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196-174
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a, Well Status. Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned R Suspended ❑ 8 to t tjf aRo3r i� Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL 11 No. of Completions: Zero 11b. Development p Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Aband.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 8/14/2019 196-174 ' 319-197 3. Address: 7. Date Spudded; 15. API Number: r P.O. Box 196612 Anchorage, AK 99519-6612 11/7/1996 50-029-22716-00-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: • 11/26/1996 PEW 11-37 Surface. 4628FSL, 4639' FEL, Sec. 34, T11N, R15E, UM 9 Ref Elevations KB 53 50 17. Field/Pool(s): r Top of Productive Interval' 4610' FSL, g' FEL, Sec. 33, T11 N. R1 5E, UM r GL 27.00 - BE 29.31 PRUDHOE BAY, PRUDHOE OIL Total Depth: 393' FSL, 4031' FEL, Sec. 27, T11N, RISE, UM 10. Plug Back Depth(MOrrVD): 18. Property Designation: 8570'18472' 1ADL 028325 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD): DNR Approval Number: Surface: x- 708213 y- 5951091 Zone - ASP 4 10440'/ 8858' f 70-054 TPI: x- 707563 y- 5951056 Zone - ASP 4 Total Depth: x- 708790 y- 5952152 r Zone - ASP 4 12. SSSV Depth (MD/TVD): None Thickness of Permafrost MD/rVD: 1900' (Approx.) [21. 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: Re-drill/Lateral Top Window electronic antl printed information per 20 AAC 25.050 N/A (ft MSL) MD/1VDSubmit /A 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, ie Acronyms may be used. Attach a separate page if necessary I r F` �./VVVq MWD / LWD (DIR/FE), OR, RES, DT, NPHI, DEN, CFTC, CNTC, PEFZ SEP 0 9 2019 23. CASING, LINER AND CEMENTING RECORD CASING %VT PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE MOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 27' 107' 27' 107' 30" 260 sx Arctic Set(Approx.) 9-5/8" 40# L -e0 26' 3809' 26' 3803' 12-1/4" 2231 sx CS III, 335 sx Class'G" 7" 26#129# L-s0n3cra0 25' 9327' 25' 8891' 8-1/2" 320sx Class'G' 4-1/2" 12.6# L-aviwrm 9205' 10440' 8876' 8858' 6" Uncemented Slotted Liner 24. Open to production or injection? Yes ❑ No 21 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.6# 13Cr80 7580' 7502'/ 7469' �,� /� lf�����r((,,,,��q/6 ( 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 000 n(\�E,I(q Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed IT U/ l information DEPTHINTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED RIFIE 8570' Set Whipstock AV M 27, PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): N/A Date of Test : Hours Testetl: Production for Test Period —► Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size Gas -Oft Ratio: Flow Tubing Press Casino Press: Calculated 24 Hour Rate --1 Oil-BbL Gas -MCF: Water -Bbl: Oil Gmvity- API (corr): Form 10-407 Revisetl 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMSi&SEP 10 2019 '0-eeal"'1111'-7 JC, THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 11-37 Permit to Drill Number: 196-174 Sundry Number: 319-197 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 via .aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, zrl�5� Daniel T. Seamount, Jr. Commissioner DATED this �day of April, 2019. RB0MS46J APR 2 3 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DECEIVED 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ r Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change: Approved Program•.M Plug for Rednll 0 • Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0• 5. Permit to Drill Number: 196-174 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic 11Service ❑ 8. API Number: 50-029-22716-00-00 . 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 11-37 9. Property Designation (Lease Number): 10. Field/Pools. ADL 0028325 PRUDHOE BAY. PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ff): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD). 8710, Junk (MD): 10440 8858 8710 8603 2493 8720,8990,9272 9144 Casing Length Size MD TVD Burst Collapse Structural Conductor BD 20" 27-107 27-107 1490 470 Surface 3783 9-5/8" 26 - 3809 26-3803 5750 3090 Intermediate 1 9302 7" 25-9327 25-8891 7240 / 8160 5410/7020 Production Liner 1 1235 4-1/2" 9205 - 1 D440 8876-8858 1 8430 1 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: Tubing Grace: Tubing MD (ft): 8622-10417 8521-8858 4-1/2" 12.6# 13Cr80 1 22-7580 Packers and SSSV Type: 4-72" Baker S-3 Penn Packer Packers and SSSV MD (ft) and TVD (fl)' 7502/7469 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: May 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 , 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Ciolkosz, Ryan R be deviated from without prior written approval. Contact Email: Ryan.Cio1kosz6Dbp.com Authorized Name. Mdaughlin, Sean M Contact Phone: +1 907 564 5977 Authorized Title: Eng neenng Team Lead - CTD Authorized Signature: � Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ I 191 Plug Integrity ❑ BOOP Test Ri ' Mechanical Integrity Test ❑ Location Clearance ❑ Other bOAE7-ZVST 201 2s/11;Z—) ✓�o., a{�P%�/.ce,� RBDMS APR 2 3 Post Initial Injection MIT Req'd? Yes ❑ No ❑— / Spacing Exception Required? Yes ❑ No Id Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL (]p l{'/6p'gAgl Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. ty ,//a ttachments ip Dupl Cat �( i( "IS& ilf 9 019 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz by CTD Engineer Date: April 16, 2019 Re: 11-37 Sundry Approval Request Sundry approval is requested to plug off the 11-37 production as part of the drilling and completing the proposed 11-37A coiled tubing sidetrack. History of 11-37: 11-37 was originally completed in 1996. It is currently producing at 300K GOR and based on the GOR trend could be over 130K GOR in 6 months which will not flow competitively at FS2. Furthermore, a Posiset plug is set with a cement plug on top preventing access below 8710' MD (85507 VDss) in 11-37. 11-37 is considered to have np existing value. The best use of the wellbore is a sidetrack. I <040'r. 117ff "of f v'a/I 16r feor�'// /r/ 9716- 4 i r��lO✓� Proposed plan for 11-37A: /'ecowfi +YV-* 4tf017. a' Vy' Ae 1W Ae A/ 11 The sidetrack 11-37A will be a `2292' horizontal CST that will kick -out from the 11-37 parent in Zone 4B. The CST will establish competitive offtake as a 24P and 22P lateral. The sidetrack will be drilled on or around July 15", 2019. During pre -rig work it is proposed to set a 4-1/2" x 7" Delta whipstock at a kickoff depth of `8570' MD. It is planned to mill the 3.80" window + 10' of rathole with service coil (See window milling addendum attached). The rig will move in, test BOPE and kill the well. The well will drill from Zone 4 to Zone 2 and then remain in Zone 2 for the duration. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" 13Cr solid liner, cemented in place. The cased hole will be logged (GR/CCL/RPM) and selectively perforated. This Sundry Sundry coversolu�ingthe existine11-37oroduction via the liner cementexistine 11-37 production via the liner cement / 0b or liner top if the liner lap test fails (alternate 20 AAC 25 112(i)1or liner too packer, if the liner lap pressure test fails (alternate Plug per 20 AAC 25 112(i)1 The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin May V, 2019) 1. SL Dummy GLMs. MIT -IA. Drift for Whipstock 7 2. EL Set Delta Whipstock. .241 1 3. C Mill XN. Mill Window. r 4. V Pre -CTD Tree work. Rig Work (scheduled to begin July 15"', 2019) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2493 psi). 2. Drill production section: 4.25" O ' —2292'(30 deg DLS build, 12 deg DLS lateral planned). 3. Run 3-1/4" x 2-7/8" 13Cr liner to TO. 4. Pump primary cement job: 58 bbls, 15.3 ppg Class G, TOC at TOL (^'7500' MD)*. 5. Perform Cleanout/Logging run with GR/CCL/RPM. 6. Perforate Wellbore. 2" Millennium guns planned ('600', 6spf, planned). 7. Freeze protect well to a min 2,200' TVDss. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. V: Valve & tree work 2. SL/FB: Set LTP if needed. PT LTP. Set KO GLD. Drift pre CT 3. T: Portable test separator flowback (if perf 500' or more), about 5 days 4. POP well and flow. Ryan Ciolkosz CC: Well File CTD Engineer Joe Lastufka 564-5977 The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EMW of 8.4 ppg KCL (^'471 psi over -balance). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "openhole" a BHA. Disposal: • All Class 1& II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24 hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and 4,000 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "o firewall to shield accumulators and primarycontrols". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: • Maximum H25 reading on DS 11: 825 ppm on 11-01(5/18/16). • Most recent H2S sample on 11-37: 22 ppm (1/23/19) Reservoir Pressure: • The reservoir pressure on 11-37 is expected to be 3373 psi at 8800' TVDSS (7.37 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2492 psi. 1rc t= GIW WELLHEAD = FMCS ACTUATOR= BKR C KR FI FV = 53.5' i SEE F1 EV= BF - 53.5'1 . ELEV - E IDCONDUCTOR, 29.31 NT -13D TERVAL KO. 6971' SQZ2-12' MS/JMD ADPERFS (01117/17) Max Angle = 94' @ 9483' D = 6.164' 05/15/172-12' Datum MD = 9120' _#. - m Datum 8800'SS DONE BK 16 9-5/8' CSG, 40#, L-80 BUTT, 1)=8.835- —{ 38( Minimum ID = 3.726" @ 7646' 4-1/2" HES XN NIPPLE 4-12" TBG, 12.6#, 13CR80 VAM TOP, .0152 bpf, D= 3.958• CSG, 26#, L-80, .0383 bpf, D = 6.276' 7- MARKER JOINT, 29 # 4-12" LNR, 12.6#, L-80 XO TO 13CR-80 NSCT 9262' FFCm 29#. NT-13CR-80 NSC—C—, D = 6.184' 9327' 1 IFORATDN SL#*MRY G: NOT ON D63TH w / MWU EAT TOP PEW: 20• Q 8622' Note: RnducOon 08 for historical pert data SIZE DEV TERVAL dp- SHDT SQZ2-12' MS/JMD ADPERFS (01117/17) 2973 22 - 8632 O 05/15/172-12' 0 09/12111 F26601 43 - 8748 C tC07131105 01/17/173-38' DONE BK 16 09/12/11 58 - 8773 C 03/17/153-38" KBG-2 DONE BK 16 00 - 8808 C 0925/973-38" 1 KBG-2 DIVY BK 12 - 8814 C 07/17/972-78' 7286 20 KBG-2 15 - 8820 C 12/10/013-38" 54 - 8860 C 07/31/05338' 90 - 8898 C 07/31105338' 2 - 8906 C 07/31105 3-38" 6 8918-8926 C 07/31105 3-38' 6 8953-8973 C 08)01/11 338" 6 9160-9165 C 0823197 3318' 4 9291-9292 C 0511087 4-12' SLTD 9293 - 10417 SLOT/C 12/01/96 4-1/r LNR 12.69,13CR-80 NSCT, .0152 bpf, D = 3.958" 11-37 SAFETY NOTES: WELL ANGL.E>70•@9078"" MAX DOGLEG: 14.6•@ 8437' ••` CHROME TBG, LNR, & CSG*" 7 208T ,�4-12' HES X NP, D = 3.813' GAS I FT MAlxlRfi C t 7481' i_44-12' HES X NP, D = 3.81 7502' 7' X4-12'BKR S3 PKR D= 3.875' 7586' 4-12' HES XN NP, D = 3.725 7580' 4-12" WLEG, D = 3.958' 7676' ELM TT LOGGED ON 07/30/05 8710' EST TOC (OS/16/17) 8720'POSBETPLUG(05/15117) 6779' INmwr-LL 363-700 HEX BRIDGE RUC 8990' 9205' 7' X 4-12• TTW SS HOF PKR. D = 3.905' mooed 9262' 4-12' PORTED JOINT(, . 9272' 4'BAKER CBP i M810UT WNOOW(11J7) 9356' DATE REV BY COMMENTS TVD DEV TYPE VLV FORT DATE MS/JMD ADPERFS (01117/17) 2973 5 KB(r2 DMY BK 0 09/12111 F26601 4075 1 KBG2 DONE BK 16 09/12/11 5885 1 KBG-2 DONE BK 16 09/12111 6574 1 KBG-2 DIVY BK 0 04/09105 7286 20 KBG-2 SO BK 22 09/12/11 t 7481' i_44-12' HES X NP, D = 3.81 7502' 7' X4-12'BKR S3 PKR D= 3.875' 7586' 4-12' HES XN NP, D = 3.725 7580' 4-12" WLEG, D = 3.958' 7676' ELM TT LOGGED ON 07/30/05 8710' EST TOC (OS/16/17) 8720'POSBETPLUG(05/15117) 6779' INmwr-LL 363-700 HEX BRIDGE RUC 8990' 9205' 7' X 4-12• TTW SS HOF PKR. D = 3.905' mooed 9262' 4-12' PORTED JOINT(, . 9272' 4'BAKER CBP i M810UT WNOOW(11J7) 9356' DATE REV BY COMMENTS DATE REV BY COMMENTS 12)0196 D-16 ORIGINAL COMPLETION 07/19116 iwbjjmU11SET HEX PLUG (07117116) 04110105 0-16 RWO 01/31/17 MS/JMD ADPERFS (01117/17) 03/17115 CJS/PJC SET CBPl ADPERF 05/17/17 W/JM SETPLUG/CMT&AOPERFS 03/18/15 PJC CSG/ LNR CORREC710N PER TALLY 04116119 NUJMD ELEVATION CORRECTIONS . 0523116 RCTIJMD FISHED BP 05117/16 0620116 WJMD CORRECTED OA GMT -REMOVED J PRUDHOE BAY UNIT WELL 11-37 PERMIT Np:1961740 API No: 50-029-22716-00 SEC 34, T11 N, R15E 4029' FEL & 488, BP Expbratbn (Abskal 28. CORE DATA Conventional Cone(s) Yes ❑ No R1 Sidewall Cores Yes ❑ No 21 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 8621' 6520' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Shublik 8538' 8441' ' Sadlerochit-Zone 4 8621' 8520' CGL - Zone 3 8672' 8568' r Base of CGL -Zone 2C 8748' 8636' 23SB - Zone 2B 8810' 8687' ' 21TS-Zone 2A 8951' 8783' ' Zone I 9047' 8829' TDF - Zone to 9206' 8876' Formation at total depth: Zone to 9206' 8876' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Ciolkosz, Ryan R Authorized Title: nFM ecialist Contact Email: Ryan.Ciolkosz@bp.cem Authorized Signature: Date: 1(�/l Contact Phone: +1 907 564 5977 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. Submit a well schematic diagram with each 10407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the detailsof any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only T/1/0= 2362/2352/106 (LRS -76 Assist SLB SL with load and test MIT -IA) MIT -IA **PASSED** to 2657 psi. (Max 2750 psi, Target 2500 psi) Pumped 2 bbls 50/50 meth spear followed by 165 bbls 100*f crude down IA to load. Pumped 1.4 bbls crude down IA to pressure up well for MIT -IA. 1 st 15mins IA lost 78psi second 15mins lost 9 psi.. Test passed, Bleed IA back to 500psi, bled back — 1.8 bbls. SL rig down off of well. Freeze protected FL with 3 bbls 50/50 and 58 bbls crude. RDMO. AFE sign hung on MV **FLUID PACKED 6/6/2019 ANNULUS**. Tags hung on WV/IA. SSV/Swab/WV=Shut, MV/IA/OA=Open AL=Shut. ***WELL S/I ON ARRIVAL*** (Pre CTD) SET 4-1/2" WHIDDON CATCHER SUB AT 7,560' SLM / 7,568' MD. PULL ST #1 BK-OGLV (7,331' MD) BK-LGLV'S FROM ST #3 (5,912' MD) & ST #4 (4,103' MD) SET BK-DGLV'S IN ST #4 (4,103' MD) & ST #3 (5,912' MD) LRS LOADED IA W/ 165 BBLS CRUDE SET BK-DGLV IN ST#1 (7,331' MD) LRS PERFORMED PASSING MIT -IA (assurance test) DRIFTED W/ 20'x 3.70" DUMMY WHIPSTOCK, 1 3/4" SAMPLE BAILER TO TD @ 8,699' SLM (sticky) LRS FREEZE PROTECTED FLOWLINE 6/6/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** ***JOB STARTED ON 07 -JUNE -2019*** WELL SHUT IN ON ARRIVAL, INITIAL TWO = 2450/550/100. PT LUBE TO 4000 PSI. RIH W/ BAKER 4.5" BY 7" WHIPSTOCK. TOOLSTRING STUCK IN NIP AT 7460'. PULL FREE, HIGH TENSION BOBBLES WHILE POOH. STUCK AT 3630'. LRS PUMP 124 BBL CRUDE, 150 BBL KCL W/ SAFE LUBE, 45 BBL DIESEL FOR FP. BURN ERS AT 3630'. 