufficient undedicated acreage available in this pool ........... 7. Is well to be deviated ............................. -. ,..---- ..... ,-~¢~= 8. Is operator the only affected party., .................... - · Can permit be approved before ten-day wait ..................... Boes operator have a lx~nd in force ............. Isa Consorvat'ion order needed .................... ,, Additional Requirements: Is the' permit fee attached. .................................... ~ ..... Is well to be located in a def'~ed ~1 .. . i i ..~~ · / Is a registered survey plat attached .......................... ..... .~ / Is well located proper distance frcm property line .................. ~Z_ .... /- No 12. 13. 14. 6o '=~' Approval l%sc~ed: . .... . 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 ................. ' .~.~~ . 17. Will surface casing protect fresh water zones ....................... ~ .... 18. Will all casing give adequate safety in collapse, tension and burst..~~ 19. Does BOPE have sufficient pressure rating - Test to ~O~ psig .. Lease & Well NO. /~' Remarks ~Geology: Engin~r~ing: --. ?, rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. .o * ALASKA COMPUTING CENTER . ****************************** . ............................ . ....... SCHLUMBERGER ....... . ............................ ****************************** RECEIVED AUG 2 8 ~997 Alaska,Oil & Gas Cons. Commisd(xl Anchorage COMPANY NAME : BP EXPLORATION (ALASKA) INC WELL NAME : N-12 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292055700 REFERENCE NO : 97374 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/08/27 ORIGIN : FLIC REEL NAME : 97374 CONTINUATION # : PREVIOUS REEL : COM~ENT : BP EXPLORATION, PRUDHOE BAY, N-12, API #50-029-20557-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/08/27 ORIGIN : FLIC TAPE NAME : 97374 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, PRUDHOE BAY, N-12, API #50-029-20557-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINELOGS WELL NAME: N-12 API NUMBER: 500292055700 OPERATOR: BP EXPLORATION (ALASKA) INC LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 27-AUG-97 JOB NUM~ER: 97374 LOGGING ENGINEER: C. YON OPERATOR WITNESS: S. BUNDY SURFACE LOCATION SECTION: 8 TOWNSHIP: liN RANGE: 13E FNL: 4136 FSL: FEL: 543 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 79.60 DERRICK FLOOR: 78.60 GROUND LEVEL: 43.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 29. O0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 29 -MAY- 81 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9773.0 9772.5 9759.0 9756.0 9755.5 9743.0 9710.0 9658.0 9651.0 9648.0 9647.0 9623.5 9613.5 9598.5 9569.5 9563.0 9551.5 9544.5 9537.5 9537.0 9518.5 9499.0 9484.5 9483.0 9478.5 9477.5 9470.5 9453.5 9437.0 9422.5 9417.5 9393.5 9384.0 9383.5 9373.0 9365.5 9365.0 9355.0 9351.0 9345.5 9334.0 9331.0 9326.0 9325.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GR CH CNTD 88889.5 88889.0 9774.0 9774.0 9759.0 9759.0 9755.5 9754.5 9743.0 9743.0 9709.5 9710.0 9657.0 9651.0 9647.0 9647.0 9623.5 9614.5 9598.5 9598.5 9569.0 9562.5 9551.5 9545.5 9537.5 9537.5 9518.5 9518.5 9499.5 9499.0 9484.0 9484.0 9478.5 9478.5 9471.0 9471.0 9453.5 9453.5 9437.5 9437.5 9421.5 9421.5 9417.0 9417.0 9392.0 9392.0 9383.0 9383.0 9372.0 9372.0 9364.0 9364.0 9354.5 9349.5 9349.5 9343.5 9333.5 9333.5 9330.0 9330.0 9324.5 9324.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 9321 . 0 9320.5 9320.5 9288.5 9288.5 9288.5 9284.5 9284.5 9283.5 9284.0 9269.5 9270.0 9261 .'5 9260.5 9250.5 9250.5 9250.5 9218.0 9217.0 9214 · 0 9213.5 9195.0 9194.0 9194.0 9183.0 9182.0 9177.0 9175.5 9175.5 9163 . 0 9161 . 5 9149.5 9147.0 100.0 97.5 98.5 $ REMARKS: This tape contains the LDWG cased hole edit for BP Exploration well N-12 CNTD. There are four edit base passes an average pass file, and four raw data files. The depth adjustments shown above reflect cased hole GR to open hole GR and cased hole NPHI to open hole GR. Ail other CNTD curves were carried with the NPHI shifts. The base Gamma Ray was provided by the client. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01COI DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER : 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9790.0 9142.0 CNTD 9797.0 9142.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NI~4BER : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-I997 14:08 PAGE: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD REMARKS: This file contains CNTD Pass #1. shifts were applied to this data. $ LIS FORMAT DATA NO pass to pass ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE RBPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 NRATCNTD 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 CRATCNTD 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNTD CPS 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNTD CPS 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 CNTCCNTD CPS 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1022503 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: ** DATA ** DEPT. 9798.000 NPHI.CNTD 25.006 NRAT. CNTD 4.237 CRAT. CNTD NCNT. CNTD 2951.598 FCNT. CNTD 696.640 CFTC. CNTD 678.375 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1352.000 CCL.CNTD 0.000 DEPT. 9139.500 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC.CNTD GRCH. CNTD 42.801 TENS. CNTD -999.250 CCL. CNTD -999.250 4.419 3267.270 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCR~ENT: 0.5000 FILE SU~9~ARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9790.0 9142.0 CNTD 9797.0 9142.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFISER : 1 BASELINE DEPTH .............. 88888.0 9778.5 9778.0 9767.0 9763.0 9755.5 9745.0 9743.5 9738.0 9730.5 9728.5 9718.0 9710.5 9696.0 9695.5 9672.0 9658.0 9657.5 9651.0 9647.5 9624.0 9619.0 9599.0 9598.0 9585.5 9568.5 9545.0 9540.5 9537.5 9537.0 9518.5 9499.5 9499.0 9458.0 9454.0 9453.5 9437.5 9435.0 9417 0 9415 5 9408 0 9407 0 9393 5 9384 0 9383 5 9377.0 9372.5 9369.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTD .............. 88889.5 9780.0 9763.5 9754.5 9743.0 9695.0 9671.0 9656.5 9651.0 9647.5 9599.0 9585.5 9537.5 9518.5 9499.5 9458.0 9453.5 9438.0 9416.5 9406.0 9392.0 9383.0 9372.0 9368.5 88888.5 9778.5 9768.0 9755.5 9745.0 9738.5 9729.0 9726.0 9716.5 9709.0 9696.0 9657.0 9623.5 9619.5 9598.0 9568.5 9545.5 9541.5 9537.0 9499.0 9453.0 9435.0 9415.0 9407.0 9383.0 9376.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: 9364.5 9363.5 9355.0 9353.5 9354.5 9354.5 9342.5 9342.0 9336.0 9335.0 9330.0 9329.5 9326.0 9325.0 9321.5 9321.0 9320.5 9320.0 9311.0 9310.5 9288.0 9288.5 9282.0 9282.0 9278.5 9278.5 9268.5 9268.0 9260.0 9260.0 9258.0 9256.0 9254.0 9254.0 9245.5 9241.5 9235.5 9234.5 9226.5 9223.5 9225.5 9225.0 9211.0 9209.5 9205.5 9202.5 9199.5 9197.5 9195.5 9192.5 9184.5 9183.5 9184.0 9182.0 9169.0 9168.0 9165.5 9163.0 9160.0 9157.0 9155.0 9153.0 9152.0 9151.0 9148.5 9148.0 100.0 98.0 99.5 $ REMARKS: This file contains CNTD Pass #2. The depth shifts shown above relect GRCH pass #2 to GRCH pass #1 and NPHI pass #2 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: TYPE REPR CODE VALUE .............................. 4 66 1 5 66 6 73 7 65 8 68 O.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 NRATCNTD 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1022503 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9797.500 NPHI.CNTD 24.904 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD -999.250 CCL. CNTD -999.250 DEPT. 9140.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 50.509 TENS. CNTD -999.250 CCL.CNTD -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMFIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9792.0 9134.0 CNTD 9797.0 9134.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 9795.0 9786.5 9779.0 9778.5 9769.5 9759.0 9755.5 9753.5 9745.5 9743.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTD 88890.0 88888.0 9788.5 9780.0 9759.0 9754.5 9743.0 9795.0 9778.5 9767.5 9753.0 9745.