6/7/2019 ***JOB CONTINUED ON 08 -JUNE -2019*** T/1/0=2290/525/90 Temp=S/I (LRS -76 assist E -line) E -line stuck IH. EL stuck at — 3500' (54 bbls). Pumped 2 bbls 50/50 followed by 124 bbls crude to verify flow past tool string and kill well head pressure. E -line still stuck. Pumped 1 bbl 50/50 and 143 bbls of 1% KCL w/ safe lube down TBG in attempt to free up tool string. Freeze protected TBG with 45 bbls crude. 6/7/2019 ***Continued on 6/8/19 WSR*** ***JOB CONTINUED FROM 07 -JUNE -2019*** RELEASED ERS @ 3599' TOP OF TS, TOWS @ 3630'. POOH. COME TO SURFACE WITH MH -22 AND HALF ERS. RDMO. WELL SHUT IN ON DEPARTURE. FINAL T/l/O = 125/636/235. ***JOB COMPLETE ON 08 -JUNE -2019*** ***LIH @ —3599' TOP OF TS (TOWS @ 3630') = (1-3/8" FN)/ERS/CMIR/CMIR/WPMOT/WPTET/WPGRT/WPST/BKR-10/BKR 4.5" X 7" DELTA 6/8/2019 WHIPSTOCK, OAL = 53', OAW = 685 LB, MAX OD = 3.625"*** ***Continued from 6/7/19 WSR*** E -line OOH. RDMO. EL in control of well upon LRS 6/8/2019 departure. IA/OA=OTG. FWHP=85/600/200 ***WELL S/I ON ARRIVAL SWCP 4518*** (pre ctd) ATTEMPT TO PULL E -LINE TOOL STRING FROM 6610' SLM & MADE 5 RUNS. 6/10/2019 ***CONTINUE WSR TO 6/11/19*** Daily Report of Well Operations PBU 11-37 ***CONTINUE WSR FROM 6/10/19 SWCP 4518***(ctd) MAKE 3 ATTEMPT TO PULL E -LINE TOOL STRING W/.125" C. SWAP TO .160" C. FISH E -LINE TOOL STRING & BAKER SETTING TOOL FROM 5881' SLM WHIPSTOCK STILL IN HOLE oal = 19.31'. MAKE 2 ATTEMPT TO PULL WHIPSTOCK FROM 5926' SLM. 6/11/2019 ***CONTINUE WSR TO 6/12/19*** ***CONTINUE WSR FROM 6/11/19 SWCP 4518***(ctd) MADE 7 ATTEMPTS TO FISH WHIPSTOCK FROM 5926' SLM. RAN KOT & LIB TO ST# 3 @ 5902' SLM FOR A 10' CORRECTION TO 5912' MD. RAN 350" DE -CENT & 3.50" LIB TO TOP OF WHIPSTOCK @ 5921' SLM(5931' MD). 6/12/2019 ***WELL S/I ON DEPARTURE*** ***WELL S/I ON ARRIVAL***(pre ctd) FISHED BKR 4.5" X 7" DELTA WHIPSTOCK FROM 5932' SLM. DRIFTED W/ 20'x 3.70" DMY WHIPSTOCK & S.BAILER TO TOC @ 8703' SLM (no 6/18/2019 sample) ***JOB STARTED ON 02 -AUG -2019*** (SLB ELINE SET WHIPSTOCK) SET 4-1/2" x 7" BAKER DELTA WHIPSTOCK AT 8570' TOWS, 20 DEG LOHS. RIG DOWN LUNE. WELL 8/1 ON DEPARTURE. FINAL T/l/O = 2470/600/150. 8/2/2019 ***JOB COMPLETE ON 02 -AUG -2019*** T/1/0=2200/500/75. Pre CDR2. Set 4" CIW "H" TWC #432 @ 125". RD upper tree. RU CDR 8/3/2019 tree #3, target 90 #5. ***JOB IN PROGRESS***. Seelog for details. Filal WHP's TWC/0/0. T/1/0=2310/550/110. Bleed WHPs to 0 psi (pre CTD). CDR2 tree rigged up. TFL @ 7580' (@ end of TBG, 116 bbls), IA & OA FLs @ near surface. Bled IAP to BT from 550 psi to 0 psi in 15 min (FTS, 0.42 bbls fluid), OAP decreased 10 psi to 100 psi. Bled OAP to BT from 100 psi to 0+ in 35 min (FTS, 0.29 bbls fluid, IAP increased 20 psi. Monitor while rigging down. WHPs unchanged. Final WHPs = 2310/20/0+. 8/4/2019 SV, WV, Upper MV = C. MV = O. IA, OA = OTG. 05:45 T/I/O=TWC/500/50. Pre CDR2. C/O with day crew. PT CDR2 tree #3 to low 300psi and high 5000psi for 5 min ea. Passed. Pull H TWC #432 @125". RU CDR2 test spool #2. Torqued to API spec. PT CDR test spool # 2 to low 300psi and high 5000psi for 5 min ea. Passed. Job 8/4/2019 Complete. See log. Final WHP's 2200/500/50. T/1/0=2310/30/10. Temp = SI. WHPs (post bleed). CDR2 tree installed. TP unchanged, IAP & OAP increased 10 psi overnight. 8/5/2019 SV, WV, Upper MV = C. MV = O. IA, OA = OTG. 05:15 T/I/O = 2320/20/30. Temp = SI. WHPs (post bleed). CDR2 tree installed. TP increased 10 psi, IAP decreased 10 psi & OAP increased 20 psi since 8/05/19. SV, WV, Upper MV = C. MV = O. IA, OA = OTG. 10:30 8/7/2019 North America - ALASKA - BP Page 1 Operation Summary Report Common Well Name: 11-37 AFE No Event Type: RE-ENTER- ONSHORE(RON) Start Date: 8/20/2019 End Date 8/24/2019 H-S4DW0019G5-EX-D1-RN-(1,907,271.00) Project: PBU Site: 17 _-- -- — --_- Rig Name/No.: CDR -2 Spud Daterrime: 11!7/1996 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. lBPUO1: USA00001243 Active datum: KB @53.5Ousft (above Mean Sea Level) - Date From - To Him i Task Code NPT Total Depth Phase _ Description of Operations (usft) ��i 8/12/2019 07:00 - 13:30 6.50 MOB P PRE PRE JOB SAFETY MEETING WITH CREWAND - TRUCK DRIVERS. - EMPHASIS ON GOOD COMMUNICATION, j ! VERIFY STOP COMMAND. • !, ! _ STOP BLOCK IN PLACE TO PREVENT RIG FROM ROLLING BACKWARDS INTO WELL. - -- TREE & CASING VALVES ON TREE SHUT IN. _1 IA, OAAND OOA PRESSURES= O/20/0 PSI - DRILL SITE OPERATOR NOTIFIED AND DECLINED WITNESSING RIG MOVE OFF OF WELL. I- ANYONE CAN STOP THE JOB ATANYTWE. l BE WATCHFUL MOVE PITS AND RIG MODULE OFF WELLAND MOVE TO 11-37A -SPOT MAIN SUB j- REMOVE SOW, INSTALL THE CRAWLER AND SPOT RIG OVER WELL PITSAND SPOT UPTO MAIN SUB 13:30 - 0000 10.50 —!-MOVE MOS P i PRE TRIG IS SPOTTED BUT NOT ACCEPTED, NABORS HAS REQUESTED TIME TO ' REPLACE THE LOWER CHAIN SPROCKETS IN 'BETWEEN WELLSAND THE REQUEST WAS GRANTED. THE RIG WILL BEACCEPTED WHEN THE INJECTOR WORK IS COMPLETED - INJECTOR MAINTENANCE - LTT BOTH MASTERS AND SWAB VALVES TO 3500# - SERVICE TREE VALVES -HOOK UP MPD LINE _I _ - COMPLETE RIG UP CHECKLIST 8/13/2019 0000 - 01:00 1.00 MOB P PRE INJECTOR MAINTENANCE COMPLETE INJECTOR MAINTENANCE AND OPERATE INJECTOR - INSTALL COIL CONNECTOR -PULL TEST TO 50K I REHEAD BHI UQC _ RIGACCEPT 00:00 HRS" ---_ �--._.. 01:00 - 05:30 4.50 BOPSUR P PRE NU BOP'S PJSM -"HOLD RIG EVAC DRILL -3 MIN 14 SEC TO j MUSTER** LTT PERFORMED EARLIER -REMOVE TREE CAP •i'i-INSTALLBOPS I I INSTALL INJECTOR AND CHECK TREE BOLTS j --__ 0530 - 07:00 1.50 BOPSUR P ! PRE 1 PREP TO TEST ROPE - PURGE ALL SURFACE LINES AND COIL WITH I FRESH WATER j - PUMP 2 DISCHARGE PUMP CAP IS LEAKING, j 'BLEED OFFAND TIGHTEN -SHELL TEST IS GOOD Printed 9/5/2019 10:09:15AM "All depths reported in Drillers Depths`" North America - ALASKA - BP Page 2 off. Operation Summary Report Common Well Name. 11-37 APE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 8/20/2019 End Date: 8/24/2019 H-S4DW0019G5-EX-D1-RN- (1,907,271.00 ) Rig Name/No.: CDR -2 Spud Date/Time: 11/7/1996 12:0O:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC, USA00001243 Active datum: KB @53.50usft (above Mean Sea Level) _---L.BPUOI: Date From - To Him Task Code 1 NPT Total Depth Phase Description of Operations (hr) -- --_ r-- Suse> — 07.00 13:30 I 6.50 BOPSUR P I, � PRE TEST 80PE AS PER AOGCC.AND BP GUIDELINES. ALL TESTS TO 250 / 3500 PSI. TEST WITNESS BY WSL AND TOOLPUSHER. WAIVED BY AOGCC REP LOU LAUBENSTEIN j TEST 1: IRV, STRIPPER, C9, C10 BACKWARDS -PASS TEST 2: BLIND/ SHEARS, RI, BLIA, BI, B4 R1 -PASS HAD TO REPURGE SURFACE LINES . j TEST 3: ANNULAR (2-3/8"), TIW41, B3, B2, 'BL1-PASS TEST 4: UPPER 2-3/8" PIPE / SLIP, TIW #2, BL2, R2, T2, C15 - PASS TEST 5: C16, T1, C11 - PASS 'TEST 6: VARIABLES (2-3/8"), C7, C9, C10, TV2 - FAIL, GREASE VALVES 7,9 & 10 RETEST - PASS 'TEST 7: LOWER 2-3/8"PIPE / SLIP, C5, C6, Ce, TVI -PASS TEST 8: CHOKE A, CHOKE C - PASS j PERFORM ACCUMULATOR DRAW DOWN TEST 'INSTALL SAVER SUB TEST 9: ANNULAR (3-1/2") C1, C4 - PASS ___' TEST 10: VARIABLES (3-1/2")_C2, C3 - PASS 1330 - 17:15 3.75 BOPSUR P PRE _ BOP TEST COMPLETED TEST WAS FAIL/PASS, REGREASE ALL 3 VALVES & PASSED - RD TEST EQUIPMENT -GREASE KILL& CHOKE LINE VALVES AND CHOKE MANIFOLD - SWAP OUT LUBRICATOR AND GET RKRS - INSTALL BHI FLOATS, TEST BODY 250/4700 THEN FLOATS TO 3500 PSI - GOOD PT, STAB ON AND DISPLACE COIL TO MUD -PT LUBRICATOR 17:15 - 19:15 2.00 KILLW P 8,570.00 PRE WELL KILL OPS - GOOD PT, LINE UP TO BULLHEAD KILL WELL - ONLINE WITH METHANOL TO THE TT - CLOSE SWAB, OPEN WELL TO A CLOSED CHOKE - WHP = 2331 PSI, ONLINE WITH 10 BELS OF METH, 290 BBLS OF KCL, 10 BBLS HVP, 146 BBLS OF MUD - MAX PRESSURE AT BREAKOVER @ 5 BPM 2780 PSI (55 BBLS OF KCL) IA 700 '.- FINAL INJECTION PRESSURE @ 5 BPM 1946 - PURGE INJECTOR TO TIGER TANK - REDUCE RATE TO 1 BPM TAKING RETURNS TO THE THE TIGER TANK (10 BIBLE) - BRING RETURNS INSIDE WITH A 1 FOR 1 CIRCULATION - 10 MIN FLOW CHECKAT THE ROTARY- ' GOOD NO FLOW - - _ _.. ....II ...... _ ----_ _ ___ - INJECTOR OFF @ 19:15 HRS _ —_-- ri 9:15 - 20:15_ 1.00 9TWHIP P 8,570.00 WEXIT MU WINDOW MILLING BHA PJSM - MU MILLING BHA - INJECTOR ON @ 20:00 HRS -PT QTS TO 3500# Printed 9/5/2019 10:09:15AM **All depths reported in Drillers Depths" North America -ALASKA - BP Page 3 otJ6 Operation Summary Report Common Well Name: 11-37 --- - AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 8/20/2019 End Date: 8/24/2019 H-S4DW0019G5-EX-D1-RN- (1,907,271.00 ) Protect: PBU----- Somite: 11 Rig Name/No.: CDR -2 : Spud Date/Time: 11/7/1996 12:00:OOAM Rig Release: Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00001243 Active datum: KB @53.50usft (above Mean Sea Level) Date From - To I Hrs Task Code NET Total Depth Phase Description of Operations 20.15 - 00:00 3.75 ! STWHIP P 8,570.00 XIT RIH WITH MILLING BHA - RATE BPM 0.521N 0,87 OUT CIRC IPRESSURE 1152 ** HELDAD1 KWT DRILL" iMIN2SECSTO SECURE THE WELL ' - TIE IN FROM 8290' TO 8357' (NO I CORRECTION REQUIRED) 8/14/2019 _-_RIH TO 8460' 00:00 - 01.30 1.50 STWHIP P 8,575.00 WEXIT RIH TO 8563 -RATE BPM 0.521N 0.67 OUT CIRC PRESSURE 1152 '- MUD WEIGHT IN 8.5 PPG OUT 7.7 PPG - TAKE RETURNS TO THE TIGER TANK - BRING RETURN BACK INSIDE -PU 43 SO 27 - RATE BPM IN 1.0 OUT 1.0 - MUD WEIGHT IN 8.5 PPG OUT 8.5 PPG RIH AND LIGHTLY TAG PINCH POINT @ 8575' - OBSERVE NO FLOW AT THE SHAKERS WHILE CLOSING EDC O.r f 01:30 - 16:00 14.50 STWHIP P 8,577.00 WEXIT MILL 3.72" WINDOW PER BAKER REP FROM 8575' MD TO 8580.5' MD - RATE: 2.79 BPM IN, 2.78 BPM OUT - MUD WEIGHT: 8.59 PPG IN, 8.55 PPG OUT - DWOB: 1 -4 KLBS - FREE SPIN 2700 PSI ON BTM 2870 PSI - LOOKS LIKE WE POPPED OUTAT 8580.5' (5.5' WINDOW), WOB DROPPED OFF TO IK AND CONTINUING TO FALL OFF - CALL ODE LET HIM KNOW BUT WE AE STILL GOING TO TIME MILLAS PER PLAN FOR AN 8' WINDOW 8583' AT 8' START MILLING RAT HOLE 8584.6 (WOB AT 349K) j -8586.7 WOB DROPPED OFF TO 1.5K - MILLED RAT HOLE TO 8594', START REAMING PASSES _-REAM PASSES LOOK GOOD, DRY DRIFT 16'.00 - 21:30 i 5.50 STWHIP P 8,594.00 WEXIT TRIPPING OPS - DRY DRIFT IS CLEAN, FLOW CHECKAND - OPEN EDC _ - GOOD NO FLOW, POOH AT MAX RATE li - PERFORM 10 MIN FLOW CHECK. WELL STATIC - LAY DOWN WINDOW MILLING BHA. WINDOW MILL TIGHT 3.71"GO/3.70"NOGG, I2t30 .REAMER 372"GO/3.71 NOGO _ - 00:00 2.50 DRILL P 8,594.00 PRODt RIH WITH 4-1/8' DRILLING BHA#3 j - RATE: 0.69 BPM IN, 0.92 BPM OUT, CIRC PRESSURE: 826 PSI - MUD WEIGHT: 8.51 PPG IN, 8.54 PPG OUT - LOG DOWN FOR TIE-IN FROM 8240' TO 8280' MD (FORMATION) WITH -5' CORRECTION Printed 9/5/2019 10:09:15AM **All depths reported in Drillers Depths** TREE= ' CNV LLHEAD = FMC ACTUATOR= BKRC KB. ELEV= 54' REF ELEV = 53.5' BF. ELEV = 29.31' KOP = 6970' Max Ary- - 94° 9483' Dat9m MD = 9129 Dabm TVD = 8800' SS 7' CSG, 2911, 84' NT13CR-80 NSCC, / D=6.184• #' CONDUCTOR L J 9-5/8', 40#, L-80 BUTT, D = 8.835• H 38 Minimum ID = 3.725" @ 7568' 4-1/2" HES XN NIPPLE 412' TBG, 12.611, 13CR410 VAM TOP, 7580' .0152 bpf, D = 3.958' ' CSG, 26#, L-80, .0383 bpf, 1)= 6276' 8447' 4-12•X 7" DELTA WHIPSTOCK (08f02M9)8� 67� 1 7' MARKER JOf4T.26# (109 1 11-37SAFETY NOTES: WELL MAX DOGLEG 14.6° @ 843x77' E' CHROME TBG,* i LNR, &CSG°°• 2107 4-1/2'HESX NP,D=3.813" GAS LFT MANDRF S HES X NP, D = 3-813- X 4-12' BKR S-3 R(R, D = 12' FES XN NP, D= 3.725" Y -"I YVLC , U= ELM TT LOGGED ( TOP OF 4-1/2• LNR 9206' 1 8990' 7• FES E7SV (04/07/05) 9144' 33/8' BP PUSHED DOWN HOLE (04/05105) 9205' 7• X 412• TIN SS HORQONTAL 12• LNR, 12.6#, L-80 XO TO 13CR-80 NSCT 9262' ST M7 TVD DEV I TYPE VLV LATCH I POR! I DATE 5 2999 2994 5 KBG-2OMY • • 9252' 412• PORD3J JOM (40.49') BK[(0 0 09/12/11 SPF INTERVAL Opn/Sq 4 4101 4096 1 KBG2 DMY BK0 O 06/06/19 08/14/19 2-112" 6 3 5912 5906 1 KBG-2 DMI' BK 3-3/8" 06!06/19 8758 - 8773 C 03/17/15 2 6601 6595 1 KBG-2 DMY BK0 C 04/09/05 ' 33/8" 1 7330 7308 20 KBG-2 DMY BK0 , 06/06/19 - HES X NP, D = 3-813- X 4-12' BKR S-3 R(R, D = 12' FES XN NP, D= 3.725" Y -"I YVLC , U= ELM TT LOGGED ( TOP OF 4-1/2• LNR 9206' 1 8990' 7• FES E7SV (04/07/05) 9144' 33/8' BP PUSHED DOWN HOLE (04/05105) 9205' 7• X 412• TIN SS HORQONTAL 12• LNR, 12.6#, L-80 XO TO 13CR-80 NSCT 9262' REV BY CSG, 29#, NT-13CR-80 NSCC, D = 6.184' 9327' 1291196 PERFORATION SLAM, 05/17/17 NXWIJMD PKR. D = 3.905' REF LOG: NOT ON DEPTH w/ MND D46 RWO ANGLE AT TOP PSiF 20° @ 8622' • • 9252' 412• PORD3J JOM (40.49') Note: Refer to Roduction DB for historical perf data 9272' 4' BAKH2 CBP , SIZE SPF INTERVAL Opn/Sq SHOT SOZ 2-1/2" 6 8622-8632 O 05/15/17 08/14/19 2-112" 6 8743-8748 C 01/17/17 MLLOUT WNDOW (11-37) 9356' 3-3/8" 6 8758 - 8773 C 03/17/15 39/8" 6 8800-8808 C 09/25/97 ' 33/8" 12 8812-8814 C 07/17/97 , 2-7/8" 6 8815-8820 C 12/10/01 33/8" 6 8854-8860 C 07/31/05 33/8" 6 8890-8898 C 07/31/05 ' 33/8" 6 8902-8906 C 07/31/05 33/8" 6 8918-8926 C 07/31/05 3318' 6 8953-8973 C 08/01/11 3X8" 6 9160-9165 C 08123/97 33/8" 4 9291 -9292 C 05/10/97 41/2' SLTDJ 9293 - 10417 SLOT/C 12/01/96 J l NSCT..0152 bpf. D - DATE REV BY COMMENTS DATE REV BY COMMENTS 1291196 0-16 ORIGINALCOMPLETION 05/17/17 NXWIJMD SET PLUG/CMT&ADPERFS 0411095 D46 RWO 04116/19 NL/JMD ELEVATIONCORRECTI NS 03/17/15 CJS/PJC SETCBP/ADPERF 06/11/19 JN1JJMD4 TBG DEPTH CORRECTIONS 03/18/15 PJC CSG/ LNR CORRECTION PER TALLY 06!11/19 GJB/JMD GLV C/O (owmll9) 07/19/16 CJS/JMD SET HEX PLUG 07/17/16 08/14/19 NXWIJMD SET WHIPSTOCK 06/02/19 01/31/17 MS/JMD ADPERFS (01117/17 PRUDHOE BAY UNIT WELL -9111-37 PERM IT No: 11961740 API No: 50-029-22716-00 BP Exploration (Alaska) TFEE= Cw WH.IFEAD= ACfWTOR= _FMC f3KRC -- ----- - KB. AEV = ----- - - 54' BF. B -EV 6 KOP= 6970' M& Angle = 94n @948_7 a KN - 8'48 c Datum TVD = 88W SS 11-37A PROPOSED T CSG, 29#, NT 13CR80 250.^,, D = 6.184' Minimum ID = 3.725" @ 7567' 41/2" HES XN NIPPLE 4-12" TBG, 12.8#, 13CR-80 VAM TOP, .0152 bpf, D = 3.958' 7- CSG, 260, L-80, .0383 bp1, D = 627 3-1/4', 6.5#, TCa, MR -a5 9170' Baker 4-12' 2 T OBTA WFPSTOCK PERFORATION 50MMARY REF LOG: NOT ON DEPTH = I M W D ANGLE AT TOP PERF: 20. 