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 10 9737.0 9728.0 9720.5 9709.0 9696.5 9696.0 9685.5 9680.0 9665.5 9658.0 9657 5 9651 0 9647 5 9635 5 9629 0 9622 0 9615 0 9613 5 9598 5 9598 0 9585.5 9569.0 9537.5 9537.0 9529.0 9519.0 9499.0 9484.5 9484.0 9478.0 9437.5 9432.0 9422.5 9417.0 9415.5 9405.5 9394.0 9388.5 9388.0 9384.0 9373.0 9372.0 9364.5 9360.5 9353.0 9329.0 9326.0 9321.5 9320.5 9311.0 9299.0 9288.5 9282.0 9275.0 9271.0 9720.5 9695.0 9679.5 9665.0 9656.5 9651.0 9647.5 9629.5 9616.5 9598.5 9585.5 9568.5 9537.5 9518.5 9499.5 9484.5 9438.0 9421.5 9416.5 9392.5 9387.0 9383.5 9372.0 9363.5 9360.0 9325.0 9320.0 9311.0 9298.5 9288.5 9282.5 9270.0 9737.0 9725.5 9709.0 9696.0 9685.5 9657.0 9634.5 9621.5 9614.0 9598.0 9537.5 9529.0 9499.5 9484.5 9479.0 9432.0 9415.0 9404.5 9387.5 9383.5 9371.0 9352.0 9328.0 9321.0 9282.0 9276.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 11 9268.5 9268.0 9256.5 9255.0 9252.0 9252.0 9235.5 9234.0 9235.0 9234.5 9219.0 9217.0 9212.5 9209.5 9195.5 9194.5 9195.0 9192.5 9186.5 9184.0 9177.0 9176.5 9172 . 5 9171 . 5 9163.5 9161.5 9158.0 9156.0 9154.5 9153.0 9150.0 9149.5 9147.5 9146.5 100.0 99.0 99.5 $ REMARKS: This file contains CNTD Pass #3. The depth shifts shown above relect GRCH pass #3 to GRCH pass #1 and NPHI pass #3 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: 12 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELI~ CODE (HEX) ....................................................................................... DEPT FT 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 NRATCNTD 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 CRATCNTD 1022503 00 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 FCNTCNTD CPS 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 ClTTC CNTD CPS 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 1022503 O0 000 O0 0 3 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 9797.000 NPHI.CNTD 24.301 NRAT. CNTD 4.104 CRAT. CNTD NCNT. CNTD 2891.945 FCNT. CNTD 704.705 CFTC. CNTD 686.229 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1375.000 CCL.CNTD 0.000 DEPT. 9133.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 47.971 TENS.CNTD -999.250 CCL. CNTD -999.250 4.327 3222.739 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 13 FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMF2~f: 0.5000 FILE SUMbIARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9792.0 9142.0 CNTD 9797.0 9142.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9792.5 9782.0 9769.0 9760.0 9753.5 9750.0 9743.5 973 6.5 9725.0 9721.0 9715.5 9710.0 9696.0 9695.5 9676.5 9671.5 9658.0 9657.5 9647.0 9638.5 9624.0 9613.5 9598.5 9598.0 9586.0 9569.0 9556.5 9544.0 9537.5 9537.0 9518.5 9499.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTD .............. 88888.0 88887.0 9791.5 9782.0 9768.0 9760.0 9753.0 9749.0 9743.5 9737.0 9725.5 9721.0 9715.0 9709.0 9696.0 9695.0 9676.0 9671.0 9657.0 9657.0 9647.0 9637.5 9623.5 9615.0 9599.0 9598.5 9586.0 9569.0 9556.5 9545.5 9537.5 9537.5 9518.5 9499.5 9499.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 14 9484.5 9484.5 9484.0 9484.5 9477.5 9478.5 9454.0 9454.0 9453.5 9454.0 9437.0 9437.5 9432.0 9432.5 9422.0 9421.5 9416.5 9416.5 9415.5 9415.0 9405.5 9405.0 9405.0 9404.5 9392.5 9391.5 9384.5 9383.5 9383.5 9383.0 9373.0 9372.0 9372.0 9371.5 9367.5 9366.0 9360.5 9360.0 9355.0 9354.0 9343.0 9342.5 9342.5 9341.5 9330.5 9330.0 9321.5 9321.5 9320.5 9320.0 9306.5 9306.0 9288.0 9288.5 9283.5 9283.5 9282.0 9282.5 9281.0 9281.5 9271.0 9270.5 9268.0 9268.0 9254.5 9254.5 9252.0 9252.0 9245.5 9246.0 9235.0 9234.0 9228.0 9230.0 9211.0 9213.5 9200.0 9202.5 9192.0 9191.5 9190.5 9193.5 9179.5 9183.5 9171.5 9177.0 9168.5 9168.0 9147.5 9147.0 9144.5 9151.0 100.0 99.5 106.5 $ REMARKS: This file contains CNTD Pass #4. The depth shifts shown above relect GRCH pass #4 to GRCH pass #1 and NPHI pass #4 to NPHI pass #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~4 CODE (HEX) DEPT FT 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTD PU-S 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNTD 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNTD 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNTD CPS 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNTD CPS 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTD CPS 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTD CPS 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 CCL CNTD V 1022503 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9797. 000 NPHI. CNTD -999.250 NRAT. CNTD 4.273 CRAT. CNTD NCNT. CNTD 2796.839 FCNT. CNTD 654.579 CFTC. CNTD 637. 418 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1403.000 CCL. CNTD 0.000 DEPT. 9141.500 NPHI.CNTD -999.250 NRAT. C NTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD 48.801 TENS.CNTD -999.250 CCL.CNTD -999.250 4.487 3122.417 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 16 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, 4 CNTD REMARKS: The arithmetic average of passes 1,2,3 & 4 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 O.5 9 65 FT 1i 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... N~E SERV UNIT SERVICE API API API API FILE NUMB NUIVlB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1022503 O0 000 O0 0 5 1 1 4 68 NPHI CNAV PU-S 1022503 O0 000 O0 0 5 1 1 4 68 NRAT CNAV 1022503 O0 000 O0 0 5 1 1 4 68 CRAT CNAV 1022503 O0 000 O0 0 5 1 1 4 68 NCNT CNAV CPS 1022503 O0 000 O0 0 5 1 1 4 68 FCNT CNAV CPS 1022503 O0 000 O0 0 5 1 1 4 68 CFTC CNAV CPS 1022503 O0 000 O0 0 5 1 1 4 68 CNTC CNAV CPS 1022503 O0 000 O0 0 5 1 1 4 68 GRCH CNTD GAPI 1022503 O0 000 O0 0 5 1 1 4 68 TENS CNTD LB 1022503 O0 000 O0 0 5 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9798.000 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 1352.000 DEPT. 9139.500 NPHI.CNAV -999.250 NRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV GRCH. CNTD 42.801 TENS.CNTD -999.250 -999.250 CRAT. CNAV -999.250 -999.250 CNTC. CNAV -999.250 -999. 250 CRAT. CNAV -999. 250 -999. 250 CNTC. CNAV -999. 250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 18 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCRemENT: 0.5000 FILE Ste4MARY VENDOR TOOL CODE START DEPTH CNTD 9805.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CNTD CNTD CNTD CNTD $ STOP DEPTH .......... 9140.5 COLLAR LOCATOR LOGGING SOURCE COMP NEUTRON HOUSING COMP NEUTRON CART. Il-AUG-97 8C0-609 1100 Il-AUG-97 10070.0 9798.0 9150.0 9798.0 1800.0 YES TOOL NUMBER ........... CAL-U 381 NSR-LA 3137 CNH-CA 64 CNC-DA 54 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 19 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 0.0 10060.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TE~fPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) '. WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG ) : PRODUCED FLUIDS 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REFiARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS #1. This log was depth ref to a Schlumberger BHC log dated, 29-May-81. Logging interval was TD (9798 ft ) to 9150 matrix = sandstone four passes were made $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 gAGE: 2O TYPE REPR CODE VALUE .............................. 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS1 PU 1022503 O0 000 O0 0 6 i i 4 68 0000000000 RTNR PS1 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS1 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS1 CPS 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS1 CPS 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS1 CPS 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS1 CPS 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS1 V 1022503 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9805.500 NPHI.PS1 23.585 RTNR.PS1 4.000 TNRA.PS1 RCNT. PS1 3282.051 RCFT. PS1 820.513 CNTC. PS1 3653.528 CFTC. PSi GR.PS1 0.000 TENS.PSi 897.000 CCL.PS1 0.000 DEPT. 9140.500 NPHI.PS1 50.491 RTNR.PS1 6.356 TNRA.PSI RCNT. PS1 1636.448 RCFT. PS1 257.454 CNTC. PS1 1868.309 CFTC. PSi GR.PS1 41.594 TENS.PSI 1188.000 CCL.PS1 -999.250 4.233 799.001 7.380 250.704 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 21 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMPIARY VENDOR TOOL CODE START DEPTH CNTD 9807.