6 8622- 622'r.Rel[r W Prot aclbn Oa Icr lklmkalPerl data ;R.I., tQE tPFI TE.V.L Onitat 1207 SOZ 2-11x' 6 6622 - i6J O OSIIN" 2992 2-ln• a KN - 8'48 c alnnn 1 Ja18- 6 6738 - 9273 c O31,7116 DOME 2-1n• a 8600Ba05 c 091xsro7 5911 Jars- 12 6893-i8H c ontlro7 2-718 6 8815 � 8420 c 2H 0101 12;10A)" 1 KBG-2 3818- a 8864-6860 c o7nfro6 3823- 6 89Yo-6896 c 67n1ros BK 3476- 6 8902 - 8906 c OMims 3-318• a 8918 6926 c 0779 Lbs 0.318' 6 5963-8973 C OBAI/11 3-318• 6 9160- 8166 O 0:133191 3-32' a 9291 - 9293 G 03/10/07 4-112• SLTO 1.293 - 10417 SLOTIC 12MIM6 SAFETY NOTES: WELL ANGLE> 70- @ 9078' --- MAX DOGLEG 14.6- @ 8437"" CHROME TB% LHR, d CSG --- 2072' 4-1 R' FCS X NP, D - 3.813' GAS 1 FT LOA KE AW4 C ST MD I TVQ I DEV/ I TYPE I VLVM1609f12111 07/l9/16GIS/,AID SET HD(FLUG(07117/16) 070 84116 M16 FWO 5 2998 2992 5 KBO -2 DW CSG/ LTR MR11,TpN PER TALLY 1 4 4101 4095 1 KBG-2 DOME 13 5911 5905 1 KBG-2 DOME 12 6601 6595 1 KBG-2 OW 51 7330 7307 20 KBG-2 S0 BK 22 71 3.873' 3.875' 7550' J-13-12' X f�LE 7567 4-12' HES XN NP. D = 3.725' � 767$• �—j4-12' WI.EG, D=3.058' 7b76' 9-M TT LOGG®ON 07/3405 2-7/e', 6.5#, STL, 13CR-85 —, 10881' DATE I fall/ BY I COWAENTS I DkTE NEN SY COWENTS 120"66 MIS OWG7WIL COMPLETION 07/l9/16GIS/,AID SET HD(FLUG(07117/16) 070 84116 M16 FWO 1/31/17 MSIJMQ ADF61FS(01117/17) 03/17/15 CJS/ P SET CEA ADUW 05/17/17 SET PLUGKW 8 ADFERFS 03/16/15 PJC CSG/ LTR MR11,TpN PER TALLY 05123116 RCT] flSF�BP(OS!17/16) I 0620/16 F7M',A9U coRF CTEDOACMT-F7HS FD 4YSi�i PRLCHDE9AY UHT WELL' 11-37 PEFUT W:'1961740 AFI W: 50-02122716-00 SE; 34, TI IN, R15E� 4029' FEL 8 48W FFL BP eAp wMio (Alaska) Well Bighole Quick Test Sub to Otis Top of 7" Otis Distances from top of riser Excluding quick -test sub Top of Annular Top of Annular Element 6.7ft Bottom Annular B.Oft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips a1 Kill Line CDR2-AC 4 Ram BOP Schematic Date 21-Nov17 -- — —— -- --- CL 2-3/8" x 3-1/2 VBRs 12.fi ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab CL of Flow Cross CL of Master LDS LDS Ground Level f-- 7-1116' 6k Flange x 7' @ic Boa -- Swab � Master Choke Line Test Pump Hose Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of"Suspended." Ste Task Res onsible 1, The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed the initial Geologist work) reviewer will cross out that erroneous entry and initial then v1 it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engin6ers will serve as quality control for steps I and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz CTD Engineer Date: April 16, 2019 Re: 11-37A Permit to Drill Request 11 ' /s' Z p *Of1%` Approval is requested for a permit to drill a CTD sidetrack lateral from well 11-37 with the Nabors CDR2 Coiled Tubing Drilling rig on or around July V, 2019. Proposed plan for 11-37A: The sidetrack 11-37A will be a 2292' horizontal CST that will kick -out from the 11-37 parent in Zone 4B. The CST will establish competitive offtake as a 24P and 22P lateral. The sidetrack will be drilled on or around July 15th, 2019. During pre -rig work it is proposed to set a 4-1/2" x 7" Delta whipstock at a kickoff depth of `8570' MD. It is planned to mill the 3.80" window+ 10' of rathole with service coil (See window milling addendum attached). The rig will move in, test HOPE and kill the well. The well will drill from Zone 4 to Zone 2 and then remain in Zone 2 for the duration. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" 13Cr solid liner, cemented in place. The cased hole will be logged (GR/CCL/RPM) and selectively perforated. Pre -Rig Work (scheduled to begin May V, 2019) 1. SL Dummy GLMs. MIT -IA. Drift for Whipstock 2. EL Set Delta Whipstock. 3. C Mill XN. Mill Window. 4. V Pre -CTD Tree work. Rig Work (scheduled to begin July 151h, 2019) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2493 psi). 2. Drill production section: 4.25" OH, —2292'(30 deg DLS build, 12 deg DLS lateral planned). 3. Run 3-1/4" x 2-7/8" 13Cr liner to TD. 4. Pump primary cement job: 58 bbls, 15.3 ppg Class G, TOC at TOL (`7500' MD)*. S. Perform Cleanout/Logging run with GR/CCL/RPM. 6. Perforate Wellbore. 2" Millennium guns planned ("600', 6spf, planned). 7. Freeze protect well to a min 2,200' TVDss. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. V: Valve & tree work 2. SL/FB: Set LTP if needed. PT LTP. Set KO GLD. Drift pre CT 3. T: Portable test separator flowback (if perf 500' or more), about 5 days 4. POP well and flow. The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EMW of 8.4 ppg KCL (^'471 psi over -balance). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "openhole" a BHA. Disposal: • All Class 1& II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24 hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and 4,000 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "o firewall to shield accumulators and primary controls". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: • Maximum H2S reading on DS 11: 825 ppm on 11-01 (5/18/16). • Most recent H2S sample on 11-37: 22 ppm (1/23/19) Reservoir Pressure: • The reservoir pressure on 11-37 is expected to be 3373 psi at 8800' TVDSS (7.37 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2492 psi. er. eLeV = z KOP = 6970' Max Alvie = 94-@9483"11 Datum MD= 9120' Da0#n ND= 8800'SS 14-112" Nf-13 D - 8.184' #, CONDUCTOR, n_ Minimum ID = 3.725' @ 7646' 4-112" HES XN NIPPLE 1.4-12" TBG, 12.6#, 13CR80 0152 bpf, D = 3.956" T CSG. 269. L-80. 0383 bof_ 29 # NSCC, D=6.184' PERFORATION SUMMARY FEF LOG: NOT ON DEPTH w/ MWD ANGLEATTOP PHRF:20' Q 8622' Nota: Refer to P oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 2-12" 6 8622 -8632 O 05/15/17 KBG-2 2-12" 6 8743 -8748 C 01/17/17 4075 3-38" 6 8758-8773 C 03/17/15 3-38" 6 6800 - WDII C 09125197 338" 12 8812-8814 C 07/17197 KBG-2 2-78" 6 8815-8820 C 12110)01 7288 338" 6 8854 -8860 C 07/31105 3-38" 6 8890-8898 C 07731105 3-38" 6 8902-8906 C 07/31/05 3-38" 6 8918-8926 C 07/31105 3-3/8" 6 8953-8973 C 06)01/11 338" 6 9160-9165 C 0623/97 3-3/8" 4 9291-9292 C 05/10197 4-12" SLTD 9293 - 10417 SLOT/C 12/01/96 12.6#,13CR-80 NSCT, .0152 bpf, D = 3.958" 11-37 SAFETY NOTES: W ELL ANGLE> 70° @ 9078' •`• MAX DOGLEG: 14.6° @ 8437'*** CHROME TBG, LNR, & CSG*'* 208T 4-12-HESXNP,D=3.813' GAS LFT MANDRELS ST ND ND DEV TYPE VLV3BKO 01/31/17 DATE 5 2999 2973 5 KBG-2 DMT7' 052316 RCT/JMD FISHED BP 05/17/16 09/12/114 4111 4075 1 KOG-2 DOME 09/12/113 5912 5885 1 KBG-2 DONE 09/121112 6601 6574 1 KBG-2 DMN 04/19/051 7330 7288 20 KBG-2 SO 09/12/11 7481' 4-12' HES X NP, ID = 3.813" 7502' 7" X4-12" BKR S3 RCF; D= 3.875' 7588' 4-12" HES XN NP, D = 3.725" 7597 4-12" WLEG, D = 3.958" 7578' —�M TT LOGGED ON 07/30/05 I 9205' I 363-700 HB( BRIDGE PLUG k1RFl:3i :19:a.97_1LZipul.:7 �_ � T71• D = 3.905" MLLOUT WINDOW (11-37) 9356' DATE REV BY COMMENTS DATE REV BY F COMMENTS 1210196 D46 ORKUNAL COMPLETION 07/19/16 CJS/JMDSETHEX PLUG (07/17/16) 041095 D46 RIND 01/31/17 MS/JMD ADPERFS (01/17/17) 03/17/15 GJS/PJC SETCBP/ADPERF 0517/17 WV/JM SET PLUG/CMT B ADPERFS 03/18/15 PJC GSGf LNR CORRECTION PER TALLY 04116119 JNIJJMD ELEVATDNCOfRRECTDNS 052316 RCT/JMD FISHED BP 05/17/16 062416CWJMD CORRECTED OA CMr-REMOVED PRUDHOE BAY UNIT WELL: 11-37 PERMR No: X961740 API No: 50-029-22716-00 T71 N, RI 5E, 4029' FEL 8 488, SP Exploration (Alaska) TREE= cwv 11-37A PROPOSED WELLHEAD= FMC ACTUATOR= HKRC KB. 9F/ or 54' BF. EEV = ••22-:6132 O 05113117 KOP= 6970' Max Angle = 94' @ 9483' Dat1#nLD= 9120' Datum ND= 9800' SS W-13CR-80 NSOC, D= 6.184' #, CONDUCTOR D- 9-5/8' CSG, 40#, L-80 BUTT, D- 8.835' I—t 3809' Minimum ID = 3.725" @ 7567' 41/2" HES XN NIPPLE 4 -1/2 -TBG, 126R. 13CR-80 VAM TOP, .0152 bp1. D= 3.958• 26#, L-80, .0383 bp1, D = 3.1/4, 6.54, TCI, 13CR-05 917W Baker 4-1/2' x T DELTA VN�PBTOCK 8670' PERFORATOR SUMMARY REF LOO: kOT ON DEPTH e / M W D A MOLE A T IOP PERF: x0.0 9632• Norc Refer M ProCacUan DU ler Sw"rkel Pod Oe+a SME SPF MTERVAL 10,oiSqt SHOT SO2 2-+n' 6 ••22-:6132 O 05113117 5 29% 2-v2- a 9693-eIn c DW 3-31e• a :,If ;1,7 758 8728 c Oa1:ns 4 4101 3-3161- 6 9800-$80e c 00,35,07 DONE 3-an•96 12•16 1 cc 07/17,07 3 5911 2-7 • 1 :::1 u. 9320 noro+ u DONE 3-596• 6 9959 - 8960 c 07n+ros 2 6601 3-310 • ••90 - Uo8 c 07,3+,05 DMY Sore• s uo2 - 9309 c o7nvos 1 7330 San• 8 :908 - U2a c 07191,05 SO San• 6 9963-6973 O 0:0111+ San- s 9160-9' c 03,33,07 3-319• 4 929+ - 9292 O Os11oroi 41 n• sLTo 9293 1041 SwT. 02,3+,3: SAFETY NOTES: WELL ANGLE > 70• @ 9078' »• MAX DOGLEG: 14.6• @ 6437' •e• CHROME TBG, LNR, & CSG '•` GAS LFT MAN42B_S ST MD IND I DEV I TYPE I VLV KTCI POREI DATE 5 29% 2992 5 K3G-2 DW SK 0 09112/11 4 4101 4095 1 KBG-2 DONE BK 16 09112/11 3 5911 5905 1 KBG-2 DONE BK 16 09112/11 109112(11 2 6601 6595 1 KBG-2 DMY BK 0 04/0910.5 1 7330 7307 20 KBCa2 SO BK 22 IT X 4.10 BKR S-3 PKR D= 3.875- 3.70- DEPOY SLEEVE 5-300' 7550' 113117 X NPPLE 7576' ELM TT LOGGED ON 07!30/05 2-7/6-.6.54, STL, 13CR -85 DATE REV BY COMMENTS DATE REV BY COM9BdTS 1210196 D-16 ORIGINAL COMPLETION 07/19/16 CJSIJMJ SET HEC PLUG (07/17116) 0411OMS 0-16 R8NO 01/31/17 R&JbD ADPBWS (01/17/17) 03/17/15CI&RICSETCBRADPERF 05/17/17 NWAC SET PLUG/CMT & ADPERFS 03/18/15 PJC CSG LPR CORwcnON PER TALLY 0523116 RCTIM FISFED IBP (05(17116) 0620!16 RMJMJ COIWECTED CA CMT -REMDVRD PRdDHOE BAY CRIT WELL '11-37 PSW IT ND: '1961740 AHI ND: 50.029-22716-00 SEC 34, T1 IN, R15E 4029 FEL & 4884' FPL BP Exploration (Alaska) Well Bighole Quick Test Sub to Otis Top of 7" Otis Distances from top of riser Excluding quick -test sub Top of Annular CDR2-AC 4 Ram BOP Schematic Date 21 -Nov -17 0.0 ft .---.—.—.—.—.—.—.—�.—.—.—.—.—. Hydril 7111 Top of Annular Element 6.7ft AnnularCL Blind/ShearsCL 4AnnularBottom 2-318" Pipe/SlipsBi Kill Line r--T:In CL2-3/8"x3-,/T"VBRs ,2.6ft CL 2-318" Pipe/Slips Rig's Dnp Pan 7-1116" 6k Flange x T' Dtis Boa CL of Top Swab F— Swab ar T, CL of Flow Cross 17.4 ft � Master CL of Master 18.8 ft LDS IA OA LDS O Ground Level T2 Test Pump Hose • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate I21 Other Stimulate 0 Alter Casing 0 Change Approved Program ��-❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: $e -p 5/, 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 196-174 �V'./ .4" 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 ' AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22716-00-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 11-37 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: Total Depth: measured 10440 feet Plugs measured See Attachment feet JUN 1 true vertical 8858 feet Junk 9144 feet JUN5 7011 7 measured AOGCC Effective Depth: measured 8720 feet Packer measured 7503 feet true vertical 8612 feet Packer true vertical 7469.63 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 27-107 27-107 1490 470 Surface 3783 9-5/8"40#L-80 26-3808 26-3803 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1235 4-1/2"12.6#L-80 9205-10439 8876-8858 8430 7500 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet SCM4NED JUL 2 5 2017, Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 22-7580 22-7542 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 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: 40 12846 5579 1238 282 Subsequent to operation: 771 52259 0 1881 1111 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development IO. Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Chamansingh,Ann Marie Contact Name: Chamansingh,Ann Marie Authorized Title: Petroleum Engineer h Contact Email: AnnMarie.Chamansingh@bp.co Authorized Signature: �f1G CI ... - j... Date: (`t Contact Phone: +1 9075644070 1-,e �/, o ,S \, JUN Form 10-404 Revised 04/2017 ���L- i �� RB®I�fl� v J�„ 2 6 2617 Submit Original Only • • RECEIVED JUN 15 2017 AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary June 14, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug with Cement Cap and Addition of Perforations for Well 11-37, PTD # 196-174. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Plugs Attachment PBU 11-37 SW Name Date MD Description 11-37 05/16/2017 8720 PosiSet Plug w/Cement on Top 11-37 07/17/2016 8779 7" HEX PLUG 11-37 04/07/2005 8990 7" HES EZSV 11-37 05/08/1997 9272 4-1/2" CIBP • • m Q,o00000000 CU N. CA N N r- N O O O O O Cr O U) LO V N.- tn. 0 0 0 0 0 0 0 0 0 L CA LL) CD Cr CO CC CO M M 7 Ct N- N '- N Cr V m c- O O N- 00 N- 00 00 CO N.. M N O M 00 N co Cfl M CO CD 00 00 C() M CO 00 CO 00 CO N N O M CD N- CD Cf co U) Cr U) N- N N NNCflMOCOON 00 00 00 O O NO OM CrUDCODNC Up MTr rs O co Tr no CD CO(00 00 00 C)) N- VCI i i i i i , i i Q M CD Cr M Tr O COO O N 0r NNNCID TrNNCNN _ M CDCD CE! 00oo0ootpV Nr °Qa000 � c0OD J d itMMMMM (D4# 'N N if) O y- T- '- ' N CD N 0)cn 60 0) CSO 0) (0 d0 ) : (Ni UN N N N N N _ N (� F- I-- 7 --- NI- 7 L .6. M M to CO J W W W W W ct I— Q Q Q Q _ W 0 0 0 0 0 _ Q W W W W W W cn < 22222 C9 Z c W W W W W W m O � HHHI- HZ � o Z Z Z Z Z J I_ • m m T- CD CO r` M Tr O) N CD N r` OLU L r` c- Ch UP M CD N Tt N Tr CO r` CO N O) p. OCO r` LC) O Ti N Ti O LU N- TT O N r` al M co LU OO CD CA N N LU O CD O) O 0 LU G OD CO CO 00 CO CO CO Ns OD 0 CO CO Ps Ns O OOD 0 03 00 a O 1- CD N ct CO CO CO Tr O) c- LC) CD CD st LO r� y M CO N Cr) r` Cr A N O CO C N- N co CA 0. 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CY) N- OT- N LO CD CA O N r- CD J J a a u) Z d' a, CD N- N- OOOOOOO) CDCD CV 0 0 0 W W 0 J C7 C) CO CO CO CO CO CO CO CO CO CO CO CO CD CD Z Z Z O J J 0 J LNa Q Q < = 0 0 0- U10- < < wa 000 W w Z W W W a O 01- 0 M2220C~nai ccoccoco Q a C « N C'r) CO 0 N Tr V' N- O N CO Cr) 0 0 Cr) aN LC) O - - to LL7 CD O — LCA CONCH 0 M d CO N- r` CO CO CO CO CO CO 0 C D CD e- N N ,L W CO 0 0 0 0 CO 0 CO CO 0 0 CO CD CA CD COC L N 2 2 2 0 u~) c~i) cai) C,)) Cn a) a. 0 O mCL CL CL CL CL aCL aCL CL aCL CL CL a Q030303 03 03 mmmmmmmmm a O t a, a a> I- 0 0 c000000000000000 LU O N CV N N CV CV N N N CV N CV CV N N Z W < 1I w LC) LC) LC) LC) LO LC) LC) LO LO LC) LC) LC) LO LC) LC) a w 0 U W a WLL a W a LU LO LC) LC) In 1.0 LO LO LO LC) LC) LU In LU LC) < 0 J I- J J D J D a' a J J Q < < a Cl) LL t n LL C a cC a) C7 Ch C7 C7 M C7 C7 M M Cr) CO Cr) Cr) Cr) M N LL a co O tL N m LL J u LL Ci) CLcan a m co • • • Packers and SSV's Attachment PBU 11-37 SW Name Type MD TVD Depscription 11-37 TBG PACKER 7502.58 7469.63 4-1/2" Baker S-3 Perm Packer 11-37 PACKER 9204.56 8875.95 4-1/2"TIW SS Horiz Packer 0 • o ¥ ce _a / 0 US US / k E .in / v _ > / � 2 mI o & / 3 � 2 2 0 \ o 8 �� ., < 7 $ o / = I Ce | E > W b O 0 D to co CL a cc w E O CO D / / 2 z � e , �\ _JC K 0 0 > C > " % x = d « 0 0 ƒ / o >- y o _ L ■ I - _ & ƒ I ® k ' a. 6 CL ;4- & @ E co o u_ E = 0 e ¥ L E ■ © 7ED ~ E � 0 � 5 b �� c•1 U)/ � � O � / /0. / / / � E § 2 ƒ 2 ƒ / 3w = 5 = el cx � � � � 2 % $ u.:(f) 2220 _ ƒ 0 ,- -oZ -w Sujco ? $ � 200I 2 E » 2 * co ƒ $ � , c / _1 U_ Ce ~ o f n & % _ % CD \ H O A L o O $ ‘- 14.