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CNTD CNTD CNTD CNTD $ STOP DEPTH .......... 9140.5 COLLAR LOCATOR LOGGING SOURCE COMP NEUTRON HOUSING COMP NEUTRON CART. 11 -AUG-97 8C0-609 1100 11 -AUG-97 10070.0 9798.0 9150.0 9798.0 1800.0 YES TOOL NUMBER ........... CAL-U 381 NSR-LA 3137 CNH-CA 64 CNC-DA 54 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: 22 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 0.0 10060.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REFiARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS #2. This log was depth ref to a Schlumberger BHC log dated, 29-May-81. Logging interval was TD (9798 ft ) to 9150 matrix = sandstone four passes were made $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 23 TYPE REPR CODE VALUE 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS2 PU 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS2 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS2 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS2 CPS 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS2 CPS 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS2 CPS 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS2 CPS 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS2 V 1022503 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9807.500 NPHI.PS2 23.585 RTArR.PS2 4.000 TNRA.PS2 RCNT. PS2 3282.051 RCFT. PS2 820.513 CNTC. PS2 3653.528 CFTC. PS2 GR.PS2 97.194 TENS. PS2 872.000 CCL.PS2 0.000 4.233 799.001 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: 24 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE . 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMF2~T: 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTD 9808.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CNTD CNTD CNTD CNTD $ STOP DEPTH 9133.0 COLLAR LOCATOR LOGGING SOURCE COMP NEUTRON HOUSING COMP NEUTRON CART. 11 -AUG-97 8C0-609 1100 II-AUG-97 10070.0 9798.0 9150.0 9798.0 1800.0 YES TOOL NUMBER CAL-U 381 NSR-LA 3137 CNH-CA 64 CNC-DA 54 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: 25 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 0.0 10060.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS #3. This log was depth ref to a Schlumberger BHC log dated, 29-May-81. Logging interval was TD (9798 ft ) to 9150 matrix = sandstone four passes were made $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: 26 TYPE REPR CODE VALUE .............................. 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 NPHI PS3 PU 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 RTNR PS3 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 TNRA PS3 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 RCNTPS3 CPS 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 RCFT PS3 CPS 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 CNTC PS3 CPS 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 CFTC PS3 CPS 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS3 V 1022503 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 9808.000 NPHI.PS3 RCNT. PS3 1684.211 RCFT. PS3 GR.PS3 99.751 TENS.PS3 7.996 RTNR.PS3 2.000 TN-RA.PS3 842.105 CNTC. PS3 1874.837 CFTC. PS3 916.000 CCL.PS3 0.000 DEPT. 9133.000 NPHI.PS3 53.318 RTNR.PS3 7.411 TNRA.PS3 RCNT. PS3 1764.166 RCFT. PS3 238.045 CNTC. PS3 1928.802 CFTC. PS3 GR. PS3 50 . 611 TENS. PS3 1226. 000 CCL. PS3 -999. 250 2.117 820. 027 7.704 231.804 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 27 **** FILE TRAILER **** FILE NA~E : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 9808.0 9141.0 CNTD LOG HEADER DATA DATE LOGGED: il-AUG-97 SOFTWARE VERSION: 8C0- 609 TIME LOGGER ON BOTTOM: 1100 II-AUG-97 Ti) DRILLER (FT) : 10070.0 TD LOGGER (FT) : 9798.0 TOP LOG INTERVAL (FT): 9150.0 BOTTOM LOG INTERVAL (FT) : 9798.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CNTD COLLAR LOCATOR CAL- U 381 CNTD LOGGING SOURCE NSR-LA 3137 CNTD COMP NEUTRON HOUSING CNH-CA 64 CNTD COMP NEUTRON CART. CNC-DA 54 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: 28 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRInr. R~S CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 0.0 10060.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (cPs): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS #4. This log was depth ref to a Schlumberger BHC log dated, 29-May-81. Logging interval was TD (9798 ft ) to 9150 matrix = sandstone four passes were made $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14:08 PAGE: 29 TYPE REPR CODE VALUE .............................. 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) ....................................................................................... DEPT FT 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 NPHI PS4 PU 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 RTNR PS4 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 TNRA PS4 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 RCNTPS4 CPS 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 RCFT PS4 CPS 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 CNTC PS4 CPS 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 CFTC PS4 CPS 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS4 V 1022503 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 9808.000 NPHI.PS4 67014.781 RTNR.PS4 -999.250 TNRA.PS4 RCNT. PS4 3368.421 RCFT. PS4 0.000 CNTC. PS4 3749.673 CFTC.PS4 GR.PS4 0.000 TENS.PS4 800.000 CCL.PS4 0.000 DEPT. 9141.000 NPHI.PS4 54.230 RTNR.PS4 7.061 TNRA.PS4 RCNT. PS4 1635.688 RCFT. PS4 231.660 CNTC. PS4 1875.095 CFTC. PS4 GR.PS4 48.468 TENS.PS4 1179.000 CCL.PS4 -999.250 -1057.499 0.000 7.809 225.587 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-AUG-1997 14: 08 PAGE: 30 **** FILE TRAILER **** FILE NAMIE : EDIT .009 SERVICE : FLIC VE~gION : O01CO1 DATE : 97/08/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/08/27 ORIGIN : FLIC TAPE NAME : 97374 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, PRUDHOE BAY, N-12, API #50-029-20557-00 * * * * REEL TRAILER * * * * SERVICE NAME : EDIT DATE : 97/08/27 ORIGIN : FLIC REEL NAME : 97374 CONTINUATION # : PREVIOUS REEL : C01~IMENT : BP EXPLORATION, PRUDHOE BAY, N-12, API #50-029-20557-00 N- 12 PRUDH OE BAY Run 1' 12 - June - 1994 PDK-I.00/GR BoraXLog t834 M/BSTERN ATLAS Atlas Wireline Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD N - 12 500292055700 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 28-JUN-94 1393.01 K. BRUNNER FRANKENBURG 8 11N 13E 4136 543 79.60 78.60 45.75 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 9241.0 3RD STRING 7.000 10060.0 PRODUCTION STRING 5.500 8802.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: BHCS PBU CURVE CODE: GR RUN NUMBER: 2 PASS NUMBER: 1 DATE LOGGED: 13-MAY-81 LOGGING COMPANY: SWS , EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH 9393.0 9394.0 9394.5 9396.0 9399.5 9399.5 9403.0 9403.0 9413.0 9413.5 9420.0 9420.5 9422.0 9422.5 9436.0 9436.5 9438.0 9438.0 9454.0 9454.0 9479.0 9479.0 9485.0 9485.0 9499.5 9499.5 47.00 29.00 17.00 9519.0 9538.0 9546.0 9552.0 9556.5 9563.0 9599.0 9647.0 9649.5 9651.0 9655.0 9657.0 9683.0 9710.0 9743.5 9755.0 9759.0 9793.0 9797.0 9812.0 $ REMARKS: 9519.0 9538.0 9546.5 9551.5 9557.0 9564.0 9599.5 9647.5 9650.5 9651.5 9655.5 9658.0 9683.5 9710.0 9744.0 9756.0 9759.5 9793.5 9797.0 9813.0 PDK-100/GR Borax Log. LOG TIED TO BHCS DATED 29-MAY-81. LOGGING SUITE ORGANIZATION: 1) BASE LOG AFTER 60 BBLS SEAWATER INJECTED. 2) BORAX PASS 1 AFTER 20 BBLS BORAX INJECTED. 3) BORAX PASS 2 AFTER 40 BBLS BORAX INJECTED. 4) BORAX PASS 3 AFTER 60 BBLS BORAX INJECTED. 5) FLUSH PASS AFTER INJECTING 20 BBLS SEAWATER. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR THE BASE PASS. THE CURVE IS CALLED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8.0" CASING SIZE = 7.0" SALINITY = 25,000 PPM. A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR THE BASE PASS. OPEN HOLE GAMMA RAY FOR DEPTH MATCHING DOWNLOADED FROM BP EXPLORATION UPS/CSS ON 24-JUN-94. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. / ? ?MATCH1A. OUT $ FILE HEADER FI LE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9381.0 9822.0 9394.0 9834.0 (MEASURED DEPTH) BASELINE DEPTH SGMA 9394.5 9396.0 9402.0 9402.0 9407.5 9408.5 9413.5 9414.0 9416.0 9416.0 9420.5 9421.0 9422.5 9423.5 9434.0 9434.5 9436.0 9436.0 9438.0 9438.0 9440.0 9440.0 9454.5 9454.5 9479.5 9479.0 9485.0 9485.5 9499.5 9499.5 9519.0 9519.0 9528.5 9529.0 9538.0 9537.5 9546.5 9546.5 9556.5 9556.5 9599.0 9600.0 9616.0 9616.5 9626.0 9626.5 9647.5 9647.5 9652.5 9653.0 9657.0 9657.5 9710.0 9710.5 9746.5 9747.0 9755.0 9756.0 9759.0 9760.0 9778.5 9778.5 9781.0 9781.0 9808.5 9808.5 9810.5 9810.5 $ REMARKS: in separate files. -- EQUIVALENT UNSHIFTED DEPTH BASE PASS (60 BBLS SEAWATER INJECTED). ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCH1B. OUT $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 BIF PDK 68 1 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 SS PDK 68 1 CPS 8 MSD PDK 68 1 CU 9 RATO PDK 68 1 10 RBOR P~DK 68 1 11 RICS PDK 68 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S * DATA RECORD (TYPE# 0) Total Data Records: 69 API API API API Log Crv Crv size Length Typ TYp Cls Mod 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 64 958 BYTES * Tape File Start Depth = 9845.000000 Tape File End Depth = 9365.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16338 datums Tape Subfile: 2 252 records... Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9379.0 9822.0 9391.0 9834.0 BASELINE DEPTH GRCH 9365.0 9365.0 9385.0 9383.5 9392.5 9393.5 9393.0 9394.5 9397.0 9398.5 9398.0 9399.0 9401.5 9402.5 9402.5 9403.0 9.403.0 9404.0 9407.5 9408.0 9410.5 9413.0 9414.5 9413.5 9417.0 9419.5 9420.0 9423.5 9424.5 9424.0 9424.5 9425.0 9426.5 9426.0 9427.5 9428.5 9429.5 9430.0 9431.0 9432.5 9433.5 9433.5 9434.0 9434.5 9438.5 9445.0 9445.5 9447.5 9448.0 9449.0 9449.0 9450.0 9450.0 9450.5 9457.5 9458.5 9459.0 9459.5 9465.5 (MEASURED DEPTH) in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 9409.0 9412.0 9414.5 9417.5 9420.0 9421.0 9425.0 9426.0 9430.0 9430.5 9435.5 9439.0 9448.0 9449.0 9458.5 9459.0 9466.0 9466.5 9477.0 9480.0 9482.0 9485.0 9489.0 9490.0 9491.5 9493.0 9493.5 9494.0 9494.5 9495.5 9499.5 9500.0 9504.5 9505.5 9520.5 9521.0 9525.0 9525.5 9530.0 9535.0 9540.5 9543.5 9555.0 9556.5 9557.0 9558.5 9559.5 9562.5 9581.5 9593.5 9597.5 9602.0 9603.0 9604.0 9608.0 9609.0 9636.0 9637.0 9644.5 9645.5 9653.5 9657.5 9660.5 9661.5 9662.5 9669.0 9671.0 9683.0 9687.5 9695.5 9703.0 9704.0 9704.5 9705.5 9715.5 9749.5 9756.5 9494.5 9495.5 9496.0 9500.O 9501.0 9505.5 9506.0 9541.0 9544.5 9556.0 9595.0 9603.5 9604.0 9605.0 9646.0 9659.0 9662.0 9670.0 9671.5 9684.0 9688.5 9696.0 9704.5 9705.0 9705.5 9706.0 9716.0 9751.0 9758.0 9466.5 9477.0 9480.5 9482.5 9486.0 9490.0 9490.5 9492.5 9494.0 9494.5 9521.0 9522.0 9526.0 9527.0 9531.5 9535.5 9557.0 9558.0 9559.5 9560.0 9563.5 9582.5 9599.0 9609.5 9610.0 9637.0 9637.5 9646.0 9655.0 9663.0 9663.5 9704.5 9705.0 9779.0 9789.0 9802.0 9802.5 9811.5 9812.0 9812.5 9813.0 9815.5 9828.0 9845.0 $ REMARKS: 9781.0 9790.0 9802.0 9803.0 9813.0 9812.5 9813.5 9814.0 9816.5 9828.5 9845.0 BORAX PASS I (20 BBLS BORAX AWAY) . ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH2A. OUT / ? ?MATCH2B. OUT $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 BIF PDK 68 1 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 SS PDK 68 1 CPS 8 MSD PDK 68 1 CU 9 RATO PDK 68 1 10 RBOR PDK 68 1 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 I CU 14 SGMB PDK 68 1 CU * DATA RECORD (TYPE# 0) Total Data Records: 61 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 00 201 24 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 4 4 00 201 24 1 4 4 00 201 24 1 56 966 BYTES * Tape File 'Start Depth = 9845.000000 Tape File End Depth = 9365.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 14416 datums Tape Subfile: 3 203 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9581.0 9822.0 9593.0 9834.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 9597.0 9599.0 9600.5 9602.0 9603.0 9635.5 9636.5 9647.0 9653.0 9697.5 9698.5 9702.0 9703,5 9703.0 9704.5 9704.0 9705.0 9704.5 9705.5 9705.5 9706.0 9706.0 9707.0 9706.5 9707.0 9708.0 9708.0 9708.5 9714.5 9715.0 9721.5 9721.5 9727.0 9727.5 9731.0 9733.0 9736.5 9738.0 9739.5 9743.5 9744.5 9745.5 9749.5 9751.0 9752.0 9755.5 9757.0 9757.5 9762.0 9771.5 9794.5 9795.5 9801.5 9811.5 9813.0 9814.0 9814.5 9815.0 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 9598.0 9636.5 9637.0 9647.5 9654.0 9707.5 9737.5 9746.5 9753.0 9758.5 9762.5 9772.5 9802.0 9814.5 9815.5 9816.0 9815.5 9828.0 $ REMARKS: 9816.5 9828.5 BORAX PASS 2 (40 BBLS BORAX AWAY). ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH3A. OUT / ? ?MATCH3 B. OUT $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 BIF PDK 68 1 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 SS PDK 68 1 CPS 8 MSD PDK 68 1 CU 9 RATO PDK 68 1 10 RBOR PDK 68 1 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU * DATA RECORD (TYPE# 0) Total Data Records: 61 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 , 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 56 966 BYTES * Tape File Start Depth = 9845.000000 Tape File End Depth = 9365.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 30754 datums Tape Subfile: 4 134 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9568.0 9822.0 9580.0 9834.0 BASELINE DEPTH GRCH 9573.0 9573.0 9585.5 9600.0 9600.5 9603.5 9604.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 9586.5 9608.0 9609.0 9609.0 9609.5 9613.5 9613.5 9624.5 9626.0 9625.0 9626.0 9627.0 9628.0 9629.5 9635.0 9636.0 9636.0 9636.5 9641.5 9642.0 9642.0 9643.0 9642.5 9643.5 9642.5 9643.5 9644.0 9644.0 9644.5 9644.5 9645.5 9646.0 9646.0 9646.5 9647.0 9647.5 9648.0 9652.5 9653.0 9653.0 9654.0 9655.0 9656.0 9660.5 9661.5 9667.5 9668.0 9676.0 9675.5 9680.5 9680.5 9681.0 9681.5 9683.0 9683.5 9683.5 9684.0 9691.5 9693.0 9703.0 9704.0 9704.0 9705.0 9704.5 9705.0 9705.5 9713.0 9713.5 9714.0 9714.0 9715.0 9716.0 9720.0 9720.5 9721.0 9728.5 9745.0 9750.0 9752.5 9754.0 9755.0 9757.5 9759.0 9768.5 9771.0 9780.0 9787.5 9791.0 9796.5 9802.0 9810.5 9811.0 9812.0 9813.0 9816.0 9817.0 9827.5 $ REMARKS: 9715.0 9716.5 9720.0 9720.5 9721.0 9729.0 · 9746.0 9751.0 9754.0 9755.5 9755.5 9758.5 9760.0 9769.0 9772.5 9780.5 9787.5 9791.5 9797.0 9802.0 9810.5 9811.5 9812.5 9813.0 9816.0 9817.0 9828.0 BORAX PASS 3 (60 BBLS BORAX AWAY) . ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH4A. OUT / ? ?MATCH4 B. OUT $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units GRCH PDK 68 1 GAPI BKL PDK 68 1 CPS BKS PDK 68 1 CPS BIF PDK 68 1 CSLS PDK 68 1 CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 6 LS PDK 68 i CPS 7 SS PDK 68 I CPS 8 MSD PDK 68 i CU 9 RATO PDK 68 1 10 RBOR PDK 68 1 11 RICS PDK 68 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 I CU * DATA RECORD (TYPES 0) Total Data Records: 61 966 BYTES * 56 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 Tape File Start Depth = 9845.000000 Tape File End Depth = 9365.000000 Tape File Level Spacing = 0.500000 Tape File .Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 28832 datums Tape Subfile: 5 159 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 9593.0 9599.0 9609.0 9610.0 9611.5 9612.5 9635.5 9636.5 9641.0 9642.0 9645.5 9646.0 9647.0 9651.0 9655.5 9657.0 9667.0 9676.5 9679.0 9680.5 9681.5 9697.0 9698.0 9699.0 9703.0 9706.5 9707.5 9713.5 9714.5 9715.5 9716.5 9721.0 9722.5 9726.5 9728.5 9731.0 9735.5 START DEPTH STOP DEPTH 9573.0 9822.0 9585.0 9834.0 GRCH 9599.5 9647.0 9651.5 9656.0 9668.0 9676.0 9678.5 9681.0 9697.0 9699.0 9703.5 9707.0 9707.5 9715.5 9726.0 9728.0 9731.5 9736.