• CO \ k2 � � 2 \ -'77f \ � 7G � � co < : U) ƒ � k7 ƒ o � U \ / ari / ; g q _ D 2 a) u_ < e _ . I w a a. $ > Hu52 k / �� � �en / / DUa � W R woo = • c \ » 2 CI E , uER bq § / 2a / & CLbirrW \ L « $ % � < ua ¥ @ « � .. � rCO -I � = 2 0 aZCLOF « p � L = - -I222 2 _ � o_ ma .U) - 120 >< / F)< moOk E 7 > 2 n 2 2 = n - 9 b « 0 0 ? b n = 0 @ _1 mZ � x & _, = o e _1 1- 2 .- 2 0_ # 2 o 0 _i 0_ 2L@a . ® _I —Iw , _I � � _ , $ cn u = fgl -& �� 22u < 2 � uk � � � 2S � � Uf2 / / - 2 / < b / 2 - \ / K - b - w - - \ < R $ m 2 : f : : w c ! A v- < : a w a rem 2 2 < O : O - 2 0 O L a ¥ ¥ N. N. F- - - d 2 .- / n % / \CO Lr) = n q # \ / « TREE=1, aw IIII r WHIHFAD= FMC 11 -37 -.111Pry NOTES: WELL ANGLE>70°@9078'*** ACTUATOR= BKR C MAX DOGLEG:14.6*@ 8437 ***CHROME TBG, KB.BEV= 54' 64 7"CSG 29# --1 ' 30.cx LNR,&CSG*** BF.fl.EV= NT-13CR-80 NSCC, ./J KOP= 6970" ID=6.184" 2087' _14-112"HES X NP,D=3.813" Max Angle= 94°@ 9483' I I — Datum IVI3= 9120' _#,CONDUCTOR H ? Datum ND= 8800'SS _ GAS LFT MANDRELS D= " ST MD ND DEV TYPE VLV ATC PORT DATE 5 2978 2973 5 KBG-2 DMY BK 0 09/12/11 9-5/8"CSG,40#,L-80 BUTT,D=8.835" — 3809' 4 4081 4075 1 KBG-2 DOME BK 16 09/12/11 L 3 5890 5885 1 KBG-2 DOME BK 16 09/12/11 2 6580 6574 1 KBG-2 CMY BK 0 04/09/05 Minimum ID =3.725" @ 7546' 1 7309 7288 20 KBG-2 SO BK 22 09/12/11 4-1/2" HES XN NIPPLE ' 7460' _14-1/2"HES X NP,D=3.813" Z 1K 7481' _-17"X 4-1/2"BKR S-3 PKR D=3.875" I I 7546' H4-1/2"HES XN NP,D=3.725" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, — 7558' 0152 bpf,D=3.958" / ‘ 7558' H 4-1/2"WLEG,ID=3.958" 7"CSG,26#,L-80,.0383 bpf,D=6.276" —{ 8447' I--x x 7576' —{ELM TT LOGGED ON 07/30/05 0 8710' j—j T TOC(05/16/17)I 1 8720' [POSISET PLUG(05/15/17) 7"MARKB2 JONT,26#(10') —I 8759' HED 9 7'MARKER JOINT,29#(20') H 8769' 8779' —NTERWELL 363-700 HDC BRIDGE PLUG 110111."-6014111110111."-6014111 (07/17/16) D TOP OF 4-1/2"UR — 9205' —I 8990' H 7"HES EZSV(04/07/05) 4-1/2 LIC, 12.6#,L-80 XO TO 13CR-80 NSCT 9252' ilk 9144' H 3-3/8"IBP PUSHED DOWN HOLE(04/05/05) 17 CSG,29# NT-13CR 80 NSCC D=6.184" 1-1 9327' 0 9205' —7"X 4-1/2"11W SS HORIZONTAL PERFORATION SUMMARY PKR,I)=3.905" REF LOG: NOT ON DEPTH w/MVVD ANGLE AT TOP PERF:20'@ 8622' i,6 SO8 9252' —{4-112'F ORTE)JONi(40.49') Note:Refer to Production DB for historical perf data 1 = --I 9272' H4"BAKER CSP SCE SPF INTERVAL Opn/Sqz SHOT SQZ , 2-1/2" 6 8622-8632 0 05/15/17 ' 2-1/2" 6 8743-8748 C 01/17/17 ILMLLOUT WINDOW(11-37) 9356' 3-3/8" 6 8758-8773 C 03/17/15 3-3/8" 6 8800-8808 C 09/25/97 3-3/8" 12 8812-8814 C 07/17/97 , 2-7/8" 6 8815-8820 C 12/10/01 ' 3-3/8" 6 8854-8860 C 07/31/05 3-3/8" 6 8890-8898 C 07/31/05 3-3/8" 6 8902-8906 C 07/31/05 3-3/8" 6 8918-8926 C 07/31/05 3-3/8" 6 8953-8973 C 08/01/11 3-3/8" 6 9160-9165 C 08/23/97 3-3/8" 4 9291 -9292 C 05/10/97 4-1/2" SLTD 9293-10417 SLOT/C 12/01/96 4-1/2"LNR,12.6#,13CR-80 NSCT, .0152 bpf,D=3.958" —{ 10440' ___A_____k DATE REV BY COMVENTS DATE REV BY COMMENTS PRWHOE BAY UMT 12/01/96 D-16 ORIGINAL COMPLETION 07/19/16 CJS/JM)SET HEX PLUG(07/17/16) WELL:91-37 04/10/05 D-16 RWO 01/31/17 MS/JMD ADPERFS(01/17/17) P82MT No:'1961740 03/17/15 CJS/PJC SET CEP/ADPERF 05/17/17_NXW/JMC SET PLUG/CMT&ADFERFS API No. 50-029-22716-00 03/18/15 PJC CSG/LNR CORRECTION PER TALLY SEC 34,T11 N,R15E 4029'FEL&4884'FM. 05/23/16 RCT/JMD FSH BP(05/17/16) 06/20/16 MAD CORREC1137OA CMT-REMOVED BP Exploration(Alaska) • STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 196-174 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22716-00-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PRUDHOE BAY UNIT 11-37 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: „, Total Depth: measured 10440 feet Plugs measured See Attachment feet f1 true vertical 8858 feet Junk measured 9144 feet FEB 0 6 7017 Effective Depth: measured 8779 feet Packer measured 7503 feet ,� true vertical 8662 feet Packer true vertical 7469.63 feet l,.,Al Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20”91.5#H-40 27-107 27-107 1490 .470 Surface 3783 9-5/8"40#L-80 26-3808 26-3803 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1235 4-1/2"12.6#L-80 9205-10439 8876-8858 8430 7500 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 22-7580 22-7542 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED MAR 0 3 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 16 9519 2653 1258 769 Subsequent to operation: 1 0 2785 1858 746 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 2/3/17 Form 10-404 Revised 5/2015 ®B®M C - n 17 Submit Original Only • • Plugs Attachment PRUDHOE BAY UNIT 11-37 SW Name Date MD Description 11-37 07/17/2016 8779 7" HEX PLUG 11-37 04/07/2005 8990 7" HES EZSV 11-37 06/20/1998 8857 Sand Plug 11-37 05/08/1997 9272 4-1/2" CIBP • • CD Q 0 0 0 0 0 0 0 0 o o . o ;r LO0 0 CO ti LO LO V-- N.- U N 0 0 0 0 0 0 0 0 0 ▪ a) L) (0 't (0 V COC") () 7 't f- '- N A- N A- V V Ca LO co Co CO CO CO CO N LO CO CO N O co LO LO O) LC) CO CO CO CO CO CO CO LO CO CO CO CO CO CO I- H N LC) CO CO I- O CO LO d Lf) N- N N N N CO CO CO CO CO N CO co co co M co c o N- LCOO o CNO M CO E - wcovNr• coN. Lx, co co co co a) N- I I 1 I 1 1 I 1 4.4 Z < N.-- CO CO LO N- CO CO V LO CO O N C)>- N N N O • CO CO C N = IC( W O O O O O O O O O co 2 J 00 CO 00 e9 CO CO J L L L L co C = N CSO D M CC j M CC j CSO V te Ca, rn � � O -a N N N N N nJ 4 t co co LO CO — tgi O 00 (A CO N co in • CO N- CO CO C5-"° Lf) a) c) CO ch L t` J W W W W W H H H H H OlO Q Q Q Q Q C H W D D D D D .N U U U D cccCCCCZ LL Z c W W W W W W �p O D H H H H H Z O z Z Z Z Z .J H • • a) N t0 m CO cor-- M -sr O N CO Na- ,- ,- CO CO CO O N N CO N- ' N (3) p, CO N- U7 O N V O U) d' 10 N N- a) co U) co O O) N N U) LC) (D 0) CO U) 0 CD CO CO CO CO N- N- N- N- N- N- CO CO 0 CO CO CO CO CO 00 CO CO CO CO CO CO CO > H Q 0 N V CO CO CO Nr O r U) CO (0 V U3 1"-- .0 �. CO N- CO N- CO a- N 0 CO 61 N- N CO CA a) co N- 06 00 C3) ON N 'Cr LNC) CO 00 CO 06 yi N CO06 UW " 1 1) CO (O CO CO N- N- N- N- N- N- CO CO CO > p C70 0O 00 COCO00 00 00 00 00 OD 10 CO 00 0 H W 0 O• 0 z w w pW o 0 a) ¢ ~ U > U) J g 0 m 0 0 0 W Y Y H ~ . CO CO CO t O N- O CO CO CO CO U) O N- J J J < Q N w tY •l • M p_ N- C) N 10 CD O C) N N- CO V Q Q Q W a a z a) N- N- CO CO CO CO CO CO 0) (3) (3) ' N 0 _U _0 0_ J W W O J 0 r 0 CO CO CO CO CO CO CO CO CO CO CO O) O 2 Z Z O J J J p J r m Q Q Q = 0 0 a w ff �_ 2 0 0 0 W d d Z Q Z Z 2 2 2 0 u w UQ) co caf) CO 4-0 0 C F- "•41. M CO O N N- O N 00 M O O co co .5. U) O U) U) C3) O U) CO N C7) O N- N- 00 0O 00 00 00 00 C3) CA C3) c- N N LL 00 00 co 00 OO co co co 00 co w 03 C3) O co ami O I Nr _� U O CO NY 2 2 2 0 v) v~) can (Ji) vai M ate ) Ct. O U .2 c LL_ LL_ (AU) W C/) (F) Cl) (I) Cl) Cl) Ci) (I) (I) is o_ ddo_ ddo_ dNldddd � Q < m m m m m m m m m m m m 0. O t a) a d I- is N- U) CO CO CO CO CO COCO CO CO CO CD CO O O r- r- 0 C 0 0 CD CD 0 0 0 0 0 0 0 0 0 0 W z O N N N N N N N N N N N N N N Z w < w W LL W N N LL . . . . . I` f` ~ � r 0 W O U _Li W y . . . . Z a JW W w W • a M N- t` ti ti ti r Q 0 J H J J D J D CY a O m 0 D W —) -I D Q O W W Q Q a U) LL. LL 'n L.L. co a fY a) E • N- N- N- N- N- N- N- N- r-- CO - M CO Cr) CO CO CO CO CO CO CO Cr) M co co N i i i i i i i i LL a c) O w N a' a = = = = = = = c- rm a a a O J O 0 W Q Q CO 03 w i Cn CT) a tY • • Packers and SSV's Attachment PRUDHOE BAY UNIT 11-37 SW Name Type MD TVD Depscription 11-37 TBG PACKER 7502.58 7469.63 4-1/2" Baker S-3 Perm Packer 11-37 PACKER 9204.56 8875.95 4-1/2"TIW SS Horiz Packer I 6 ± m I E 0 ± a c U- I m e a L a 0 -J oz CD \ 0CD o O m ? E ® 6 c / 2 » R 2 U) 117 3 0 - & ± - A U /111 \ / Ef \ 0 n_ 0- 2 © . / _i J * / \ \ \ / 0 E \ 2 / 7 \ / / ƒ / i < f _ 02 / / � II \ a) E / C 0 2 E l i \ O c / R a- z ƒ \ 0z - /S I ' / ƒ O 0 < O / CY ƒ E / / k\ / L ar- C m \ co Q 2 U IIdL= • CNV WELLHEAD= FMC 11 -37 7 SAFETY NOTES: WELL ANGLE>70-@ 9078'*** ACTUATOR= BKRC ��// MAX DOGLEG:14.6^@ 8437'***CHROME TBG, KB.ELEV= 54' 7"CSG,29#, 64' LNR,&CSG*** Hx BF. ELEV= KOP= 6970' NT-13CR 80 NSCC, Max Angle= 94 @ 9483' =6.184' 2087' 4-112"HES X NP,D=3.813" Datum MD= 9120' _#,CONDUCTOR -I ? Datum TVD= 8800'SS GAS LFT MANS D= " ST MD TVD DEV TYFE VLV ATC PORT DATE 5 2978 2973 5 KBG-2 CAN BK 0 09/12/11 9-5/8"CSG,40#,L-80 BUTT,D=8.835"A-3809' 4 4081 4075 1 KBG-2 DOME BK 16 09/12/11 3 5890 5885 1 KBG-2 DOME BK 16 09/12/11 2 6580 6574 1 KBG-2 CMY BK 0 04/09/05 Minimum ID = 3.725" @ 7546' 1 7309 7288 20 KBG-2 SO BK 22 09/12/11 4-1/2" HES XN NIPPLE ' 7460' _14-1/2"HES XNIP,D=3.813" 7481' H7"X 4-1/2"BKR S-3 PKR D=3.875" 7546' -14-1/2"HES XN NP,ID=3.725" 4-112'TBG, 12.6#,13CR-80 VAM TOP, - 7558' 0152 bpf D=3.958" 7558' -{4-1/2 WLEG,ID=3.958" 7"CSG,26#,L-80,.0383 bpf,ID=6.276" -i 8447' }—x x 7576' HELM TT LOGGED ON 07/30/05 7"MARKER JOINT,26#(10') -i 8759' --lb U 7"MARKER JOINT,29#(20') H 8769' —lb 0111.'14111118779' -INTER/ELL 363-700 HEX BRIDGE PLUG (07/17/16) 8990' H7"FES EZSV(04/07/05) TOP OF 4-1/2"LNR - 9205' 1141 4-1/2"LNR 12.6#,L-80 XO TO 13CR-80 NSCT 9252' ilk 9144' H3-3/8"IBP PUSHED DOWN HOLE(04/05/05) 7"CSG,29#,NT-13CR-80 NSCC,ID=6.184" - 9327' 9205' -7"X 4-1/2"TM/SS HORIZONTAL PERFORATION SUMMARY PKR,D=3.905" REF LOG: NOT ON DEPTH w/MWD ANGLE AT TOP PERE 30"@ 8743' l••Ie. 9252' -�4-1/2"PORTED JOINT(40.49') Nute.Refer to Production DB for historical perf data 9272' --14"BAKER CEP SIZE SPF INTERVAL Opn/Sqz SHOT SQZ , 2-1/2" 6 8743-8748 0 01/17/17 3-3/8" 6 8758-8773 0 03/17/15 ' MLLOUT WNDOW(11-37) 9356' 3-3/8" 6 8800-8808 C 09/25/97 U 3-318" 12 8812-8814 C 07/17/97 2-7/8" 6 8815-8820 C 12/10/01 , 3-3/8" 6 8854-8860 C 07/31/05 ' 3-3/8" 6 8890-8898 C 07/31/05 3-3/8" 6 8902-8906 C 07/31/05 3-3/8" 6 8918-8926 C 07/31/05 ' 3-3/8" 6 8953-8973 C 08/01/11 3-3/8" 6 9160-9165 C 08/23/97 3-318" 4 9291-9292 C 05/10/97 4-1/2" SLID 9293-10417 SLOT/C 12/01/96 4-1/2"LNR, 12.6#,13CR-80 NSCT,.0152 bpf,D -=3.958" 1Q440' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNT 12/01/96 D-16 ORIGINAL COMPLETION 07/19/16 CJS/JM)SET HDC PLUG(07/17/16) WELL:X11-37 04/10/05 D-16 RWO 01/31/17 MS/JMD ADPERFS(01/17/17) PERMIT No: 1961740 03/17/15 CJS/PJC SET MP/ADPBZF _ AR No: 50-029-22716-00 03118/15 PJC CSG/LNR CORRECTION PER TALLY SEC 34,T11 N,R15E,4029'FEL&4884'FNL 05/23/16 RCT/JMD FISHED IBP(05/17/16) 06/20/16 RMJMD CORRECTED OA CMT-REMOVED BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well ❑ Other: tic 2C p i 1, 1 CEJ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 196-174 -1 3. Address: P.O.Box 196612 Anchorage, Development VI Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22716-00-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 11-37 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: f`° , a . �I E 12 1,, Total Depth: measured 10440 feet Plugs measured See Attachment feet true vertical 8858 feet Junk measured 9144 feet AUG 1 5 2016 Effective Depth: measured 8779 feet Packer measured 7503 feet true vertical 8662 feet Packer true vertical 7469.63 feet a,f (3C) C Casing: Length: Size: MD: TVD: Burst: Collapse: �1 Structural Conductor 80 20"91.5#H-40 27-107 27-107 1490 470 Surface 3783 9-5/8"40#L-80 26-3808 26-3803 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1235 4-1/2"12.6#L-80 9205-10439 8876-8858 8430 7500 Perforation Depth: Measured depth: See Attachment feet SEATrue vertical depth: See Attachment feet ME® ���1 ,i Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 22-7580 22-7542 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 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: 12 0 978 1766 682 Subsequent to operation: 179 7344 5123 1738 800 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations WI Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ).i 44 W1� Phone +1 907 564 4424 Date 8/15/16 Form 10-404 Revised 5/2015 1l7 v Submit Original Only 1'131 RBDMS AUG 1 5 2016 • • Plugs Attachement PBU 11-37 SW Name Date MD Description 11-37 07/17/2016 8779 7" HEX PLUG 11-37 04/07/2005 8990 7" HES EZSV 11-37 06/20/1998 8857 Sand Plug 11-37 05/08/1997 9272 4-1/2"CIBP • • w k00000000 !a O) N '- N N O O O O O O L() In C M ti K7 I- Ln r- U O) L� CO �l CO CO 2 2 3 N- i- N r N r cf m L[) OD N- O N- OD OD CO � M N Ln co - OD N O Ch LC) L[) O) LC) � OCOMCocoOOL() 01 00 OD 00 OD 00 N 1 1 1 1 1 1 1 1 1 F- fs CO M LN LLO M r- N N N N (O 01 CO CO OD N 0000000 CD Ps O0OChNr' LL� COCN CO0 00 OD CO OD 000 OM) 0 Ps Q M Ps CO ¢t C 0 N CO CO 03 O N r N N N CO N- N- N N 0000000) z W a ao pO000000D Nr OD CA 00 CA 00 J co = UUUUUq# T- ' N OUl T-V T- N # N • CO CO N om _ 0) CO (0 0) O aO CD CO O CO O) - U - N N N N N N - N N `i N C 000 CO co coO) coO N LCN co LO J Ch 00 • W W W W W Q Q Q Q Q cn COW W W 0 co < 22222 0Z i W W W W W W m OF- F— F— F— F— Z � U Z Z Z Z Z J I_ • m H ai L co� COMmN (NNNrCON- NO) p, N O O 4 N d' O O N 4 O N N O co O CO CO up op CD CD Ns Ns N- Ns CO CO pop CO C] 00 00 OD OD 00 CO CO CO OD 00 O CO 00 a O N- v O CO M y O) O CO CO v O r` r- M M T- N o CO O) N• N CO CD Ni 6 00 O O NON N M O 06 00 ❑ ❑ CCOOCOCOCONsNsNNNNoOpCOONs OD > 0 03 O00ODCO CO 00 CO00000D0D 0 > 2 ❑• ❑ Lu z ~ ~ OJ a m o 0 55 dO t M cowM CO V O N- O CO CO CO M O O N J ¢ ¢ W W = p. N- O - N O O 0) O N Ns CO V0_ n. Z 0N- OCO ODC0000O) 0) 0) - No < 0 00 0 0 W 0 _10 d O COCOCOCOCOCOCO0000OOO) O) � Z z Z O J J J ❑ J ¢ ¢ m p O CL W 0- 2 12 z ❑ ❑ M 2 0 0 0 W W W W 0 N ¢ OJ ¢ 2220w wwwwM 4-1 C « OO O N [F v- N- O N CO CY) O O M M C. 0 0 - - O O 0) O - O CO N O) ft..' G N - CO CO CO OD CO CO 0) 0) 0) r- N N }rCO 00 CO CO 00 CO 00 00 00 CO 0) 0) O) LCOO- 0 0 2 0: CnY 000 W 2 2 O Ch c i Ch uWi_la 0� li. 0 0 0 0 O LL Cl) CnU) C/) C/) (I) CAU) Cl) Cl) (I) Cl) 'Eaaaaaaaaaaaaa a < M M m M M m M M m M M ( 0 0 d a 0 m O CO CO CO O O CO O CO CO CO CO CO 0 ❑ O C O o 0 0 0 0 0 0 0 0 0 0 0 W Z O N N N N N N N N N N N N N Z LL N� N- O W ❑ WCI ❑ W Ll . . . . 