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 9593.5 9609.5 9610.0 9611.5 9613.0 9636.0 9636.5 9641.0 9641.5 9645.0 9646.0 9647.0 9658.0 9682.0 9698.5 9714.0 9714.5 9716.5 9722.5 9724.0 9743.5 9749.5 9755.0 9759.0 9770.0 9777.5 9778.5 9780.0 9788.5 9789.5 9790.0 9794.0 9797.0 9801.5 .9802.0 9802.5 9810.0 9811.0 9811.5 9812.0 9813.0 9819.0 9819.5 9828.0 $ REMARKS: 9744.0 9750.5 9756.0 9759.5 9779.0 9794.5 9797.5 9811.5 9812.5 9820.0 9770.5 9777.0 9780.0 9789.0 9789.5 9790.0 9801.0 9801.5 9802.5 9811.0 9811.5 9812.5 9819.0 9819.5 9828.5 FLUSH PASS (20 BBLS SEAWATER AWAY). ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH5A. OUT / ? ?MATCH5B . OUT $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units GRCH PDK 68 1 GAPI BKL PDK 68 1 CPS BKS PDK 68 1 CPS BIF PDK 68 1 CSLS PDK 68 1 CU LS PDK 68 1 CPS SS PDK 68 1 CPS MSD PDK 68 1 CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 9 RATO PDK 68 1 1~ RBOR PDK 68 1 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 14 SGMB PDK 68 I * DATA RECORD (TYPE# 0) Total Data Records: 61 CU CU 4 4 00 201 24 4 4 00 201 24 4 4 00 201 24 4 4 00 201 24 4 4 00 201 24 4 4 00 201 24 56 966 BYTES * Tape File Start Depth = 9845.000000 Tape File End Depth = 9365.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 45170 datums Tape Subfile: 6 156 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9381.0 PDK 9393.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9830.0 9842.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : 12-JUN-94 FSYS REV. J001 VER. 1.1 1013 12-JUN-94 9839.0 9842.0 9400.0 9834.0 1200.0 YES TOOL NUMBER 2725XA .000 10060.0 .0 SEAWATER/BORAX .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): .0 REMARKS: BASE PASS (60 BBLS SEAWATER INJECTED). $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 BIF PDK 68 1 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 G1 PDK 68 1 CPS 9 G2 PDK 68 1 CPS 10 ISS PDK 68 1 CPS 11 LS PDK 68 1 CPS 12 SS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 RATO PDK 68 1 16 RBOR PDK 68 1 17 RICS PDK 68 1 18 RIN PDK 68 1 19 SGMA PDK 68 1 CU 20 SGMB PDK 68 1 CU 21 SPD PDK 68 1 F/MN 22 TEN PDK 68 1 LB 23 SGNT PDK 68 1 CU 24 PHI PDK 68 1 PU-S 4 4 06 511 09 0 4 4 39 705 61 6 4 4 74 169 61 6 4 4 00 201 24 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 35 975 96 4 4 36 631 32 1 4 4 00 201 24 1 4 4 71 162 89 6 4 4 05 626 89 6 4 4 32 125 68 0 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 52 386 28 5 4 4 17 922 28 5 4 4 00 201 24 1 4 4 00 201 24 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 193 Tape File Start Depth = 9845.000000 Tape File .End Depth = 9365.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 76858 datums Tape Subfile: 7 267 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9379.0 PDK 9391.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9830.5 9843.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 12-JUN-94 FSYS REV. J001 VER. 1.1 1058 12-JUN-94 9839.0 9842.0 9400.0 9834.0 1200.0 YES TOOL NUMBER 2725XA .000 10060.0 .0 SEAWATER/BORAX .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): .0 REMARKS: BORAX PASS 1 (20 BBLS BORAX AWAY). $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 BIF PDK 68 1 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 SS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 TEN PDK 68 1 LB 4 4 06 511 09 0 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 17 922 28 5 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 175 Tape File Start Depth = 9846.000000 Tape File End Depth = 9366.000000 Tape File-Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 89354 datums Tape Subfile: 8 249 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9580.0 PDK 9592.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): STOP DEPTH 9828.0 9840.0 12-JUN-94 FSYS REV. J001 VER. 1.1 1129 12-JUN-94 9839.0 9842.0 9400.0 9834.0 1200.0 YES TOOL NUMBER 2725XA .000 10060.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER/BORAX .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): .0 REMARKS: BORAX PASS 2 (40 BBLS~ BORAX AWAY). $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 BIF PDK 68 1 5 CCL PDK 68 1 6 CSLS PDK 68 i CU 7 CSS PDK 68 1 CPS 8 G1 PDK 68 1 CPS 9 G2 PDK 68 1 CPS 10 ISS PDK 68 1 CPS 11 LS PDK 68 1 CPS 12 SS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 RATO PDK 68 1 16 RBOR PDK 68 1 17 RICS PDK 68 1 18 RIN PDK 68 1 19 SGMA PDK 68 1 CU 20 SGMB PDK 68 1 CU 21 SPD PDK 68 1 F/MN 22 TEN PDK 68 1 LB 4 4 06 511 09 0 4 4 39 705 61 6 4 4 74 169 61 6 4 4 00 201 24 1 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 35 975 96 1 4 4 36 631 32 1 4 4 00 201 24 1 4 4 71 162 89 6 4 4 05 626 89 6 4 4 32 125 68 0 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 52 386 28 5 4 4 17 922 28 5 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 102 Tape File Start Depth = 9843.000000 Tape File 'End Depth = 9563.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 102642 datums Tape Subfile: 9 176 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9568.0 PDK 9580.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S .CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9828.0 9840.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 12-JUN-94 FSYS REV. J001 VER. 1.1 1149 12-JUN-94 9839.0 9842.0 9400.0 9834.0 1200.0 YES TOOL NUMBER 2725XA .000 10060.0 .0 SEAWATER/BORAX .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): .0 REMARKS: BORAX PASS 3 (60 BBLS BORAX AWAY). $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 BIF PDK 68 1 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 G1 PDK 68 1 CPS 9 G2 PDK 68 1 CPS 10 ISS PDK 68 1 CPS 11 LS PDK 68 1 CPS 12 SS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 RATO PDK 68 1 16 RBOR PDK 68 1 17 RICS PDK 68 1 18 RIN PDK 68 1 19 SGMA PDK 68 1 CU 20 SGMB PDK 68 1 CU 21 SPD PDK 68 1 F/MN 22 TEN PDK 68 1 LB 4 4 06 511 09 0 4 4 39 705 61 6 4 4 74 169 61 6 4 4 00 201 24 1 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 35 975 96 1 4 4 36 631 32 1 4 4 00 201 24 1 4 4 71 162 89 6 4 4 05 626 89 6 4 4 32 125 68 0 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 52 386 28 5 4 4 17 922 28 5 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 105 Tape File 'Start Depth = 9843.000000 Tape File End Depth = 9555.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 115874 datums Tape Subfile: 10 179 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 11 is type: LIS FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 5 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9573.0 PDK 9585.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SB SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9828.0 9840.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 12-JUN-94 FSYS REV. J001 VER. 1.1 1209 12-JUN-94 9839.0 9842.0 9400.0 9834.0 1200.0 YES TOOL NUMBER 2725XA .000 10060.0 .0 SEAWATER/BORAX .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): .0 REMARKS: FLUSH PASS (20 BBLS SEAWATER INJECTED). $ CN : BP EXPLORATION WN : N - 12 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 BIF PDK 68 1 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 SS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SPD PDK 68 1 F/MN 4 22 TEN PDK 68 1 LB, 4 4 06 511 09 0 4 39 705 61 6 4 74 169 61 6 4 00 201 24 1 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 1 4 71 162 89 6 4 05 626 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 17 922 28 5 88 * DATA RECORD (TYPES 0) 1018 BYTES * Total Data Records: 105 Tape File Start Depth = 9843.000000 Tape File End Depth = 9555.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 129162 datums Tape Subfile: 11 179 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 12 is type: LIS 94/ 6/28 01 **** REEL TRAILER **** 94/ 6/29 01 Tape Subfile: 12 2 records... Minimum record length: 132 bytes Maximum record 'length: 132 bytes End of execution: Wed 29 JUN 94 5:08p Elapsed execution time = 1 minute , 57.4 seconds. SYSTEM RETURN CODE = 0 PRUDItOE BAY ~~~ ~ JAN 02 Run 1: 04 - DEC - 1995 CNIGR Cased Hole 9230 9802 Logging Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING N - 12 500292055700 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 18-DEC-95 -' 1393.04 S. WHIPP 8 11N 13E 4136 543 79.60 0.00 45.75 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 9241.0 47.00 7.000 10060.0 29.00 5.500 8692.0 17.00 4.500 8802.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 13 -MAY- 81 SWS BASELINE DEPTH 9254.5 9258.5 9259.0 9262.0 9273.0 9273.5 9274.5 9283.0 9294.0 9313.5 9335.0 9336.5 9337.0 ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 9253.0 9257.0 9258.0 9261.0 9271.5 9272.0 9272.5 9281.5 9292.5 9312.5 9334.0 9336.5 9337.0 9338.0 9339.0 9339.5 9355.0 9356.0 9363.5 9364.5 9375.0 9376.0 9378'0 9378.5 9382.5 9383.5 9391.5 9392.0 9396.0 9396.5 9397.0 9398.0 9399.0 9402.0 9403.0 9405.0 9405.5 9411.0 9412.0 9420.5 9421.0 9423.0 9424.0 9432.0 9443.5 9444.0 9458.5 9459.5 9477.5 9479.0 9493.0 9494.0 9495.0 9495.5 9504.0 9505.0 9505.5 9520.5 9596.5 9597.0 9597.5 9603.5 9604.5 9611.5 9616.5 9640.5 9641.0 9642.0 9646.0 9646.5 9647.5 9660.0 9661.0 9337.5 9338.5 9339.5 9355.0 9355.5 9363.0 9364.5 9375.0 9375.5 9377.5 9378.5 9382.5 9383.0 9391.0 9392.0 9396.0 9397.0' 9397.5 9398.0 9398.5 9401.5 9402.0 9404.0 9405.0 9410.5 9411.0 9419.5 9420.5 9422.5 9423.0 9430.5 9442.0 9443.0 9457.5 9458.0 9476.0 9478.0 9492.0 9492.5 9493.5 9494.5 9503.0 9503.5 9504.0 9519.5 9595.5 9596.0 9596.5 9602.5 9603.0 9610.5 9615.5 9640.0 9640.5 9641.0 9645.0 9646.0 9647.0 9660.0 9661.0 9662.0 9669.5 9702.0 9702.5 9703.5 9704.5 9706.0 9706.5 9712.5 9713.0 9751.5 9761.0 9764.0 9764.5 REMARKS: 9661.5 9669.0 9702.0 9702.5 9703.0 9703.5 9705.0 9706.0 9712.0 9713.0 9751.5 9760.5 9763.5 9764.0 CN/GR Cased Hole. LOG WAS TIED INTO BHCS DATED 29-MAY-81. WELL TEST SUMMARY TEST DATE 24-OCT-95 ELAPSED TIME HOURS 4.0 GROSS FLUID RATE MBPD 2 . 16 NET OIL RATE MBOPD 1.12 NET WATER RATE MBWPD 1.03 FORMATION GAS RATE MMSCFD 3.35 GOR SCF/STB 2980 LIFT GAS RATE MMSCFD 2.46 CASING PRESSURE PSIG 993 TGOR SCF/STB 5173 TGLR SCF / STB 2692 CHOKE OPENING 60.1 MANIFOLD PRESSURE PSIG 215 MANIFOLD TEMPERATURE DEGF 76 WATER CUT (CALC) PCNT 4 8.0 NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CHISM OFF, CALIPER & CASING CORRECTED, SALINITY = 0.0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCHIA. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: I START DEPTH STOP DEPTH 9221.0 9793.0 9230.0 9802.0 BASELINE DEPTH NPHI 9260.5 9261.0 9286.0 9286.0 9324.5 9322.5 9337.0 9336.5 9338.5 9338.0 9339.0 9339.0 9342.5 9342.5 9354.5 9355.5 9375.0 9376.0 9376.5 9377.5 9381.5 9381.0 9383.0 9382.5 9386.0 9387.0 9396.5 9396.5 9397.0 9397.0 9398.0 9397.5 9399.0 9398.0 9400.0 9398.5 9400.5 9399.0 9401.0 9400.0 9402.5 9401.5 9403.0 9402.5 9407.5 9407.0 9419.0 9420.0 9441.5 9438.5 9442.0 9440.5 9444.0 9442.5 9445.0 9443.0 9447.5 9445.5 9448.5 9446.0 9449.5 9447.0 9450.0 9448.0 9450.5 9448.5 9451.0 9449.5 9456.0 9454.5 9457.0 9455.0 9457.5 9456.0 9459.0 9457.5 9473.0 9471.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 9476.5 9479.0 9488.0 9488.5 9 489.0 9489.5 9490.0 9493.0 9504.5 9519.0 9538.0 9569.5 9 595.0 9602.5 9 603.5 9610.0 9613.5 9614.0 9615.0 9616.0 9616.5 9641.0 9641.5 9642.0 9642.5 9643.0 9644.0 9657.0 9693.5 9698.5 9699.0 9699.5 9700.0 9707.0 9708.0 9709.0 9722.5 9755.5 9781.5 9800.0 REI~kRKS: 9474.5 9476.5 9485.5 9486.5 9487.0 9488.0 9488.5 9491.0 9502.5 9517.0 9536.5 9569.0 9593.5 9601.5 9602.5 9608.0 9611.5 9612.5 9613.5 9614.0 9614.5 9638.5 9639.0 9640.0 9640.5 9641.5 9642.5 9656.5 9692.5 9698.0 9698.5 9699.5 9700.0 9706.5 9707.5 9708.0 9722.0 9755.5 9781.5 9800.0 PASS 1. FUCT & NUCT WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ? ?MATCHIB. OUT $ : BP EXPLORATION (ALASKA) : N-12 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod I GRCH 2418 68 i GAPI 2 NPHI 2418 68 i PU-S 3 FUCT 2418 68 i CPS 4 NUCT 2418 68 i CPS 4 4 4 4 4 4 4 4 16 42 995 99 1 42 995 99 1 42 995 99 1 42 995 99 I * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 26 Tape File Start Depth = 9840.000000 Tape File End Depth = 9205.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6356 datums Tape Subfile: 2 312 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: I START DEPTH STOP DEPTH 9221.0 9793.0 9230.0 9802.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH GRCH NPHI 9217.0 9215.5 9226.5 9225.0 9234.0 9234.0 9254.0 9252.0 9269.0 9268.5 9282.5 9282.5 9294.0 9292.0 9310.0 9308.5 9310.5 9309.0 9311.5 9312.5 9314.0 9315.0 9323.5 9324.0 9325.0 9332.0 9336.5 9340.0 9340.5 9343.5 9349.0 9350.5 9351.5 9359.0 9362.5 9366.5 9375.0 9376.5 9378.5 9379.5 9381.5 9387.0 9387.5 9391.0 9392.0 9392.5 9310.0 9311.5 9313.0 9313.5 9330.5 9335.5 9339.0 9340.0 9350.0 9350.5 9358.0 9362.0 9378. 9378. 9386. 9387. 9390. 9391. 9391. 9321.5 9322.0 9322.5 9335.5 9342.5 9349.0 9359.5 9367.5 9375.0 9376.5 9380.5 9386.5 9393.0 9394.0 9398.0 9399.0 9403.5 9406.5 9410.0 9411.0 9414.5 9423.5 9424.5 9426.5 9429.0 9429.5 9444.5 9445.5 9448.0 9448.5 9449.5 9455.0 9471.0 9483.0 9488.0 9489.0 9489.5 9490.0 9493.5 9494.0 9495.0 9496.0 9497.0 9500.5 9501.0 9501.5 9503.0 9504.0 9504.5 9518.0 9537.5 9544.5 9563.0 9572.5 9573.0 9573.5 9593.5 9594.0 9597.0 9598.5 9602.0 9604.0 9608.0 9615.0 9628.5 9641.5 9642.0 9642.5 9644.0 9656.5 9662.5 9676.5 9392.5 9397.5 9398.0 9409.0 9409.5 9422.0 9423.5 9425.5 9427.5 9443.5 9447.0 9447.5 9448.0 9486.5 9487.0 9487.5 9493.0 9493.5 9494.0 9499.5 9500.0 9500.5 9502.0 9502.5 9543.0 9596.0 9603.0 9606.5 9627.0 9641.0 9662.0 9676.5 9394.0 9403.0 9406.0 9414.5 9428.0 9443.0 9453.5 9468.0 9480.5 9487.0 9488.0 9494.0 9494.5 9502.0 9515.5 9535.5 9561.0 9570.5 9571.5 9572.0 9590.0 9590.5 9597.0 9599.5 9612.5 9639.0 9640.0 9641.5 9656.5 9677.5 9681.5 9696.0 9698.5 9699.0 9702.0 9703.0 9703.5 9704.5 9706.0 9711.5 9712.5 9713.0 9713.5 9715.5 9716.0 9745.5 9749.5 9757.5 9765.5 9780.0 9782.5 9783.5 9788.0 9790.0 9797.0 9797.5 REMARKS 9677.5 9680.5 9694.5 9697.5 9698.5 9701.5 9702.0 9702.5 9703.0 9705.5 9711.0 9711.5 9712.0 9712.5 9714.0 9715.0 9744.5 9749.0 9756.0 9765.0 9779.0 9781.5 9782.0 9788.0 9790.0 9797.0 9797.5 PASS 2. FUCT & NUCT WERE SHIFTED WITH NPHI. / ? ?MATCH2A. OUT /??MATCH2B. OUT CN : BP EXPLORATION WN : N - 12 'FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units GRCH 2418 68 i GAPI NPHI 2418 68 1 PU-S FUCT 2418 68 1 CPS NUCT 2418 68 i CPS (m sKA) Size API API API API Log Crv Crv Length Typ Typ C ls Mod 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 I * DATA RECORD (TYPES 0) Total Data Records: 26 1006 BYTES * 16 Tape File Start Depth = 9840.000000 Tape File End Depth = 9205.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet - **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6356 datums Tape Subfile: 3 184 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type= LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER~ DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 9221.0 9793.0 2418 9230.0 9802.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: i ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH GRCH NPHI 9217.0 9215.5 9226.5 9225.0 9234.5 9233.0 9246.5 9243.0 9247.5 9244.0 9255.0 9252.5 9256.5 9256.0 9260.0 9257.5 9260.5 9258.5 9275.0 9274.5 9276.5 9274.5 9277.5 9275.0 9280.0 9277.5 9282.5 9280.5 9286.0 9285.0 9286.5 9286.0 .9288.5 9288.0 9289.5 9288.5 9293.0 9292.0 9293.5 9291.5 9294.0 9292.5 9294.5 9292.0 9293.5 9305.0 9301.5 9311.0 9307.5 9313.0 9312.0 9313.5 9312.5 9314.5 9313.0 9318.5 9316.0 9326.5 9324.0 9327.0 9325.0 9329.5 9328.0 9330.5 9328.5 9332.5 9330.5 9336.0 9334.5 9335.0 9342.5 9341.5 9343.0 9342.5 9344.0 9343.5 9344.5 9349.0 9349.5 9350.0 9351.0 9353.5 9354.0 9354.5 9355.5 9358.5 9359.0 9360.5 9370.5 9373.5 9374.0 9375.5 9376.5 9379.0 9386.5 9390.0 9390.5 9391.0 9392.5 9393.0 9393.5 9394.5 9395.0 9395.5 9396.0 9396.5 9397.0 9397.5 9398.5 9401.5 9402.0 9402.5 9403.0 9407.5 9408.0 9410.0 9410.5 9411.0 9420.0 9421.0 9422.5 9423.0 9425.5 9426.5 9427.5 9430.5 9431.5 9432.0 9433.0 9438.0 9439.0 9439.5 9440.0 9442.5 9443.5 9445.0 9347.5 9348.5 9349.0 9349.5 9352.0 9353.0 9353.5 9354.0 9357.0 9358.0 9391.5 9392.5 9393.0 9393.5 9394.0 9395.0 9395.5 9396.5 9397.5 9400.5 9401.0 9401.5 9408.5 9409.0 9420.5 9421.5 9425.0 9425.5 