5 -. - -. Z a J 0 w W L1 w C. M N- N- I"- N. N,- I,- N. N- N- I,- Ns Ns ¢ ❑ J 1- J J J n 0_ 0 m ❑ m W --1 -J ¢ 0 W W ¢ ¢ 0_ N LL LL LL N ace 0 E LL a m O LL Nix LL J ¢ ¢ mmu_ Ecov�iam • • Packers and SSV's Attachment PBU 11-37 SW Name Type MD TVD Depscription 11-37 TBG PACKER 7502.58 7469.63 4-1/2" Baker S-3 Perm Packer 11-37 PACKER 9204.56 8875.95 4-1/2"TIW SS Horiz Packer • 0 7 ? a / k \ / 2 co c2 I- o 0 o 0_ 'a t0 § 2 k - 0 5- (7) I- & 0 -J o @ I / b E n 2 m C b •• u_ u_ \ _, � 1 o >- 9 : o ofi IIz 2 0 2 2-0 03- / . 2 / - I w 0 / k OCl. / / U eL�o ° Oz �w Li) Y 2w -03 � - % � ' / k o / � 0 ƒ 5. '- ° 0_ .o 0a) 0w 00 0 m E y e a ii I 2 w w r0_ k / _ o w - _ 0 0) £ 0 � D : w0 ƒ o ..e � E - : � k � - 2 @ 2 - E o L « h e t e -1 >, / = k ® � � 2ak / � � / > 6 / > Z2aI < N - « co ƒ ao2@ - 70oo20w j zbr / 2 (9 � z / w0 < ' � 0 2 w � / k � / ku_ / _1kk -J � � / k - I-- w # -J _I ® LU * O Z _I -I0_ LL & � w ., ■ $ 0- Lw « IOtcn � � � .�2 >* ** ,- � bkR k : 0 ! G m = m : m : : FE m R i : 5 w < c o 0 co \ % / 2 q > k ® b ¥ ¥ N- ¥ 0 • TREE= CNV 111) 7 -ARTY NOTES: WELL ANGL ACTUATOR= BKRC 11 _3 MAX DOGLEG:14.6•@ 8437'E•CHROME TBG,; K8 ELEV= 54' 7'CSG 29# H 64' y I LNR,&CSG*** BF.F3E1/= Nr-13CR-80 NSCC, KOP= 6970' MixAngle= 94 @ 9483' D=6.184" i ' ( 2087' HES " Datum MD= 9120' #,CONDUCTOR, —I ? Datum TVD= 8800'SS GAS LFT MADS D= J " ST MD_TVD DEV TYPE VLV ATC PORT DATE 5 2978 2973 5 KBG-2 DMY BK 0 09/12/11 9-5/8"CSG,40#,L-80 BUTT,C=8.835" H 3809' 4 4081 4075 1 KBG-2 DOME BK 16 09/12/11 L 3 5890 5885 1 KBG-2 DOME BK 16 09/12/11 2 6580 6574 1 KBG-2 DMY BK 0 04/09/05 Minimum ID =3.725" @ 7546' 1 7309 7288 20 KBG-2 SO BK 22 09/12/11 4-1/2" HES XN NIPPLE ' r 7460' _14-1/2"FES X NP,D=3.813" Z I 7481' H7"X 4-1/2"BKR S-3 PKR,D=3.875" ' I 7546' —I4-1/2"HES XN NP,D=3.725" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, —I 7558' I\ .0152 bpf,13=3.958" --/ 7558' —{4 1/2"WLF3G,D=3.958" 7"CSG,26#,L-80,.0383 bpf,D=6.276" —I 8447' I--x x 7576' H H.M TT LOGGED ON 07/30/05 17"MARKER JOFNT,26#(10') --I 8759' I---119 7"MARKER JOINT,29#(20') H 8769' He 8779' 1 MB /*E..L 363-700 HEX BRIDGE PLUG (07/17/16) TOP OF 4-1/2"LNR —I 9205• �' - 9990*' — 7"HES EZSV{04/07/05} 4-1/2"LNR,12.6#,L-80 XO TO 13CR 80 NSCT —I 9252' 4111, 9144' H 3-3/8"BP PUSHED DOWN HOLE(04/05/05) r CSG,29#,NT-13CR-80 NSCC,D=6.184" —I 9327' a.--1 9205' 17.X 4-1/2"TM/SS HORIZONTAL PERFORATION SU MARY ` PKR,D=3905" REF LOG: NOT ON DEPTH w/MIND ANGLE AT TOP FERE:32"n_ 8758' M•00 8 9252' H4-1/2" (40.49') Note:Refer to Production CB for historical perf data iii' 9272' —I4"BAKER CEP SEE SPF INT@R'VAL Opn/Sqz SHOT SQZ 3-3/8" 6 8758-8773 0 03/17/15 ' 3-3/8" 6 8800-8808 C 09/25/97 : ILMLLOUT WINDOW(11-37) 9356' 3-3/8" 12 8812-8814 C 07/17/97 2-7/8" 6 8815-8820 C 12/10/01 3-3/8" 6 8854-8860 C 07/31/05 3-3/8" 6 8890-8898 C 07/31/05 ' 3-3/8" 6 8902-8906 C 07/31/05 3-3/8" 6 8918-8926 C 07/31/05 3-3/8' 6 8953-8973 C 08/01/11 3-3/8" 6 9160-9165 C 08/23/97 , 3-3/8" 4 9291-9292 C 05/10/97 ' 4-1/2" SLID 9293-10417 SLOT/C 12/01/96 4-1/2"LNR,12.6#,13CR-80 NSCT,.0152 bpf,D=3.958' H 10440' , DATE REV BY COMAENTS DATE REV BY COMMENTS PRUDFOE BAY INT 12/01/96 D-16 ORIGINAL COMPLETION 03/17/15 CJS/PJC SET CBR ADPERF WELL:91-37 04/10/05 D-16 MO 03/18/15 PJC CSG/LNR CORRECTION PER TALLY FERMT No.'1961740 01/15/07 CRS/PAG LOG CORRECTION(07/30/05) 05/23/16 RCT/,944)FISTED BP(05/17/16) AR No: 50-029-22716-00 07/17/10 OOB/PJC TALLY/DRAWNG CORRECTIONS 06/20/16 RIWJMD CORRECTED OA CMF-REMOVE ) SEC 34,T11N,R15E,4029'FEL&4884'FT/ 08/14/11 OOB/PJC PERF REF LOG UPDATE 07/19/16 CJS/JMD SET HEX PLUG(07/17/16) 09/18/11 RCT/PJC GLV C/O(09/12/11) BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM& REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Re-enter Susp Well 0 Other: Dislodged IBP m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 196-174 3. Address: P.O.Box 196612 Anchorage, Development IJ Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22716-00-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 11-37 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10440 feet Plugs measured See Attachment feet RECEIVED true vertical 8858 feet Junk measured 9144 feet e Effective Depth: measured 8783 feet Packer measured 9205 feet JUN 0 9 2016 true vertical 8666 feet Packer true vertical 8875.95 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 27-107 27-107 1490 470 Surface 3783 9-5/8"40#L-80 26-3808 26-3803 5750 3090 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1235 4-1/2"12.6#L-80 9205-10439 8876-8858 8430 7500 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet SCWO FEB 0 2 2017, Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 22-7580 22-7542 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 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: 68 0 1144 1927 691 Subsequent to operation: 2 0 2473 1818 716 14.Attachments:(required per 20 AAC 25.070 25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations IZ1 Exploratory ❑ Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 6/8/16 Form 10-404 Revised 5/2015 1/7-1- F/t f)1.o. RBDMS [A/ JUN 0 9 2016 Submit Original Only • • Plugs Attachment PBU 11-37 SW Name Date MD Description 11-37 04/07/2005 8990 7" HES EZSV 11-37 06/20/1998 8857 Sand Plug _ 11-37 05/08/1997 9272 4-1/2" CIBP • • m • oO0000Ooo N- CD N T- N T- N 0 O OO Tr O Tr O Ul tO C M i- LO N- U) N- ti U E LU (ID V- CO g O M M • Tr T- N '- N ' vt Tr m T- CID 00 N- 00 1s OD 00 M ▪ M N Ln M CO N O O M Ln U1 O LC) T' OD CD M CO O 00 00 U1 M 000003CO0 N 0 H III Ps QD tt M U L0 c Ps N N N N (0 M CID CO CO N 00 O M O C Cr)Ps Q O M Tr u, CID N M 000 O— 00 CO Tr N- N- M e5OCfl co 00 CO 00 O) _ N- o o 4.6• 1 Q MPs N- CO M lLU 0(O O N r NNNCO [hN- NsNN 00 co 00 O) • M H a0 O O O O O O O Opp V 71- 00 00 00 00 OD J C = J 0 0 V 0 0 4t T- O) - N O T- T- T- T r CID QD (ID O) 00 Off) CO CD (O CD ss N N N N N N _ -- Tr Tr J: M M Cn CD CO CD 00 N O In Op CID uD C COup M M 01 000 M O U/ T W W W W W im c O W W 00LLI 0LIJ 0LLI W Z0wwwwwwm DHHF- HZ � V Z Z Z Z Z • • ar N t0 m co M O N CO N I— CC) O t M CO M O) N V- N V- CO N- N O) p, I� O O 4 N 4 O O N 4 O al O CO O) O) N N O O CO O) co CO LO o CO CO CO CO I- ti N- N- ti N- co CO CO CO CO CO CO CO CO CO CO CO CO CO CO a 0 vCDOMvaOcococr Y M N- cM N 0 CO O) I— N CO CA 0. 4600 OONONNMCn00O CO CA N N Cf O CO CO CO I-- CO W • CO CD CO CO N- N- I-- I- ti N- CO CO CO • CO CO CO 00 00 CO CO CO OD CO CO CO CO O W a w o � Luz gg o0 Y U 0 O m O O W Y Y g MO V ON- OOCOCOMOO J J J ¢ ¢ U) W cc = CD I,- CO CO CO CO CO CO a) O) CD N _U U_ U_ W W ? C o co CO CO co co CO co co co co O) a) Z Z Z O J J J R ¢ ¢ ¢ = Q Q 0_ W a E C) (-) 00.1 & & Z6.. Z w w w 0- H H ¢ J ¢ CO ti 2 2 2 0 cn co N u) co CO elI Qa r I- 00 O N Nr A ' O N CO M O O M ° lC) O lC) t!) O) O '— tf) CO N O) O M d N 00 co co co CO CO CA O) O) - N N - W 0 00 CO 00 00 00 O co O O 00 O) CD O) 03aI L a) O — — J = H 1- a J W 2 a 2 O co co co co co CD a ° U c .2 u_ o_ n_ o_ o_ o_ o_ o_ a_ au U) d < m COCOm m m m m m m m m a 0 t a) a 111 Q OOOCOCOCOOOCOCOCOCOCO 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 W Z o N N N CV N N N N CV N N N N Z U- ¢ w • T- N N N N CV CV N N N CV CV N Z 000 0 d W U W W U- 0. W O M V �f v Nt V- et V- v CO 0 - W J J J = 0: a ¢ ¢ a Cl) IL IJ—i I¢i Cl) d Et a, E �a • I� til� NN- N- N- l- til- NN- N 3 M M M M M M M M M M M M M 0_ a Cn C O C I W a m a g a J ¢ ¢ 03 03 u_ IL U U a 0! • • Packers and SSV's Attachment PBU 11-37 SW Name Type MD TVD Depscription 11-37 TBG PACKER 7502.58 7469.63 4-1/2" Baker S-3 Perm Packer 11-37 PACKER 9204.56 8875.95 4-1/2"TIW SS Horiz Packer • • c -p ° a) 0 o Q m b o o m c -0 a) C A -0 0 _ fo 0 ca N M M 7 . -c o +J LL Q fpm o g C ` U C o ° 13 N E. N O t°o p C I I� O U w Z co E '0 >i (p a) !� m o — o N N p = Q ° U U U) • O t a) ,T;) ° o ° -aO T:) ..c Cn - N c2 ° u) i L M o -0 a c O C - o N- O co D_J Q C M N 7 J p O C CO Cri O Q 0) C W- O N ( a) .O (n Y II — p M O M �� O fl- a) fo � � N � 4-, ° p a) w 2 a) C.) Cr) c o Q a 0Cr > Q > a E 47. aC my ao 4. rn �(13 � � �� m Q * m Q) m a) -0N -0 ow c sz J r- mzm00O E ° O `. C N C E p 0 _ 2 N fp J cD 0 0 F- fp = fp II O J -J C c F- o � E C .S ° wOmO ° > Lo iv) x mM �to ©F N a 0 a fo m m 2 f i io - o I: flofI H °° tiMm�E o v°) w w zzCCp w 13 n -t o o b F- m �on0 @�(rt L - U c > ° -0 7 N O -) W Q 2 c c a 7o a) •- U E as U ° Q cei •H M Cvj z 2 ©c�i = J m > } c _o p ° c 3 ° ° > m >— moa om eco 0 �• � * 0 3pf3Y ` • * 0 21)- 0(� � 2 > W � m2Nff� O � — C4) * f' U0 * ° Y ° � ° o � c_n � MO wLlja ti I * Q -1 fp a) * N 0 .2 .- O co C > J J a J f C > (/) ap F- 0 W M r CD �OLLJo o_(0 a) co • UN m a) v) LL v) -� , • OF- Mu) — J LO r * fo co E z 2 N ° "p >,> O fp 0 a CD - Q 00 Z i - w M Z c,- co' x- 7N U 4(7) -° QO -0 (/) • D - — m co N -0M W M OX Oi O O N * 5 a N * fp o E ° • ) (/) N a) f 'O - O O ,F Ch O f. 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' ' ►1 2087' 4-112"NES X NP,D=3.813' Datum MD= 9120' --#p,CONDUCTOR, —{ ? 11 1 Datum TVD= 8800'SS /1 /1 GAS LFT MANDRELS D= ►4 11 ST MD TVD DEV TYPE VLV ATC FORT DATE 5 2978 2973 5 KBG-2 DMY BK 0 09/12/11 9-518"CSG,40#,L-80 BUTT,D=8.835" —j 3809' 4 4081 4075 1 KBG-2 DOME BK 16 09/12/11 3 5890 5885 1 KBG-2 DOPE BK 16 09/12/11 — 2 6580 6574 1 KBG-2 CNN BK 0 04/09/05 Minimum ID =3.725" 7546' 1 7309 7288 20 KBG-2 SO BK 22 09/12/11 4-1/2" HES XN NIPPLE ' 7460' _44--1/2"FES X NP,D=3.813 7481' —Jr X 4-1/2"BKR S-3 PKR,D=3.875" I 7546' —14-1/2"FES XN NP,ID=3.725" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, — 7558' 0152 bpf,D=3.958" \ 7558' --j 4-1/2"WLEG,ID=3.958" 7'CSG,26#,L-80,.0383 bpf,ID=6.276" H 8447' j—x y, ( 7576' HELM TT LOGGED ON 07/30/05 r MARKER JONT,26#(10') —{ 8759' F--. 7'MARKER JOINT,29#(20') —j 8769' H. 11 {TOP OF 4-1/2"LNR —{ 9205• ��� 8990' H 7"FES EZSV(04/07/05) 4-1/2"LNR, 12.6#,L-80 XO TO 13CR-80 NSCT —1 9252' 9144' -j 3-3/8"IBP PUSHED DOWN HOLE(04/05/05) 7"CSG,29#,NT-13CR-80 NSCC,D=6.184" — 9327' El 9205' --{7'X 4-1/2"TtW SS HORIZONTAL PERFORATION Sl1hRuIAr ' PKR,D=3.905" REF LOG: NOT ON DEPTH w/MWD ANGLE ANGLE AT TOP PERF:32°@ 8758' M••041--1 9252' H4-112"PORTED JOINT(40.49') Note:Refer to Production DB for historical perf data iwi' 9272' —{4"BAKER CEP SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 8758-8773 0 03/17/15 3-3/8' 6 8800-8808 0 09/25/97 , MLLOUT WINDOW(11-37) 9356' 3-3/8" 12 8812-8814 0 07/17/97 2-7/8" 6 8815-8820 0 12/10/01 3-3/8" 6 8854-8860 0 07/31/05 3-3/8" 6 8890-8898 0 07/31/05 ' 3-3/8" 6 8902-8906 0 07/31/05 3-3/8" 6 8918-8926 0 07/31/05 3-3/8" 6 8953-8973 0 08/01/11 3-3/8" 6 9160-9165 C 08/23/97 , 3-3/8" 4 9291 -9292 C 05/10/97 4-1/7 SLID 9293-10417 SLOT/C 12/01/96 4-1/7 L 126#13CR 80 NSCT,.0152 41 L - I`Pbpf,D-3.958" H 10440' DATE REV BY COMIuENTS DATE REV BY COMMENTS PRUDHOE BAY IJNTT 12/01/96 D-16 ORIGINAL COMPLETION 08/14/11 OOB/PJC PERF REF LOG UPDATE WELL: 11-37 04/10/05 D-16 RWO 09/18/11 RCT/PJC GLV CIO(09/12/11) PERMIT No: 1961740 01/15/07 DRS/PAG LOG CORRFI;TION(07/30/05) 03/17/15 CJS/PJC SET CBF/ADPERF AFT No: 50-029-22716-00 07/17/10 OOB/PJC TALLY/DRAWING CORRECTIONS 03/18/15 PJC CSG/LNR ODRRECf1ON PER TALLY SEC 34,T11N,R15E,4029'FEL&4884'FNL 08/08/11 OOB/PJC PERF REF LOG CORRECTION 05/23/16 RCT/JM)FISHED BP(05/17/16) 08/08/11 SRD/PJC PERF(08/01/11) BP Exploration(Alaska) STATE OF ALASKA Fl ECE1VED A_ JKA OIL AND GAS CONSERVATION COM. JON APR 0 9 2015 REPORT OF SUNDRY WELL OPERATIONS 9 1 Operations Abandon J Repair Well U Plug Perforations U Perforate U Other 'C C Performed. Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ElWaiver ❑ Time Extensions Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weill] 2 Operator 4.Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development El Exploratory ❑ 196-174-0 3 Address P 0 Box 196612 Stratigraphic❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-22716-00-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028325 PBU 11-37 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) '10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 10440 feet Plugs measured See Attachment feet true vertical 8857 98 feet Junk measured 9144 feet Effective Depth measured 8783 feet Packer measured See Attachment feet true vertical 8665 64 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 83 20"91 5#H-40 27-110 27-110 1490 470 Surface 3782.78 9-5/8"40#L-80 26 45-3809 23 26-3803 28 5750 3090 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 24 95-7558 13 25-7521 39 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured). ' Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 0 0 0 0 0 Subsequent to operation: 1244 43119 499 0 1026 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Explorator❑ Development Q Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil Q Gas ❑ WDSPLIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC0 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerhays(bp.com Printed Name Nita Summerhays,e' Title Petrotechnical Data Engineer / 47//M Signature+--,,', /.4rialKgillr Phone 564-4035 Date 4/9/2015 v-r- 4I 1017C- RBDM3c APR 1 0 2015 ala/� Form 10-404 Revised 10/2012 Submit Original Only • Daily Report of Well Operations ADL0028325 T:DATE SUMMARY "**WELL Sit ON ARRIVAL*-*(perforating) SWCP 4522 R/U 3/14/2015 ***CONT ON 3/15/15 WSR*** *** CONT FROM 3/14/15 WSR *** (perforating) SWCP 4522 R/U DIRFT W/16'x 3-3/8" DUMMY GUN &4-1/2"T.E.L(loc t.t. at 7,567'slm +9'correction to ELM 7,576') TAGGED BOTTOM AT 8,959' SLM (no issues) 3/15/2015 ***WELL S/I ON DEPARTURE*** ***WELL SHUT-IN ON ARRIVAL***(SLB E-LINE ADPERF AND IBP) INITIAL T/I/O= 1250/1980/280 LRS L&K TBG W/KCL&DIESEL FRZ PRT RIH W/15'x3-3/8"HSD POWERJET HMX GUN 6SPF 60° PHASE. PERFORATED INTERVAL 8758'-8773'. TIED INTO BAKER HUGHES RPM 0/0 LOG DATED 28-OCT-2014 LAID DOWN EQUIPMENT FOR NIGHT, WILL RETURN IN AM TO SET IBP. NOTIFIED PAD OP 3/17/2015 ***CONTINUE 18-MARCH-2015*** T/I/0=963/1329/346 Temp=S/I Assist SEL with load and test(perforating) Loaded tbg with a 5 bbl meth spear and 238 bbls 1% Kcl.freeze protected tbg with 5 bbls meth and 35 bbls diesel. E-line on 3/18/2015 well at departure IA/OA=OTG Final WHP's 0/1350/437 ***CONT FROM 3/17/15 WSR** (SLB ELINE ADPERF I IBP) LRS PERFORMED ANOTHER L&K W/FRZ PROTECT ON TBG (SEE LRS REPORT) RIH W/ELINE TOOLS&3-3/8"BAKER IBP SET BAKER 3-3/8" IBP @ 8790' MID ELEMENT(TOP SET @ 8783') (PLUG SPECS= 1.375"FISHING NECK, /11.04'OAL/3-3/8"MAX OD[TWO 6"SEALING ELEMENTS&ONE 1"STIFFENER RING] TIED INTO BAKER HUGHES RPM 0/0 LOG DATED 28-OCT-2014&SLB PERF LOG RAN YESTERDAY WELL SHUT IN UPON DEPARTURE-NOTIFIED PAD OP RELEASED TO POP FINAL T/I/O=0/1300/400 3/18/2015 ***JOB TO COMPLETE*** FLUIDS PUMPED BBLS 78 DIESEL 20 METH 478 1% KCL 576 TOTAL a) co ea m co N- co V' N CO N N- UO O 1- CO t CO CO CO CD V' N V' CO N- OD CA p, I- to O 4 4 O Ld 4 ( co N 0 Q) LO CO O Cr) N LU to CO CA co 00 to O CO CO CO CO 1- N- N- N- I� co CO CO O OO 00 00 LU 00 OO 00 CJO CO CO CO > cu a 0 O Z W LU a J O a o Y O O o' VO W Y Y g o co k ' CO coM V OO ' - LO CO CVlN O ' - J U O w W r N- CO N- CO c- C) CO 0) N- N 00 0) J J J d d to Z c a) V' N- CO Cil d Lri a0 O) N V- tLO CO 00 CO aO CO 0_ 0_ 2000 _10 _1 O J W W a CO CO CO CO N- I` ti N- N- CO CO CO Z Z Z O J J J 0 J o 00 OO 00 OO oO c0 O 00 00 M M co Q Q < I 0 0 11. 