9430.0 9430.5 9442.5 9344.5 9350.0 9357.0 9358.5 9370.0 9373.0 9374.0 9375.5 9376.0 9378.5 9386.5 9390.0 9391.0 9391.5 9393.0 9396.0 9396.5 9397.0 9397.5 9400.5 9401.0 9406.0 9407.0 9409.5 9410.5 9419.5 9420.0 9424.0 9424.5 9428.5 9429.0 9435.5 9436.0 9436.5 9437.5 9440.0 9440.5 9445.5 9446.0 9448.0 9449.0 9450.0 9456.0 9456.5 9457.0 9458.0 9458.5 9459.0 9472.5 9490.0 9492.0 9493.5 9494.0 9494.5 9495.0 9496.0 9496.5 9501.5 9502.5 9504 · 0 9504.5 9505.0 9506.5 9508.0 9512.0 9512.5 9514.0 9514.5 9515.0 9523.0 9524.0 9532.5 9533.0 9536.0 9542.5 9543.0 9560.5 9568.5 9571.5 9572.0 9573.0 9573.5 9577.0 9577.5 9586.0 9587.0 9590.5 9591.0 9592.0 9593.0 9594.0 9594.5 9595.0 9603.5 9604.0 9604.5 9609.0 9446.5 9447.5 9448.0 9456.5 9457.5 9492.5 9493.0 9494.0 9495.0 9500.0 9500.5 9502.0 9503.0 9521.5 9522.0 9530.0 9531.0 9534.0 9567.0 9592.5 9593.5 9603.0 9607.5 9442.5 9443.5 9453.5 9454.5 9455.0 9455.5 9456.5 9469.5 9487.0 9490.0 9491.5 9492.0 9501.5 9502.0 9503.5 9504.5 9508.5 9509.5 9511.0 9512.0 9512.5 9540.0 9541.0 9558.5 9569.0 9570.0 9571.0 9572.0 9575.5 9576.5 9585.0 9585.5 9590.0 9590.5 9591.0 9592.0 9592.5 9593.0 9601.5 9602.0 9613.5 9614.5 9615.0 9616.0 9629.0 9634.5 9635.0 9640.5 9641.0 9641.5 9647.0 9653.0 9 654.5 9659.0 9660.5 9661.0 9663.0 9664.5 9683.0 9684.0 9684.5 9690.0 9691.0 9694.5 9695.0 9699.0 9699.5 9701.5 9702.5 9703.5 9717.5 9718.5 9719.5 9729.5 9746.0 9755.0 9759.0 9759.5 9762.5 9764.0 9777.5 9780.0 9783.0 9784.0 9786.0 9787.5 9788.0 9796.5 9797.0 9797.5 $ REMARKS: 9612.0 9612.5 9612.5 9614.0 9626.5 9633.5 9634.0 9639.0 9640.0 9638.5 9644.0 9652.0 9653.5 9658.5 9660.0 9661.0 9662.0 9662.5 9683.0 9682.0 9683.0 9688.5 9689.0 9694.0 9692.5 9698.5 9699.5 9701.5 9699.0 9702.0 9702.5 9702.0 9716.0 9716.5 9717.0 9729.0 9744.5 9753.5 9758.0 9759.0 9761.5 9763.5 9777.5 9779.0 9782.0 9782.5 9784.5 9786.5 9788.0 9797.0 9797.0 9797.5 PASS 3. FUCT & NUCT WERE SHIFTED WITH NPHI. / ? ?MATCH3A. OUT / ? ?MATCH3B. OUT $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : N- 12 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GRCH 2418 68 i GAPI 2 NPHI 2418 68 i PU-S 3 FUCT 2418 68 I CPS 4 NUCT 2418 68 I CPS 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 16 * DATA RECORD (TYPE~ 0) 1006 BYTES * Total Data Records: 26 Tape File Start Depth = 9840.000000 Tape File End Depth = 9205.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12712 datums Tape Subfile: 4 267 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass I gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0. 5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 1, 2, 3 2418 1, 2,-3 $ REMARKS: AVERAGED PASS. CN WN FN COUN STAT GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES. $ BP EXPLORATION (ALASKA) N-12 PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units I GRCH CNAV 68 i GAPI 2 NPHI CNAV 68 I PU-S 3 FUCT CNAV 68 i CPS 4 NUCT CNAV 68 i CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 16 * DATA RECORD (TYPE# 0) Total Data Records: 2 6 1006 BYTES * Tape File Start Depth = 9840.000000 Tape File End Depth = 9205.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12712 datums Tape Subfile: 5 49 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER= 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9219.0 2418 9228.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM= TD DRILLER (FT): TD -LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (PT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (PT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): .MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9827,5 9836.5 04-DEC-95 FSYS REV. J001 VER. 1.1 1800 04-DEC-95 10010.0 9804'0 9230.0 9802.0 1800.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA 0.000 10060.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : N- 12 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log crv Crv Size Length Typ Typ Cls Mod I GR 2418 68 I GAPI 2 CNC 2418 68 i PU-S 3 CN 2418 68 i PU-L 4 LSN 2418 68 i CPS 5 SSN 2418 68 i CPS 6 CCL 2418 68 1 7 SPD 2418 68 I F/MN 8 TEN 2418 68 I LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 91 Tape File Start Depth = 9840.000000 Tape File End Depth = 9208.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35474 datums Tape Subfile: 6 166 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9220.0 2418 9229,0 $ DATE :r.Z:)GGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FI'): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB PCM PCM/CCL GR GAMMARAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (PT): LOGGER'S CASING DEPTH (PT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY'. HOLE CORRECTION (IN): STOP DEPTH 9827.5 9836.5 THERMAL SANDSTONE 0.00 0.000 04-DEC-95 FSYS REV. J001 VER. 1.1 1828 04-DEC-95 10010.0 9804.0 9230.0 9802.0 1800.0 YES TOOL NUMBER 3913NA 8250EA/824eEA 8262XA 2418XA 0.000 10060.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.00.0 0.000 0.000 0.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : N- 12 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units i GR 2418 68 i GAPI 2 CNC 2418 68 I PU-S 3 CN 2418 68 i PU-L 4 LSN 2418 68 i CPS 5 SSN 2418 68 i CPS 6 CCL 2418 68 1 7 SPD 2418 68 I F/MN 8 TEN 2418 68 I LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 ,635 99 1 32 * DATA RECORD (TYPES 0) Total Data Records: 91 1014 BYTES * Tape File Start Depth = 9839.000000 Tape File End Depth = 9206.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35510 datums Tape Subfile: 7 166 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9217.0 2418 9226.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9825.5 9834.5 04-DEC-95 FSYS REV. J001VER. 1.1 1856 04-DEC-95 10010.0 9804.0 9230.0 9802.0 1800.0 YES TOOL NUHBER 3913NA 8250EA/8248EA 8262XA 2418XA 0. 000 10060.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0. 000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : N- 12 : PRUDHOE BAY : NORTH SLOPE * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod I GR 2418 68 i GAPI 2 CNC 2418 68 i PU-S 3 CN 2418 68 I PU-L 4 LSN 2418 68 I CPS 5 SSN 2418 68 i CPS 6 CCL 2418 68 1 7 SPD 2418 68 I F/MN 8 TEN 2418 68 I LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 91 Tape File Start Depth = 9839.000000 Tape File End Depth = 9207.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 58236 datums Tape Subfile: 8 166 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 9 is type: LIS 95/12/18 01 **** REEL TRAILER **** 95/12/18 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 18 DEC 95 4:llp Elapsed execution time = 2.42 seconds. SYSTEM RETURN CODE = 0 SCH~U BERGER.~ . . ~ ' ~ISTAPE VER!FI¢ ~'NG _ LVP 009,H03 VERfFICATIDN ~ISTING PAGE ** REEL HEADER SERVICE NAME :SERVIC DATE :81/06/ 6 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 PR VIOUS REEL COMMENTS ~REEL COMMEN~S ** TAPE HEADER ** SERVICE NAME :SERVIC DATE :8it06t 6 ORIGIN :NAM1 TAPE NAME : CONTINUATION # :01 PREVIOUS TAPE ~ COMMENTS :TAPE COMMENTS ** FIbE HEADER **~ VERSION DATE : MAXIMUM LENGTH : 1024 FIbg TYPE PREVIOUS FILE ** INFORMATION RECORDS MNEM CONTENTS CN WN FN RANG: TOWN: SECT: COUN: STAT: CTRY: MNEM S~HIO ALASKA PETROLE N 12 PRUDHOE BAY ANGE OWNSHIP ECTION ORTM SLOPE ALASKA U.S.U. CONTENTS PRES: DIbFDNF ** RECORD TYPE 047 ** ** RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 020 065 00 000 005 065 O0 000 015 065 000 000 005 065 000 000 008 065 00 000 007 065 00 000 015 065 000 000 010 065 000 000 010 065 UNIT TYPE CATE SIZE CODE 000 000 OO7 O65 bVP 009,H03 VERIFICATION LISTING PAGE 2 RECORD TYPE 047 ** DATA FORMAT RECORD ENTRY BLOCKS TYPE 9 0 SIZE REPE CODE ENTRY 4 65 . lin ! 66 0 DATUM SPECIFICATION MNEM SERV ID DEPT SP ISN ILD ISN SFnU GR ISN DT RHOB NPHI NUC GR NUC CALI NUC DRHO NUC NEAT NUC NCNb NUC FCNL NUC ICE SERVIC ORDER BLOCKS UNIT API API API API FILE SIZE PROCESS SAMPLE LOG TYPE CLASS MOD NO. LEVEL V 0 0 OHMM 0 12 46 O 0 4 OH~M 0 0 0 0 0 4 ~HN~ 2 0 0 4 APi 0 3~ 30 0 0 4 0 G/C3U$/F 0 ~ 4 0 52 3 35 4 PU 0 68 2 '0 .0 4 GAPI 0 3! 32 0 0 4 N 0 2-8 3 4 /C3 0 44 0 4 42 34 9~ 0 34 93 0 0 4 REPR 0 1 68 0 I 68 0 1 68 0 1 68 0 1 68 0 I 68 0 1 68 0 1 68 0 1 68 0 ! 68 0 1 68 0 1 68 0 1 68 DATA DEPT SFLU NPHI NEAT ;250 GR .100 GR .740 NCNb ~999.250 ILD 999.250 DT- 128,250 CALf 2600.000 FCNL ~999.250 ,250 RHOB .297 DRHO 971.000 DEPT SFLU NPHI NEAT ooo :ooo 719 GR NCNb -31.500 93.813 D ,8.3 ~ALZ 2961.000 FCNL 747.352 ,563 RHOB 'B;742 DRHO 1394.000 DEPT SFLU NPHI NEAT 9900 000 SP 6:973 GR ~5.723 GR 2.~. 1I NCNb -58.03i ILD 50. 406 DT 48.875 CALI 2938,000 FCNL 3.602 74.563 RHOB 9.1~2 DRHO i4~-2.,0 0 DEPT ~FbU NPHI NEAT 980 000 SP 20 ', 6'54 GR 2,412 NCNb -~.312 .484 DT .328 ILM ,563 RHOB .8,695 DRHO 1259,000 DEPT SFLU 9700.000 SP 16.406 GR -90 312 ILD 5,328 ILM 6.i-88 RHOB -999 250 2:45! 0,148 7.055 2.607 0.039 3,775 2.490 0.057 9.930 2,365 0,012 12.258 2,357 B DRHO ~00 NPHI S NRAT DEPT 6 5 95 HO D!RHO 2'51:0 PAG~ 0,064 17.125 2.47~. 0,060 14.773 2,414 0.018 :l. 5~,000 781 0,036 , ? '0'467 2,578 '999,250 -999,250 99~,374 - ,250 -999,250 2,334 -999,250 -999.250 3,207 -999.250 -999,250 ,215 ,250 .250 9~.390 -9 .250 LVP NPHI NRAT DEPT NPHI NRAY DEPT SFGU NPHI NRAT DEPT SF~U NPHI NRAT DEPT NPHI NRAT DEPT NPHI NRAT DEPT NPHI NRAT DEPT SFhU PH! RAT DEPT FGU PHI NRAT DEPT SFLU NPH! NRAT DEPT NPHI NRA DEPT '999, '999. 8400,000 '999 -999~ -99 2 , 0 NCNG ggg. 250 8200 000 SP .250 G -' ~ {mm ~' ~ 3- m. ~ · "999,250 NCNL : 999,250- FC . '9.99,250 PAGE -999.250 I 295 -999!250 -999 250 1.450 '999,250 -999.250 2 705 2,807 -999.250 '999.250 810~, 1,224 . -999,250 '999, -999,250 -999. ,ooo.ooo 1 000 · -999[250 -999 250 . 91.,213 GR .9 9.250 999.250 'NCNb ~ i"'"999 790~ 000 SP 629 GR -999 -99·9 5 ~ 0 7800.000 SP M ;250 GR -999,250 NCNG i999-250 :;FCN[--~ '_:999.250 '' 9:344 -99 250 -999'250 770~.000 -SRP ,535 G -999, -999, 1,491 · 999,250 -'999,250 2 32O ~.999:250 999.250 7600.000 SP 1.955 -~99.250 - 99.250 750-0,000 .$P ! · 726 GR :1.433 -999.250 bVP 009.H03 VERIFICATION bISTING NPHI NRAT DEPT SFbU NPHI DEPT NRAT DEPT DEPT SFbU NPHI NRAT DEPT SFbU NPHI NRAT DEPT SFbU NPHI NRAT DEPT SFLU NPHI NRAT DEPT NPHI NRAT DEPT SFLU NPHI NRAT DEPT SFLU NPHf NRAT DEPT SFLU -999.250 GR ~999,250 -999.250 NCNb .... 999, 740~,000 SP .064 GR 385. -999, 0 NCNb 9 7300,000 SP -66 -99~ 999fi - 2 0 NCNb 999 7.20~,000 SP 617 GR 99~3:250 GR 7100.000 SP 9993 984 GR - 250 GR -999 250 NCNb 250 RHOB DRHO 250 0 ) ILD IbM 125 DT 999,250 RH B 250 CAbI -999,250 DRHO 250 FCNL -999~250 ' -( 50 RHOB CAGI i~.9.250 R~O -71 13 -999, 50 -999,250 ooo ooo =so -,,,. o 6900 000 SP -54.406 Z~ ~:990 GR .100~500 T :999,250 GR .999.250 ALI 0 999.250 NCNb '999.25 1 '999 50 CAb -999 ~50 FCNb 103, -999. -999'250FCNL 0 PAGE -999.250 2 045 -999!250 -999 250 2.467 -999.250 -999.250 3.234 '999,250 '999.250 3.326 -999,250 -999,250 -999 250 GR -999 25O NCNU 6700,000 , 902 GR :99 ,250 GR 999,250 NCNb ~60~.000 SP ,553 GR 999,250 GR '999.250 NCNb 6500,000 SP , 990 GR :99 250 GR 999.250 NCN~ 640~,000 SP .797 GR 1,819 '999,250 '999,250 1,916 '999,250 '999.250 3.584 -999,250 -999,250 6O " HO -999,250 B .-999' 50 CAGI - -999'2:50 DRHO 2 999,250 FCNL -999. 250 -59,281 '85.29:250 ILD '. 2'242- · 3,215 -999.250 -999,250 2.781 :999.250 999'250 2,352 -999.250 LVP NPHI NRAT DEPT SFDU NPHI NRAT DEPT NPHI NRAT DEPT SFDU NPHI NRAT DEPT NPHI NRAT DEPT SF~U NPH~ NRAT DEPT SFbU NPHI NRAT DEPT SFLU NPHI NRAT SFLU NPHI NRAT DEPT SFLU NPNI NRAT DEPT NPHI NRAT DEPT SFLU 009.M03 VERIFICATION bISTING -999,250 GR -999.250 NCNb 6300.000 SP 2.869 GR -999,250 GR -999,250 NCNb 6200,000 3,311 -999,250 G -999.250 NCNb -999,250 GR -999,250 NCN~ 6000 000 -999.250 NCNb o :ooo -999,250 -999;250 5800.000 SP 99~ 006 - 250 GR -999 250 NCNb 570~,000 SP ,629 GR '999,250 '999,250 NCNb 600,000 SP 250 GR -999,250 NCNb 50~,000 664 9 ~ 5 999,2 0 GR -999,250 NCNb 5400.000 25, 53 999,~ 50 '999,250 NCNb -999.250 CAb[ '99'9,250 DRHO -999.250 -9991,250 -60.563 ILD . 3.359 IbM 101'625 DT 999;250 RHOB -999..250 CA~Z~ ~ . -999.250 DRHO -64,188 I~D . ~4,637 IbM 97.[25 DT -999.250 -:999.250 -CA~I :999,250-' 999,250 FCN~ 999,250 116,~, ~8 D~ '999.~50 CA5I 0 FCNb 9,9.250 '999.25 ' ' 9 " P -7 D IbM R 8 RHOB GR -999.250 CAbI '999,250_ DRHO NCNb -999,250 FCNb -999,250 .53 72.43:8 D~ .'999'250 CALI "'999 '250 FCNIa -999;250 -~23,8~3 IbD ~,-3.~48 IbM 64.000 DT -999.250 RHOB -:999,250 CAbI :9.99~2:50' DRHO 118.625 I~D 486 IbM '46,688 DT ~ 999,250 CAbI -999,250 FCNb :999.,250 -g12,312 ,500 DT '999 ~5.0 CAbI '999:50 FCNL -122.563 40,875 DT :999,250 CAhI ' ,999,250 '999'250 RHOB '999;250 DRHO "999,250 16 813 .IbD 38:656 DT -999,250 RHDB PAGE -999.250 250 -999.250 3.320 -999 250 -999:250 4,641 -999,250 -999,250 3.775 -999,250 -999,250 3,375 -999 250 '999:250 3 453 ~-999i250 -999 250 3,543 -999.250 -999.250 2.785 -999.250 -999.250 3.809 -999,250 -999,250 10.734 -999,250 '999,250 2.160 -999,250 LVP NPHI NRAT DEPT SFLU NPHI NRAT DEPT NPHI NRAT EPT FLU NRAY DEPT SFLU NPHI NRAT SFLO NPH! NRAT DEPT FLU PHI NRAT DEPT SFLU NPHI NRAT DEPT NPHI NRAT NPHI NRA? DEPT SFLU NPHI NRAT 009.H03 VERIFICATIDN GISTING -999.250 GE -999.250. NCNL 5100,000 SP 4 516- GR -.999' ,250 GR 999. 250 NCN(~ 500~.0.00 SP ,086 GR '999,250GR '999.250 NCNL 4900. 000 -9599223 250 GR HO -999. 250 NC.NL '999'-250 FCNL.>-"9991,250 4800,000 3.988 'GR '999, -999. 4700.000 ,250 GR 999.250 N. CNL ,o .ooo .770 999,2§0 GR 999.250 NCNL 4500.000 SP 9~.914 GR -9 ,250 '' '999,250 'NC'L 4400,000 3'971 '999,250 GR- -999,250 NCNL 4300.000 SP ,746 . - ! !!,~!! 999 ', 250 DRHO: '999; 250 FCN"L '999,250 . PAGE -999.250 2.463 -999.250 -999.250 1.955 -999,250 -999.250 :984 -99 250 -999.250 -99250 -999.250 2.381 -999.250 -999.250 5.410 -999.250 -999.250 5871 999i250 250 10.531 -999.250 -999.250 2.828 -999.250 -999.250 5.137 -999.250 -999,250 420~:000 469 4.789 -999.250 ~VP NPHI NRAT DEPT SFLU NPHI NRAT DEPT FbU PHI NRAT DEPT SFGU NPHI NRAT DEPT SFbU NPHI NRAT DEPT SFLU NPHI NRAT DEPT SFbU NPHI NRAT EPT F~U NPHI NRAT DEPT SFb NPH¥ NRAT SFLU NPHI NRAT DEPT FbU NRAT DEPT SFbU 009,H03 VERIFICATION T~ISTING ~. _-:- : '999 2S0 GR .999-.2~0 ·CALX '999': 250 ' DRHo : ~ '999:.250 ' '999 -999 4000 -999 390i -999 -999 3800.000 SP -99~' -999~250 NCN<b 3700. 8, -999.250: -999,25'0 NCNb 3600.000 SP :99'. 999.250- !NCNb 350~.000 ,629 -999~250GR -999'250 NCNb 3400 000 SP 250 GR -999 250 NCNb 330~ -999.250 GR -999.250 NCNb 3200.000 SP '250 GR -999*-250NCNb 310~ PAGE -999.250 0 0 SPt 4,133 ,223 GR . -999.250 250 -GR '99-9'2-50:'- CA.L,X<.: ':':-..,,,,.999,":250 :DRIdO -999. 250 · 20 -999.250 '25 " '999,250 250 NCN~ ' ~999 o00 $ -' 0 P .383 GR '250 GR .250 NCNb 3.707 :999.250 999°250 6 105 '999~250 -999,250 6,977 -999'250 "'999.250 0 '"999,250 '999,250 5.238 -999,250 '999,250 -999. 0 '999,250 5 906 :999:250 999.250 3,332 -999 250 0 -999~250 .000 SP -66.563- !bD- -' : <:6'3'7-9- IbM _B,863 .250 GE 76.688DT -99'9;250 RHOB -99~.250 LVP 009,H03 VERfFICATfON LI~TING NPHI -999.250 GR NRAT -999.250 NCNL DEPT SFLU NPHI NRAT DEPT NPHI NRAT DEPT SFLU NPHI NRAT DEPT NPHI NRAT DEPT SFLU NPHI NRAT -999.250 CAbI '999,250 FCNb -999.250 DRHO -999.250 oo :ooo 250 GR -999,250 GR '999.250 NCNI~ -~9.250 -ILO 9,625 DT -999~250 CALI -999.250 FCN~ ,0 47 II~M -99 .250 RHOB :9~.9'25o DRHO 999. 250 2900.000 SP -65.063 ILD 836 GE .70.500 4.090 IbM 999,250 RHOB 999.250 DRHO .,,,999,250 -999 -999 ,000 SP ,44! GR 250 GR 250 NCNL -68,875 ILD ~4,090 ~ILM 84,188 DT -999.250 RHOB -999,250 ..ALI 999.250 DRHO -999'250 FCNb -999,250 . . 000 700. -999,25'0 SP GR NCN[~ -99 188 ILD ae2,i7~2 ILM 59:500 'D~ ~:~~,9'2,,~0 EHOB -999. 250 CALI 9. 250 DRHO ......'"999,250 FCN~ -999,250 ',,.999.2=:O. C~LI. ~ .99-9,250 DRHO -999,250 FCNL 999. 250 VERSION # DATE ~ MAXIMUM LENGTH : [024 · FILE TYPE · NEXT FILE NAME EOF ~~~ ** TAPE TRAILER.*~ SERVICE NAME lSERVIC DATE :8i/06/ 6 ORIGIN :NAMi TAPE ~AME CONTI UATION NEXT TAPE.NAMB ' CO~ENTS ~TAPE ~OMMENTS ** REE~ TRAILER.~ SERVIC NA~E :SERVIc DATE ~81/06/ 6 ORIGIN : PAGE -999.250 4,355 -999.250 -999.250 4.074 -999.250 -999.250 4.0~6 50 2.~58 -999. 50 -999.250 ~000,000 999.250 -999.250 LVP 009.H03 VERIFICATION REEI~ NAME **REEI~ ID CONTINUATION # ,"0 EXT R~E~ NA~E, COMMENTS :REE~ COMMENTS ***,**.*** :. : . _ . ; PAGE lO