1 O_ I- 0 0 U W 62 CE Z O Z Ili L.LJ LLI 0_2 2 2 O c i co co cn u a) co m CO L co c0 V O O 00 O CO CO LO N ++ p_ N- O ,- N CO CA O N N- co 0) C a) N- CO CO CO CO 00 CA 0) 0) ,- N �O 0 CO CO CO CO CO CO CO CO CO CA 0) CD E a w a) (n -1-1 2 1- O- d J d - V 2 O co cn co cn cn • N in a COa N O 0 ~ C 0 L co O N V O N CO CO O N- CO Ja LO O LC) C3) O 1- LC) CO CA CA 0 ❑ a) N- a0 OD 00 00 OO O C3) CA — N N '471Q o OO 00 OO 00 OO CO OO CXR 00 CA C) O) ca a) O 2 QU O. 0 0 0 c u- co (n (n co U) (n co U) (n U) U) is CL O_ O_ CL O_ CL O_ CL O_ CL CL O_ `y Q CO CO CO m CO CO CO CO CO CO CO a 0 t a) CL 0 w J J F-- m a cCWI/) I- uw on n n to to n n n to in to to C� C7 O Q c 0 0 0 0 0 0 0 0 0 C) C) C) W J J Z U_ O N N N N N N N N N N N N Z w 0_ 0_ < W W N- 00 LU C O OO 00 00 CO C O OO 00 OO 0 w W W _i W W CC Z - 0 0 0 UJ W CL W Q M M M CO M M M M M CO M M < U .g J J D D Ct CL CO 0 CC fY J_ - 0 Q < m c0 E I co CL cc a) E cc Z 1- N- N- N- N- N N- N- N- N- N- 1.--- CO `M CO CO CO M CO M CO CO CO CO M w N w N l e i o w n_ co 0 CO 0- a a O -100w a < < co m w U U) Cn d 2 Packers and SSV's Attachment ADL0028325 SW Name Type MD TVD Depscription 11-37 PACKER 7480.59 7449.08 4-1/2" Baker S-3 Perm Packer 11-37 PACKER 9205.37 8876.11 4-1/2" TIW SS Horiz Packer m p• o o o o o N O CS) O • N.- V O �I') O t1) C u) r- N- M N- U III o o o o o o i 0) V co co LC) () 7 V (N — V r- 03 m r N- CO 00 IC) C) N r` a0 a0 CA 6) N- CA N 00 .-- QC) 0) IC) O N 00 00 00 00 Q0 OD p 00 00 N 00 CA O N- 10 N O 10 N N () N- N N co co 00 00 p 00) OD V N O 10 V 00 00 l() 0 00 CD M 0 u 03 tt) 75 ++ N QM r- Q0vCD QDin Co N N 00 N N C SI— CD 0 CD p O CD Q p 00O 2 co O - J J co *t N U c- CV (tf 0) N CA - a0 U O N- . N N • V LO CO CO a)CO N O CO co CO C a0 V a0 N r IC) J ( Z Z Z a)OOOJ 0 w 0 0 0 F. Z Z O O O ( O CC C 0 0 0 a d U) U) F- 11-37 196-174-0 Plugs Attachement SW Name Date MD Description 11-37 12/11/2001 8990 7" HES EZSV 11-37 11/27/1996 9272 4" Baker CIBP TRS CNY WELLHEAD= RC 1 1 47 S, _TY NOTES: WELL ANGLE>70"@ 9078'*** AC)UATOR= BI<R CMAX DOGLEG:14.6'@ 8437' CHROME TBG, 03.flEV—__. ... — _fie LNR,&CSG*** BF. E/ 7"CSG,29#, -1 64' A I NT-13CR-80 NSCCKOP= 970' , 1 •- Max Angle= 94 r,9483' D-6.184" I. , ' 2Q87' �4 1/2"FES X I D=3.813" Datum MD= 9120 #,COPDUCTOR H ? 1 Datum TVD= 8800'SS _ 1' GAS LFT MANDRELS ID= " 14 ST MD TVD DEV TYPE VLV ATC PORT DATE 5 2978 2973 5 KBG-2 DM' BK 0 09/12/11 9-5/8'CSG,40#,L-80 BUTT,D=8.835" H 3809" 4 4081 4075 1 KBG-2 DOME BK 16 09/12/11 L 3 5890 5885 1 KBG-2 DOME BK 16 09/12/11 2 6580 6574 1 KBG-2 DIN BK 0 04/09/05 Minimum ID =3.725"@ 7546' 1 7309 7288 20 KBG-2 SO BK 22 09/12/11 4-1/2" HES XN NIPPLE II I 74$0' _14-1/2"FES X NP,D=3.813" Z X 7481' N7"X 4-1/7 BKR 5-3 PKR,D=3.875" ' ' 7546' -14-112"HES XN NP,D=3.725" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, -1 7558' -,...„.../ 7558• 4-1/2"WnrLEG,D=3.958" .0152 bpf,D=3.958' 7"CSG,26#,L-80,.0383 bpf,D=8.276" H 8447' 1— c x 7576' H ELM TT LOGGED ON 07/30/05 7"MARKER JOM,26#(10') -I 8759' H 0 r MARKER JOINT,29#(201 --I 8769' I--41 8783' H3-318"BKR BP(03/17/15) - TOP OF 4-1/2'LNR --{ 9205' 0000' 7"FES ELSV(04/07/05) 4-1/2'LNR,12.6#,L-80 XO TO 13CR-80 NSCT -1 9252' Illk 9144' -I 3-3/8"BP PUSHED DOWN HOLE(04/05/05) r CSG,294,NT-13CR 80 NSCC,D=6.184" H 9327' 9205' 1 p 7'X 4 112'TiW SS HORIZONTAL PERFORATION SUMMARY ` RKR, =3.905" REF'LOG: NOT ON DEPTH w/M/ID ANGLEATTOP FE RF:32"n8758' •004 9252' H4 1/2"PORTH)JONT(40.49) Pate:Refer to Roduchon DB for historical perf data gil9272' -H4"BAKER CEP SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 3-3/8" 6 8758-8773 0 03/17/15 , 3-3/8" 6 8800-8808 C 09/25/97 MLLOUT WINDOW(11-37) 9356' 3-3/8" 12 8812-8814 C 07/17/97 2-7/8" 6 8815-8820 C 12/10/01 3-318" 6 8854-8860 C 07/31/05 3-3/8" 6 8890-8898 C 07/31/05 ' 3-3/8" 6 8902-8906 C 07/31/05 3-3/8" 6 8918-8926 C 07/31/05 3-3/8" 6 8953-8973 C 08/01/11 3-3/8" 6 9160-9165 C 08/23/97 3-3/8" 4 9291-9292 C 05/10/97 ' 4-1/2" SLID 9293-10417 SLOT/C 12/01/96 4-1/2'LNR,12.6#,13CR-80 NSCT,.0152 bpf,D=3.958' -I 10440' J DATE REV BY COMWBNTS DATE REV BY COMvU 41S PRUDHOE BAY UNIT 12/01/96 0-16 ORIGINAL COMPLETION 08/14/11 OOB/PJC PERF REF LOG UPDATE WELL:'11-37 04/10/05 0-16 IaNO 09/18/11 RCT/PJC GLV GO(09/12!11) PEtRINT No:1961740 01/15/07 DRS/PAGLOG CORRECTION(07/30/05) 03/17/15 CJS/PJC SET CLIP/ADFEFF AR Pb: 50-029-22716-00 07/17/10 0013/PJC TALLY!DRAWING CORRECTIONS 03/18/15 PJC CSG/UR CORRECTION PER TALLY SEC 34,T11N,R15E,4029'FEL&4884'FM.. 08/08/11 OOB/PJC PERF REF LOG CORRECTION 08/08/11 SRL)PJCPERF(08/01/11) 1 BP Explo►Iation(Alaska) XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~--/~/-/' File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: GraYScale, halftones, pictures, graphs, charts - Pages: '. Poor Quality Original- Pages: Other - Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type .OVERSIZED [] Logs of various kinds Other COMMENT5: Scann.ed b~M~r,,,d.~r~na N.~n eow~i TO RE-SCAN Notes: D,'-_C~,'-annc, r'I h~J' r~u~riv Mildred Daretha Nathan Lowell Date: ts/ STATE OF ALASKA • ALASKAIDAND GAS CONSERVATION COMMISSIA REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 15I Exploratory ❑ . 196 -1740 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22716 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028325 PBU 11 -37 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10440 feet Plugs (measured) 8990, 9272 feet true vertical 8857.98 feet Junk (measured) 9144 feet Effective Depth measured 10440 feet Packer (measured) 7481 9205 feet true vertical 8857.98 feet (true vertical) 7449 8876 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 83' 20" 91.5# H -40 27 - 110 27 - 110 1490 470 Surface 3783' 9- 5/8 "40# L -80 26 - 3809 26 - 3803 5750 3090 Production 8422' 7" 26# L -80 25 - 8447 25 - 8353 7240 5410 Production 880' 7" 29# 13CR80 8447 - 9327 8353 - 8891 8160 7020 Liner 1235' 4 -1/2" 12.6# 13CR80 9205 - 10440 8876 - 8858 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - - j . , _ _ - � s Q E D AURA E� �Ql I True Vertical depth: _ _ ` ... �il,tR"� _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 22 - 7558 22 - 7521 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm Packer 7481 7449 4 -1/2" TIW SS Horiz Packer 9205 8876 RECEIVED' 12. Stimulation or cement squeeze summary: Intervals treated (measured): AUG 201 Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cam Comm' ssion Ancheraoe 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 865 45,455 4,349 668 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - jD Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam: - Lastufk. w I 1 Title Petrotechnical Data Technologist Signatur= 1�.��,� Phone 564 -4091 Date 8/24/2011 q Form 10-404 Revised 10/2010 RBDIS AUG 2 5 2011 : � �. �,z5 /! Submit Original Only 11 -37 196 -174 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 11 -37 12/1/96 SL 9,293. 10,417. 8,888.97 8,857.91 11 -37 5/10/97 PER 9,291. 9,292. 8,888.81 8,888.89 11 -37 7/17/97 PER 8,812. 8,814. 8,688.78 8,690.33 11 -37 8/23/97 PER 9,160. 9,165. 8,865.24 8,866.6 11 -37 9/25/97 PER 8,800. 8,808. 8,679.36 8,685.67 11 -37 6/22/98 SQZ 8,800. 8,870. 8,679.36 8,731.44 11 -37 12/10/01 PER 8,812. 8,820. 8,688.78 8,694.94 11 -37 12/10/01 BPS 8,990. 9,272. 8,803.49 8,886.83 11 -37 12/21 /02 MLK 7,775. 7,776. 7,723.07 7,723.98 11 -37 4/7/05 BPS 8,990. 8,990. 8,803.49 8,803.49 11 -37 7/31/05 PER 8,918. 8,926. 8,762.96 8,767.87 11 -37 7/31/05 PER 8,854. 8,860. 8,720.14 8,724.42 • 11 -37 7/31/05 PER 8,890. 8,898. 8,745.01 8,750.26 11 -37 7/31/05 PER 8,902. 8,906. 8,752.85 8,755.42 11 -37 8/1/11 APF 8,953. 8,973. 8,783.76 8,794.75 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 411 • • 11 -37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/31/2011:* **WELL SHUT IN ON ARRIVAL*** (ELINE PERF) INITIAL T /I /O= 1850/2000/200 RIH WITH MH22 /ERS /PEK -C /PGGT /20' HSD GUN, OAL= 33', OAW= 570# ;FISHING NECK SIZE= 1.38" ; ** *JOB CONTINUED ON 31- JULY -11 * ** i E i i 8/1/2011: **JOB CONTINUED FROM 31- JULY - 2011 * ** (Eline adperf) !PERFORATED 20' INTERVAL, Q 8953' -8973' W/ 3-33" 3406 P_OWERJET HMX ;GUNS VISUAL CONFORMATION OF SHOTS FIRED [ FINIAL T /I /O= 1800/2000/200 WELL SHUT IN ON DEPARTURE - NOTIFIED PAD OP OF WELL STATUS ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL I�, • _WEL TREE = ' * CM/ LHEAD = FMC SAFETY I:S: H OVER 300 PPM, HORZ. ACTUATOR = BKR d I 1 -37 WELL GOES 70° @ 9108'. KB. ELEV = 54' * **CHROME TBG, LNR, & CSG* ** BF. ELEV = 1 �: KOP = 6970' . ! Max Angle = 94 @ 9483' I *4 Datum MD = 9120' I I # I 2087' 1_14-1/2" HES X NIP, ID = 3.813" I • Datum TV D = 8800' SS /• • • )4 GAS LIFT MANDRELS A � I ST MD TVD DEV TYPE VLV LATCH PORT DATE A 5 2978 2973 2 KBG -2 DOME BK 16 04/11/05 9 -5/8" CSG, 40 #, L -80, ID = 8.835" H 3809' A ''A 4 4081 4075 1 KBG -2 DMY BK 0 04/09/05 3 5890 5884 1 KBG -2 SO BK 20 04/11/05 2 6580 6574 1 KBG -2 DMY BK 0 04/09/05 1 _ 7309 7288 20 KBG -2 _ DMY _ BK _ 0 04/09/05 Minimum ID = 3.725" @ 7546' 4 -1/2" HES XN NIPPLE I 7460' I44 -1/2" HES X NIP, ID = 3.813" 1 Ica tit 7481' —17" X 4 -1/2" BKR S -3 PKR, ID = 3.875" 1 75 HES XN NIP, ID = 3.725" I 4 -1/2" TBG, 12.6 #, 13-CR-80, .0152 bpf, ID = 3.958" H 7558' I 1 7558' H4 -1/2" WLEG, ID = 3.958" I 17" CSG, 26 #, L -80, .0383 bpf, ID = 6.276" I--I 8447' ' 7576' HELM TT (07/30/05)1 1 MILLOUT WINDOW: 9356' I 8990' -17" HES EZSV (04/07/05) I �._ 9144' — I3 - 3/8" IBP PUSHED TO NEW DEPTH (04/05/05) I =� 9205' I — � 7" X 4 -1/2" TM/ SS HORIZONTAL PKR I w X I 9252' 1-I 4-1/2" 1 4 -112" PORTED JOINT (40.49') 1 1 4-1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 9252' eigi ( 4 -1/2" LNR PORTED, 12.6 #, L-80, .0152 bpf, ID = 3.958" I—I 9293' � 9272' -I4" BAKER CIBP 9293' —14-1/2" PORTED JOINT I 7" CSG, 29 #, 13- CR -80, ID = 6.184" I-I 9327' X PERFORATION SUMMARY REF LOG: NOT ON DEPTH w / MWD x x ANGLE AT TOP PERF: 40° @ 8800' Note: Refer to Production DB for historical perf data ■ X � SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 8800 - 8808 0 09/25/97 X x � % 3 -3/8" 12 8812 - 8814 0 07/17/97 2 -7/8" 6 8815 - 8820 0 12/10/01 X X �X 3 -3/8" 6 8854 - 8860 0 07/31/05 ` ` 3 -3/8" 6 8890 - 8898 0 07/31/05 X X 3 -3/8" 6 8902 - 8906 0 07/31/05 3 -3/8" 6 8918 - 8926 0 07/31/05 3 -3/8" 6 8953 - 8973 0 08/01/11/ 3 -3/8" 6 9160 -9165 C 08/23/97 3 -3/8" 4 9291 - 9292 C 05/10/97 4 -1/2" SLTD 9293 - 10417 SLOT /C 12/01/96 4 -1/2" LNR, 12.6 #, 13- CR -80, 10440' .0152 bpf, 0= 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/01/96 ORIGINAL COMPLETION 01/15/07 DRS /PAG LOG CORRECTION (07/30/05) WELL: '11-37 04/10/05 D16 RWO 07/17/10 00B /PJC TALLY/ DRAWING CORRECTIONS PERMIT No: x 1961740 04/11/05 DTR/PJC GLV C/O 08/08/11 008 /PJC PERF REF LOG CORRECTION API No: 50- 029 - 22716 -00 05/05/05 HUBBLE TALLY CORRECTIONS 08/08/11 SRD/ PJC PERF (08/01/11) SEC 34, T11N, R15E, 4029.09' FEL & 4884.04' FNL 07/31/05 GJB/TLH ADPERFS 08/14/11 00B /PJC PERF REF LOG UPDATE 02/26/06 ? ? ? /TLH DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20. Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 l'AINED IAN U\ j ,r I ;77;rTh gam. ` v i Mr. Tom Maunder Alaska Oil and Gas Conservation Commission IAN 0 3 101 333 West 7 Avenue Anchorage, Alaska 99501 t4 g>e,m `, fds. C., } , faSiOR Ancrilrbge Subject: Corrosion Inhibitor Treatments of GPB DS 11 I q Dear Mr. Maunder, / 37 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -11 Date: 12/21 /10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 -04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 _ NA Sealed NA NA 6/25/2010 11 -07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 -32 1941310 50029225120000 _ NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Well 05·33A 11-36 11-37 L3-08 L2-28 Job# 11366499 11594490 11626086 11626491 11221616 AUG 3 1 'lùÛ¡ 5~t\EO Log Descri tlon MCNL :loa -~~ tt L"'I r -C'X 9 RST Jq<.{ -^l JI 1"\ 7J RST /&)(n-l-q4 -t:I/~.5~fO RST /*7., - IL.I.":? "t:f 1.,,;?"-tCi RST /Jrp }1(.,ç-- -t35' t.. Date 10/20/06 04/21/07 04/22/07 OS/22/07 10/13/06 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 6' AUG 2 7 ZOO'7 Oil S1 Commission Anchorage NO. 4378 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL 1 1 1 1 1 Field: Prudhoe Bay Endicott Color CD 1 1 1 1 1 Alaska Data & Consulting Services 2525 -~ - s"~ e ~~~AK D50~~ Received by: // ^- 08/27/07 . . -------- 04/30/07 Schlumberger ~ ()' '7 20Q1 sCANNED Mf-\· NO. 4237 10~-lt~ Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD S-21 11695054 LDL 03/27/07 1 Y-31 11628764 MEM GLS 04/03/07 1 14-04 11660530 MEM PROD PROFILE 04/06/07 1 14-10 11626084 LDL 04/02/07 1 F-17A 11626083 LDL 03/31/07 1 F-30 11626078 LDL 03/26/07 1 X-21A 11660531 MEM PROD PROFILE 04/07/07 1 ~ 11661134 MEM PROD PROFILE 03/30/07 1 11649959 MEM INJECTION PROFILE 04/12/07 1 06-24A 11637328 PRODUCTION PROFILE 04/16/07 1 X-36 11649959 MEM INJECTION PROFILE 04/12/07 1 12-02 N/A MEM INJECTION PROFILE 04/14/07 1 J-12 11686735 PROD PROFILE 04/13/07 1 B-26B 11628767 MEM PROD PROFILE 04/11/07 1 11626477 PROD PROFILE 04/17/07 1 03-18A 11626081 LDL 03/30/07 1 P2-59A 11630470 USIT 04/02/07 1 11-37 11626086 PRODUCTION PROFILE 04/22/07 1 X-10 11686739 LDL 04/23/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 0E·'CE"IVE'" 0 If\ . ,', .f! ,.~" R ",;""., ..... . Date Delivered: t1AY 0 4 Z007 Received by: f)'ª,,*,ª Oil &: Gas Cons. C,ommißSÍOO Ancl'Iorago (L . . '\ STATE OF ALASKA '\ ALA,-,!. OIL AND GAS CONSERVATION COMrv.._/SION REPORT OF SUNDRY WELL OPERATIONS D D o 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 53.5 KB 8. Property Designation: ADl-028325 11. Present Well Condition Summary: Total Depth measured 10440 true vertical 8857.98 Effective Depth measured 10416 true vertical 8857.91 Casing Conductor Surface Production Liner SEP 1 I.!l.! ')0 ' r¡,J} L. 05 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development J;?1' Stratigraphic D Stimulate D ~¡t~~1'iQ Waiver D Time Exten~iôA'tJŒ!';'::,^ .i~.', ::.~ to"~ ~ Re-enter Suspended WeIIT.:j:;ì:;·J:C' 5. Permit to Drill Number: Exploratory [Ji 196-1740 Service C' 6. API Number: 50-029-22716-00-00 9. Well Name and Number: 11-37 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE all Pool feet feet feet feet Plugs (measured) Junk (measured) .j' (!;\) /f2in[!~ "f".,t\,NMEfì: SF!? Ji (;), _.U ,I" ;j\\,...t~" ,~~~~". 'j .. 8990,9272 None length Size MD TVD Burst Collapse 83 20" 91.5# H-40 27 - 11 0 27 - 110 1490 470 3783 9-5/8" 40# l-80 26 - 3809 26 - 3803.28 5750 3090 9302 7" 29# 13Cr80 25 - 9327 25 - 8890.77 8160 7020 1235 4-1/2" 12.6# 13Cr80 9205 - 10440 8876.03 - 8857.98 8430 7500 Perforation depth: Measured depth: 8800 - 8808 8902 - 8906 True Vertical depth: 8679.36 - 8685.67 8752.85 - 8755.42 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations Oil-Bbl 557 542 x 8812 - 8814 8918 - 8926 8688.78 - 8690.33 8762.96 - 8767.87 8814 - 8820 9160-9165 8690.33 - 8694.94 8865.24 - 8866.6 8854 - 8860 9291 - 9292 8720.14 - 8724.42 8888.81 - 8888.89 8890 - 8898 8745.01 - 8750.26 4-1/2" 12.6# 13CR80 22 - 7580 4-1/2" Baker S-3 Perm Packer 4-1/2" TWI'SS' Horiz. Packer 7502 9205 RBDMS BFL SEP 1 3 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 10623 4367 175 10131 4150 250 15. Well Class after proposed work: Exploratory r Development r;¡' 16. Well Status after proposed work: Oil P' Gas r WAG r Tubing pressure 2000 2100 Service r WDSPL r GINJ r WINJ .r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal k Signatu~ Form 10-404 Revised 04/2004 Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 9/9/2005 r~f1' \..... J . ~~~\,!AL Submit Original Only ,.I ) ') ...' 11-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 7/30/2005 T/I/O= 2000/1500/175 Pumped 107 bbls 150* crude to Assist E-line. FWHP= 700/1540/175 7/31/2005 CORRELATED TO SWS PEX AIT LOG DATED 20-NOV-1996 PERFORATED 8854-8860, 8890-8898, 8902-8906, 8918-8926 TAGGED TD AT 8945 FT FLUIDS PUMPED BBLS 107 Crude 1 Diesel 108 TOTAL STATE OF ALASKA - ALASKA k AND GAS CONSERVATION Cc. 111SSION C REPORT OF SUNDRY WELL OPERATION~ECE'VED MAY I 0 2005 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 181 Repair Well 0 Plug Perforations 0 Stimulate o Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well Alasl(ê} Oil ~ ~A¡;ons. Commission o4fl~@Hnsion 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 53.5' 8. Property Designation: ADL 028325 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 10440 8858 8990 8803 Casing Structural Conductor Surface Intermediate Production Liner Length 110' 3783' 9302' 1235' Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 196-174 6. API Number: 50-029-22716-00-00 99519-6612 9. Well Name and Number: PBU 11-37 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) 8990 feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 9-5/8" 3809' 3803' 5750 3090 7" 9327' 8891' 7240 5410 4-1/2" 9205' - 10440' 8876' - 8858' 8430 7500 SCANNE~".) MI-\Y 1 .:II 20(1;j Above CIBP: 8800' - 8820' 8679' - 8695' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4-1/2", 12.6# 13Cr80 7558' 7" X 4-1/2" Baker 'S-3' packer; 4-1/2" 'X' Nipple 7481' 2087' Treatment description including volumes used and final pressure: RBDMS BFL MAY I 1 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casino Pressure 3,059 342 841 6,227 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 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 Paul Chan, 564-5254 NIA 13. Oil-Bbl Prior to well operation: 274 Subsequent to operation: 194 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Printed Name Terrie Hubble Signature ~.aAf\;O. ~ Form 1 0-404 Revised 04/2004 Tubino Pressure 1,566 200 Title Technical Assistant Phone 05£",,- f Prepared By Name/Number: Date 7(J\V/oS Terrie Hubble, 564-4628 Submit Original Only 564-4628 ORIGINAL ) Well: Field: API: Permit: 11-37 Rig Workover Prudhoe Bay Unit 50-029-22716-00-00 196-174 Accept: Spud: Release: Rig: 03/27/05 N/A 04/09/05 Doyon 16 PRE-RIG WORK 01/29/04 MU AND RIH WITH 2.5" NOZZLE. ENGAGE FISH AT 7717' CTM. MADE 50 DOWN JAR HITS WITH NO INDICATION OF MOVING FISH. POH, CUT PIPE. MU AND RIH WITH FBHA #2 ECLIPSE PATCH PULLING TOOL. NO INDICATION OF LATCHING INTO FISH. POH, TOOL WAS SHEARED. REDRESS TOOL AND RBIH. ENGAGE FISH AT 7717'. HIT 50 JAR LICKS AT 30-34K OVER. NO MOVEMENT. PUMP OFF. POH AND CUT PIPE. 01/30/04 ENGAGE FISH AT 7717'; HIT 50 JAR LICKS, NO MOVEMENT. POH FREEZE PROTECT WELL 1 FLOWLINE. RDMO. 04/20/04 DRIFT WI 3.78" GAUGE RING TO TOP OF FISH AT 7705' SLM. 07/08/04 CHEMICAL CUT 4-1/2" TUBING IN FIRST FULL JOINT ABOVE TOP OF PATCH. CUT DEPTH = 7660' MD. RAN STRING SHOT FROM 7650 - 7662' AND TUBING PUNCHER FROM 7620' - 7622'. NO PROBLEMS RIH OR POOH. LEFT WELL SHUT IN. ) ) BPgXPLORATION. Operations ··$Limmary. R~port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-37 11-37 WORKOVER DOYON DOYON 16 Start: 3/27/2005 Rig Release: 4/9/2005 Rig Number: Spud Date: End: 4/9/2005 Held PJSM. R / D Floor and Cellar. Backed Rig Off of 11 - 27. Moved Rig from 11 - 27 to 11 - 37. Set Herculite and Rig Mats. Spotted Rig Over 11 - 37. Shimmed and Leveled Rig. Set and R I U Slop Tank, Closed In Cellar. N I U Secondary Annulus Valve. R I U Geronimo Line. Rig Ready to Take on Seawater. DECOMP Accepted Rig at 1200 hrs 3 I 27 I 2005. Rigged Up Lines to 7" x 4-1/2" Annulus. Held Pre-Spud Meeting wi Rig Crew, Toolpusher and Drilling Supervisor. DECOMP Held PJSM, R I U DSM Lubricator, Tubing Pressure 0 psi, 7" x 4-1/2" Annulus Pressure 0 psi, Pulled BPV, RID DSM Lubricator. R I U Lines to Top of Tree. Loaded Drum of Safe-Clean into Hopper Room. WAIT DECOMP Waited on Vac Trucks. Load and TallyDP in Pipe Shed. Serviced Rig, Serviced Top Drive, Serviced Accumulator, C I 0 Tugger & Elevator Lines. Performed Full Derrick Inspection. Repaired Dyamatic Switch. WAIT DECOMP Waited on Vac Trucks. Continued wi rig maintenance. DECOMP Vac Trucks on Location. Held PJSM wi Rig Crew, Truck Drivers, Toolpusher and Drilling Supervisor. R I U Truck, Took on 140 deg SW, Pressure Tested Lines to 3,500 psi, OK. DECOMP Lined Up to Pump Down 7" x 4-1/2" Annulus and Take Returns off of 4-1/2" Tubing. Pumped 100 bbls 140 deg SW Down Annulus to Displace Diesel From 4-1/2" Tubing, Pump Rate 10 bpm, 2,050 psi. Shut Down, Switched Valves to Pump Down 4-1/2" Tubing and Take Returns off of 7" x 4-1/2" Annulus. Pumped 40 bbl Detergent Pill, Followed by 400 bbls 140 deg SW, Pump Rate 7.5 bpm, 3,300 psi. Took All Returns to Slop Tank. Set TWC and Tested from Below to 1,000 psi, OK. Blew Down and RID Lines. Held PJSM. N I D Production Tree and Adapter Flange. Terminated Control Lines. Held PJSM. N I U 13-5/8" 5M BOP Stack; 13-5/8" 5M Hydril Annular Preventer, Blind Rams, Mud Cross, Pipe Rams wi 3-1/2" x 6" Variable Rams. N I U Riser and Flow Line. R I U BOPE Test Equipment. Held PJSM. Tested BOPE, Tested all choke manifold valves, Annular, Blind Rams, Choke & Kill HCR & Manual Valves, Floor Safety Valve, Dart Valve, Upper & Lower IBOP to 250 psi f/5min, 3,500 psi f/5 min. All Tests Held wi No Leaks or Pressure Loss. Performed Accumulator Test and Tested All Gas Monitors. AOGCC Rep. John Crisp Waived Witnessing of Test. Test Witnessed by BP Drilling Supervisor. NOTE: Unable to Test Pipe Rams Due to Space Constraints Between Top of Tbg Hgr and Ram Cavity. DECOMP Held PJSM. R I U DSM Lubricator. Pulled TWC. Tubing IIA & OA pressure = 0 psi. RID Lubricator. DECOMP Held PJSM. R I U Baker- Spear Assembly Dressed with 2 x 3.947" OD External Grapples to 4" DP. RIH and Engaged Tubing, P I U w/1 0,000# Overpull to Ensure Grapples Date FrOm-To Hours task Code NPT 3/27/2005 06:00 - 07:00 1.00 MOB P PRE 07:00 - 09:00 2.00 MOB P PRE 09:00 - 10:30 1.50 MOB P PRE 10:30 - 12:00 1.50 MOB P PRE 12:00 - 13:00 1.00 WHSUR P 13:00 - 14:00 1.00 WHSUR P 14:00 - 00:00 10.00 WHSUR N 3/28/2005 00:00 - 07:30 07:30 - 08:30 7.50 WHSUR N 1.00 KILL P 08:30 - 10:00 1.50 KILL P 10:00 - 11 :00 1.00 WHSUR P DECOMP 11 :00 - 12:00 1.00 WHSUR P DECOMP 12:00 - 15:30 3.50 BOPSUR P DECOMP 15:30 - 16:00 0.50 BOPSUF P DECOMP 16:00 - 20:00 4.00 BOPSUP P DECOMP 20:00 - 21 :00 1.00 WHSUR P 21 :00 - 23:30 2.50 WHSUR P Printed: 4/11/2005 10:10:22 AM ) ) 13PEXPLORATION . ... . Operé1ti()ns.·· ~.ul11{T1ªry :R~p()rt DECOMP Engaged. BOLDS. P / U on Tubing, Hanger Came Off Seat wi 130,000# Up Weight. Pulled 4-1/2" Tubing Hanger to Floor wi 125,000# String Weight Up. Released Spear. DECOMP Terminated Control Lines at Tubing Hanger. B / 0 and LID Tubing Hanger. DECOMP Held PJSM. B I 0 and LID Spear Assembly. C I 0 Elevators, LID 1 Joint 4-1/2" Tubing. DECOMP R I U Head Pin and Lines. Engaged Pump. Circulated Bottoms Up, Pump Rate 10 bpm, 1,670 psi. 260 bbls Pumped. Blew Down and RID Circulating Equipment. R I U Camco Spooling Unit while Circulating. DECOMP PJSM. Pulled 54 jts 4-1/2" 12.6# 13Cr80 NSCT Tubing, Spooled Up Control Line. B I 0 and LID SSSV Assembly. Recovered 46 of 58 SS Bands. RID Spooling Equipment. DECOMP POOH, LID 4-1/2" Tubing. Total Recovered: 185 Jts 4·1/2" 12.6# 13Cr80 NSCT Tubing, 1 SSSV Assy, 3 GLM Assy's, Dual Control Line, 4-1/2" 12.6# 13Cr80 NSCT Cut Jt = 26.27', 46 of 58 SS Bands. RID 4-1/2" Tubing Handling Equipment. Cleared and Cleaned Rig Floor. Held PJSM. R I U BOPE Test Equipment, Set Test Plug. Tested 3-1/2" x 6" Variable Rams to 250 psi fl 5min, 3,500 psi f/5 min. All Tests Held wi No Leaks or Pressure Loss. Test Witnessed by BP Drilling Supervisor. Pulled Test Plug, Blew Down Lines, RID Test Equipment. Ran and Set Wear Busing, ID = 9". Held PJSM. M I U Overshot BHA #2: 5-7/8" Cut Lip Guide- Bowl - Double Pin Bushing - Bowl - Extension - Top Sub - Bumper Sub - Oil Jars - Pumpout Sub - XO - 12 x 4-3/4" DC's. Total Length: 402.11' DECOMP RIH wi Overshot BHA #2 on 4" DP to 7,600'. PI U DP 1 x 1 from Pipe Shed. Rabbitted All DP Run in Hole. DECOMP M/U Top Drive and Establish Parameters. Break Circulation at 3.5 bpm I 270 psi. Dn. Wt. 155K, Up Wt. 160 K, Rot. Wt. 158K, 30 rpm at 2K ftllbs. RIH w/o Rotary t/7660'. Engage Rotary @ 5 rpm and Continue In Hole and Tag at 7658', Observe Pump Pressure Increase to 320 psi. Shut Down Pumps and Continue In Hole t/7666', (grapples swallowed 8' of fish). Slack Off and Put 15K Down on Fish, P/U t/175K to Trip Open Jars, Slack Off t/155K and then P/U t/170K. Set Rotary Torque to 10K ftllbs. Induce Left Hand Rotary at 3 rpm, Connection Broke at 10 Rounds wi 5K ftllbs RotaryTorque. P/U t/ 7650' and Break Circulation at 3.5 bpml 270 psi. Circulate Bottoms Up at 10 bpm/1960 psi POH wi Overshot BHA #2. Left Guide-Bowl-Pin x Pin Bushing-Bowl-Extension-Top Sub-Bumper Sub-Oil Jars in Hole. UD Pumpout Sub. RIH wi XO and 12 DC's, Total Length 371.98', to Retrieve Overshot Assy. RIH to 7,600'. M I U Top Drive, Established Parameters: String Weight Up 156,000#, String Weight Down 154,000#, String Weight Rotating 155,000#, 30 rpm, Torque 2,500 ft Ilbs, Pump Rate 3.5 bpm, 250 psi. Washed Down without Rotation, Tagged Top Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-37 11-37 WORKOVER DOYON DOYON 16 Date. From-To HÓUrs Task Code NPT Phase 3/28/2005 21 :00 - 23:30 2.50 WHSUR P 23:30 - 00:00 0.50 WHSUR P 3/29/2005 00:00 - 01 :00 1.00 WHSUR P 01 :00 - 02:00 1.00 CLEAN P 02:00 - 05:00 3.00 PULL P 05:00 - 09:30 4.50 PULL P 09:30 - 10:30 1.00 PULL P DECOMP 10:30 - 11 :00 0.50 BOPSUP P DECOMP 11 :00 - 11 :30 0.50 BOPSUR P DECOMP 11 :30 - 12:00 0.50 BOPSUP P DECOMP 12:00 - 13:00 1.00 PULL P DECOMP 13:00 - 23:00 10.00 PULL P 23:00 - 23:30 0.50 PULL P 23:30 - 00:00 0.50 PULL P DECOMP 3/30/2005 00:00 - 03:30 3.50 PULL P DECOMP 03:30 - 07:00 3.50 PULL P DECOMP 07:00 - 08:00 1.00 PULL P DECOMP Start: 3/27/2005 Rig Release: 4/9/2005 Rig Number: Spud Date: End: 4/9/2005 Printed: 4/11/2005 10: 1 0:22 AM ') ) Page 3 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-37 11-37 WORKOVER DOYON DOYON 16 Start: 3/27/2005 Rig Release: 4/9/2005 Rig Number: Spud Date: End: 4/9/2005 Påté· Ho j rs Ta.sk Code NPT 3/30/2005 07:00 - 08:00 1.00 PULL P DECOMP of BHA Fish at 7,630'. Screwed into BHA Fish, PI U wi 10,000# Overpull, Slacked Off and Stacked 10,000# on Fish, Worked Torque into Connection. Torqued Up on Connection by PI U to 10,000# Overpull, Applying 3 Right Hand Turns into Drill Pipe String, Then Releasing Torque. Repeated Procedure Until Same Number of Right Hand Applied Equaled Number of Left Hand Turns Back After Releasing Torque. Slacked Off and Stacked 10,000# on Fish, P I U to 10,000# Overpull to Work Residual Torque into Connection. Slacked Off on Drill String, Released 0 I S from Fish by PI U to 5,000# Overpull and Applying Right Hand Rotation. 08:00 - 11 :00 3.00 PULL P DECOMP POOH wi 4" DP. 11 :00 - 12:00 1.00 PULL P DECOMP POOH wi BHA, Stood Back DC's. Found Cut Lip Guide Connection Loose. Torqued All 5-7/8" Bowen Connections to 10,000 ft Ilbs, Torqued 3-1/2" IF Connections to 12,000 ft Ilbs. 12:00 - 14:30 2.50 PULL P DECOMP Found 4" HT38 Top Drive Saver Sub Bad. C I 0 to New 4" HT38 Top Drive Saver Sub. 14:30 - 15:30 1.00 PULL P DECOMP Held PJSM. M I U Overshot BHA #3: 5-7/8" Cut Lip Guide- Bowl - Double Pin Bushing - Bowl - Extension - Top Sub- Bumper Sub - Oil Jars - Pumpout Sub - XO - 12 X 4-3/4" DC's. Total Length: 401.93'. 15:30 - 18:30 3.00 PULL P DECOMP RIH wi BHA #2 on 4" DP to 7,600' 18:30 - 20:00 1.50 PULL P DECOMP M/U Top Drive, Established Pararmeters, Pump Rate 3.3 bpm at 240 psi, String Wt. Down 155,000#, String Wt. Up 158,000#, Rotary String Wt. 156,000#, Rotary Torque 2,000 ftllbs at 25 rpm. Slack Off Without Rotary t/7,650', Engage Roatary at 5 rpm and Continue to RIH, Tag Fish at 7,658', Observe Pressure Increase, Shut Down Pumps, Rotate Over Fish t/ 7,664'. P/U t/175,000# and Trip Open Jars. Slack Off t/ 165,000#. Reverse Rotate at 5 rpm, String Broke Free at 7-1/2 rds. with 5,000 ft/lbs Torque. Continue Appyling Left Hand Turn for a Total of 15 rds. P/U to 175,000#. Slack Off to 170,000# and Apply 3 rds. to Left. Work Pipe from 155,000# to 185,000#. Apply 3 rds. to Left (1 turn Back) and Work Pipe. Apply 3 rds. (1 turn back) and Work Pipe to 195,000#, P/U to 210,000# and Apply 3 rds. to Left and Trap Torque. Work Pipe and Set Jars Off at 175,000#. Slack Off to 150,000#, Apply 3 rds to Left, Trap Torque and P/U, Pipe Came Free at 185,000#. Break Circulation at 3.3 bpm I 240 psi. 20:00 - 23:30 3.50 PULL P DECOMP POH wi BHA #2, Left 1.5' Lower Section of Bumper Sub and Overshot Assy. That is Latched onto Tbg. Cut Off Jt. at 7,658' 23:30 - 00:00 0.50 PULL P DECOMP UD Bumper Sub, Clear and Clean Floor 3/31/2005 00:00 - 01 :00 1.00 PULL P DECOMP Slip and Cut Drlg. Line 01 :00 - 02:00 1.00 PULL P DECOMP PJSM-Build Overshot BHA #3, 5-3/4" Cut Lip Guide-Bowl-Overshot Extension-Top Sub-Bumper Sub-Oil Jar-XO-12 x 4-3/4" DC's = 396.52' 02:00 - 05:30 3.50 PULL P DECOMP RIH wi Overshot BHA 3# on 4" DP to 7,600' 05:30 - 06:00 0.50 PULL P DECOMP M I U Top Drive, Established Pararmeters, Pump Rate 3.5 bpm at 280 psi, String Weight Up 160,000#, String Weight Down 155,000#, String Weight Rotating 158,000#. RPM 25, Rotary Torque 2,000 ft Ilbs. Washed Down to 7,650', Engaged Rotary at 5 rpm and Continued to RIH, Tagged BHA Fish at 7,655', Observed Pressure Increase, Shut Down Pump, Rotated Over Printed: 4/11/2005 10:10:22 AM ) ) Page4oft1 Legal Well Name: 11-37 Common Well Name: 11-37 Spud Date: Event Name: WORKOVER Start: 3/27/2005 End: 4/9/2005 Contractor Name: DOYON Rig Release: 4/9/2005 Rig Name: DOYON 16 Rig Number: · Date From;. To Houts Task Code NPT Description Of Operations .. 3/31/2005 05:30 - 06:00 0.50 PULL P DECOMP Fish to 7,658'. PI U with 15,000# Overpull and Bled Open Jars. Slacked Off to 5,000# Overpull. Set Slips. 06:00 - 06:30 0.50 PULL P DECOMP Held PJSM wi Rig Crew, Schlumberger, Toolpusher and Drilling Supervisor. 06:30 - 07:00 0.50 PULL P DECOMP R I U Schlumberger E-Line Equipment. M I U Single Strand 80 grain String Shot and Tools. 07:00 - 08:30 1.50 PULL P DECOMP RIH wi Schlumberger E-Line wi CCL and String Shot. Tagged Up at 7,735', PI U and Worked Down to 7,748', PI U to 7,600', RIH Slowly Through Tubing Patch to 7,816'. Logged Up and Correlated to Depth per Tubing Tally. Good Indications of Collars, BHA and Tubing Patch. Logged Up on Depth, CCL at 7,706', CCL to String Shot Stand Off 6', Placed String Shot from 7,712' to 7,718', Across Tubing Collar at 7,715'. Worked 5 Left Hand Turns into Drill String and Locked Table. Fired String Shot, Good Indication Shot Fired, Lost All Torque in String. 08:30 - 09:00 0.50 PULL P DECOMP POH wi Schlumberger E-Line. RID E-Line Sheaves and LID Euipment. 09:00 - 12:00 3.00 PULL P DECOMP Work 4 Additional Left Hand Turns into String. P/U wi No Overpull. POH wi 4" DP. 12:00 - 14:00 2.00 PULL P DECOMP POH wi BHA. Stand Back DC's, B/O and LID BHA #3 Overshot Assy., B/O and LID Overshot Assy #2, B/O and LID 4-1/2" Tbg. Cut Jt. & 1 x 4-1/2" Tbg. Jt. 14:00 - 14:30 0.50 PULL P DECOMP Clear and Clean Rig Floor 14:30 - 15:00 0.50 PULL P DECOMP Serviced Top Drive 15:00 - 15:30 0.50 PULL P DECOMP PJSM-R/U 2-7/8" DP Handling Equipment 15:30 - 17:00 1.50 PULL P DECOMP M/U BHA #4, Weatherford Retrieving Tool-XO-3 x 2-7/8" DP Jts.-XO-Bumper Jars-Oil Jars-Pump Out Sub-XO-12 x 4-3/4" DC's = 493.95' 17:00 - 19:30 2.50 PULL P DECOMP RIH wi BHA #4 on 4" DP. t/7,700' 19:30 - 22:00 2.50 PULL P DECOMP M/U Top Drive, Establish Parameters, Break Circulation at 2 bpm 1220 psi., String Wt. Up 160,000#, String Wt. Dn. 155,000#, Rotary String Wt. 158,000#, Rotary 10 rpm I 2,000 ftllbs. String Torque. Slack Off and Tag at 7714'. P/U 15,000# Overpull and Trip Open Jars. Work Pipe f/160,OOO# t/ 200,000#. Break Circulation and Released Latch Tool. Confirm Tool Functioning Properly wi Weatherford Representative. Relatch onto Pkr. and Work Pipe wi Maximum Overpull of 80,000# wi No Pipe Movement. Start Jarring Process wlo Success. Pump Off Tool. 22:00 - 00:00 2.00 PULL P DECOMP POH wi BHA #4 on 4" DP. Wet Trip. Notified Spill Hot Linet 5700 at 2215 hrs. Discussed Wet Trip Conditions with Jack Bowlend. 4/1/2005 00:00 - 01 :00 1.00 PULL P DECOMP POH wI BHA #4 on 4" DP. Wet Trip. Notified Spill Hot Line at 5700. Discussed Wet Trip Conditions with Jack Bowlend. 01 :00 - 02:00 1.00 PULL P DECOMP POH wi BHA #4, Stood Back DC's, B/O and UD Bumper Sub, Oil Jar, 3 x 2-7/8" Pac DP, Weatherford Retrieving Tool. Left 4.5" Eclipse Patch Pulling Tool in Packer. 02:00 - 06:00 4.00 PULL P DECOMP Held Conference Calls with Weatherford, SChlumberger, Wells Group, Paul Chan to Discuss Plan Forward. Waited On Weatherford Retrieving Tools for Pulling Eclipse Retrieving Tool. 06:00 - 07:00 1.00 PULL P DECOMP Held PJSM. M I U BHA; 3-5/8" Taper Tap Retrieving Tool - XO - 1 Joint 2-78" DP - XO - Bumper Sub - Oil Jars - Pumpout Sub Printed: 4/11/2005 10: 1 0:22 AM ) ) PageS ,öf 11 Legal Well Name: 11-37 Common Well Name: 11-37 Spud Date: Event Name: WORKOVER Start: 3/27/2005 End: 4/9/2005 Contractor Name: DOYON Rig Release: 4/9/2005 Rig Name: DOYON 16 Rig Number: . Date From- To Hours Task Code NPT Phase' Descriþtion of Operations 4/1/2005 06:00 - 07:00 1.00 PULL P DECaMP - XO - 12 X 4-3/4" DC's. Total Length: 429.84'. 07:00 - 09:30 2.50 PULL P DECaMP RIH wi BHA on 4" DP to 7,700'. 09:30 - 10:00 0.50 PULL P DECaMP M I U Top Drive, Established Parameters: String Weight Up 160,000#, String Weight Down 155,000#, String Weight Rotating 160,000#, 20 rpm, Torque 2,500 ft Ilbs. RIH w/1 0 rpm, Torque 2,000 ft Ilbs, Tagged Eclipse Retrieving Tool at 7,714', Rotated Down, Stacked 5,000# on Tool, Screwed into Tool, P I U wi 2,000# Overpull, Set Down at 10 rpm, Stacked 5,000# on Tool. PI U Very Slowly w/15 rpm, Unscrewed Eclipse Retrieving Tool from Tubing Patch Packer. P / U 10', No Overpull. 10:00 - 13:00 3.00 PULL P DECOMP POOH wi 4" DP. 13:00 - 14:00 1.00 PULL P DECaMP POOH wi BHA, Stood Back DC's, B I 0 and LID Taper Tap Tool. Recovered Eclipse Packer Retrieving Tool. Lost 1 Dog Slip, 1-3/4" x 4". 14:00 - 14:30 0.50 PULL P DECaMP Cleaned and Cleared Rig Floor. 14:30 - 15:30 1.00 PULL P DECaMP Held PJSM. M I U Overshot BHA: 5-7/8" Cut Lip Guide - Bowl - Extension - Top Sub - Bumper Sub - Oil Jars - Pumpout Sub - XO - 12 X 4-3/4" DC's. Total Length: 397.96'. 15:30 - 17:30 2.00 PULL P DECaMP RIH wi 0 I S BHA on 4" DP. tl7,700' 17:30 - 18:30 1.00 PULL P DECaMP MIU Top Drive, Establish Parameters, Break Circulation at 3.5 bpml 300 psi. String Wt. Up 160,000#, String Wt. Down 155,000#, Rotary String Wt. 157,000#, Rotary 20 rpm/2,000 ftllbs Torque. RIH Circulating at 3.5 bpm/300 psi. and Rotating at 20 rpm, Tag at 7,715', Observe Pressure Increase tl400 psi., Shut Down Pumps. Continue in Hole Rotating tl7,718, Shut Down Rotary and SIO tl7,7120', Btm'd Out on Top Sub. PIU Slowly, Observe No Overpull, Failed to Latch, Repeat Process 2 More times wlo Success. 18:30 - 20:30 2.00 PULL P DECOMP POH wi Overshot BHA #5 on 4" DP. 20:30 - 21 :30 1.00 PULL P DECaMP POH wi BHA, Stood Back DC's, BIO Cut Lip Guide and Remove 5.0" Grapple, 1 Complete and 1 Partial S.S. Control Line Bands Stuck In Grapple. BIO and UD Bowl-Overshot Extension and Top Sub. 21 :30 - 22:00 0.50 PULL P DECOMP PIU and MIU Mill ShoelOvershot BHA #6. Mill Shoe-Bushing-Bowl- Bushing-Bowl-Overshot Extension-Top Sub-Bumper Sub-Oil Jar-XO-12 DC's. Total Lenght: 402.67' 22:00 - 22:30 0.50 PULL P DECaMP Service Top Drive, Crown, Blocks and Drawworks 22:30 - 00:00 1.50 PULL P DECaMP RIH wi Mill Shoel Overshot BHA #6 on 4" DP 41212005 00:00 - 01 :30 1.50 PULL P DECOMP RIH wi Mill Shoel Overshot BHA #6 on 4" Dp tI7,700' 01 :30 - 03:30 2.00 PULL P DECOMP MIU Top Drive, Establish Parameters, Break Circulatiion 5 bpml 600 psi. String Wt. Up 160,000#, String Wt. Dn. 155,000#, Rotary Wt. 157,000#. Rotary 60rpm/3,OOO ftllbs Torque. Wash Down t/7,715'. Mill 4-1/2" Tbg. Collar f/7,715'- tI 7,716'. Weight On Mi1l3/5K, Torque On Btm. 3/5K. Continue in Hole t/7,725'. PIU 15,000# Overpull and Trip Open Jars. 03:30 - 04:00 0.50 EVAL P DECOMP Held PJSM. R I U Schlumberger E-Line Unit and Sheaves. M I U CCL Tool and Weight Bars. 04:00 - 05:00 1.00 EVAL P DECaMP RIH wi Schlumberger CCL Log wi Weight Bars to 8,564'. Tagged Up at 8,564'. Attempted to Work Through Obstruction without Success. POOH wi E-Line. 05:00 - 05:30 0.50 PULL P DECaMP Cleared Rig Floor, Schlumberger M I U 1 Strand 80 grain String Shot to CCL Tool. Printed: 4/11/2005 10:10:22 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-37 11-37 WORKOVER DOYON DOYON 16 Start: 3/27/2005 Rig Release: 4/9/2005 Rig Number: Spud Date: End: 4/9/2005 . . .. From-To ' , , 'Date Hours Task Code NþT ' Description of Opera.tions 4/2/2005 05:30 - 07:00 1.50 PULL P DECOMP RIH wi Schlumberger E-Line wi CCL and String Shot to 7,950'. Logged Up and Correlated to CCL Log 31 30 I 2005, Logged Up on Depth, CCL at 7,816', CCL to String Shot Stand Off 3', Placed String Shot from 7,819' to 7,831', Across Tubing Collar at 7,825'. Attempted to Work 5 Left Hand Turns into Drill String Lost All Torque, Attempted to Work Left Hand Torque into Drill String without Success. POOH wi Schlumberger. Stood E-Line Tools Back. 07:00 - 08:00 1.00 PULL P DECOMP M I U to Drill String w/1 Joint of 4" DP. Worked String and Reset Grapples wi 65,000# Overpull. Worked 5 Turns of Left Hand Torque into Drill String Successfully, Allowed Torque to Relax. B I 0 and LID 1 Joint of 4" DP, M I U Packoff and Pumpin Sub. 08:00 - 09:30 1.50 PULL P DECOMP RIH wi Schlumberger E-Line wi CCL and String Shot to 7,950'. Logged Up and Correlated to CCL Log 3 I 30 I 2005, Logged Up on Depth, CCL at 7,816', CCL to String Shot Stand Off 3', Placed String Shot from 7,819' to 7,831', Across Tubing Collar at 7,825'. Attempted to Work 5 Left Hand Turns into Drill String Lost All Torque, Attempted to Work Left Hand Torque into Drill String without Success. POOH wi Schlumberger. Stood E-Line Tools Back. 09:30 - 10:00 0.50 PULL P DECOMP M I U to Drill String w/1 Joint of 4" DP. P I U on String, No Overpull, Set Down on Fish, Stacked 10,000# on Overshot. PI U with No Overpull, Engaged Pump, 4.5 bpm, 450 psi, Set Down, No Pump Pressure Increase. Shut Down Pump, B I 0 and LID 1 Joint 4" DP. Blew Down Top Drive. 10:00 - 10:30 0.50 PULL P DECOMP RID Schlumberger E-Line Equipment. 10:30 - 13:00 2.50 PULL P DECOMP POOH wi 4" DP. 13:00 - 14:00 1.00 PULL P DECOMP POOH wi BHA, Racked Back 4-3/4" DC's. B I 0 and LID Jars and Bumper Sub. 14:00 - 15:00 1.00 PULL P DECOMP BID and LID Overshot and Mill Shoe Assy w/1 Joint 4-1/2" Tubing. POOH, LID 4-1/2" Tubing Fish. Total Recovery: 3 Joints 4-1/2" 12.6# 13Cr80 NSCT Tubing, GLM Assy, Tubing Patch -(Top Packer - 2 x 2-7/8" PupJoints - Snap Latch Seal Assy) Note: Missing Lower Packer Assy of Tubing Patch. 15:00 - 16:00 1.00 PULL P DECOMP Held PJSM, Slipped and Cut Drilling Line. 16:00 - 17:00 1.00 PULL P DECOMP Held PJSM wi Rig Crew, Schlumberger Crew, Toolpusher and Drilling Supervisor. R I U Schlumberger E-Line Equipment. Set Lubricator in BOP Stack. M I U Gauge Ring and Weight Bars. 17:00 - 19:00 2.00 PULL P DECOMP RIH wi Schlumberger 3.77" Gauge Ring with CCL to 7,866', Work Through Top of 4-1/2" Tbg. Stub. Continue to RIH and Tag at 8,564'. Logged Up and Correlated to CCL Log 4/1/05. POH wi Gauge Ring. BIO and UD Gauge Ring Tools 19:00 - 21 :00 2.00 PULL P DECOMP PJSM-M/U 2 x 80 Grain Strand String Shot with CCL and RIH t/ 8,564'. Logged Up to Correlate with CCL Log 4/1/05. Position String Shot Across Interval fl 8,549'- t/ 8,562' and Fire Shot. POH wi String Shot Assy. Shot Successful, BIO and UD Tools. 21 :00 - 00:00 3.00 PULL P DECOMP PJSM-M/U 3-5/8" Chemical Cutter with CCL RIH t/7,866', Work into Tbg. Stub and Continue to RIH t/8,564'. Logged Up and Correlated with CCL 4/1/05 Log. Position Chemical Cutter in Tension at 8,560' and Fire. POH with Cutter. RID E-Line Printed: 4/11/2005 10:10:22 AM ) ) SPEXPLORATION Operatiol'1s·Surnrt'laryR~port Legal Well Name: 11-37 Common Well Name: 11-37 Spud Date: Event Name: WORKOVER Start: 3/27/2005 End: 4/9/2005 Contractor Name: DOYON Rig Release: 4/9/2005 Rig Name: DOYON 16 Rig Number: Date From':'To HoUrs Task Code NPT 4/2/2005 21 :00 - 00:00 3.00 PULL P DECaMP Tools and Equipment 4/3/2005 00:00 - 00:30 0.50 PULL P DECaMP R / D Schlumberger Tools and Equipment, Cleared and Cleaned Floor 00:30 - 02:00 1.50 PULL P DECaMP Held PJSM. M I U Spear BHA #7, Spear, Dressed wi 3.947" Grapples - Bumper Sub - Oil Jars - Pump Out Sub - XO - 12 X 4-3/4" DC's. Total Length 398.36' 02:00 - 05:00 3.00 PULL P DECOMP RIH wi Spear BHA #7 on 4" Dp V 7,810' 05:00 - 05:30 0.50 PULL P DECOMP M I U Top Drive, Established Parameters, Pump Rate 3 bpm, 380 psi. String Weight Up 162,000#, String Weight Down 155,000#, RIH and Tagged 4-1/2" Tbg Top at 7,867'. Worked Spear Through Tbg. Top and Engaged Grapples 5' into Tbg at 7,872'. PI U String wi 7,000# Overpull, POOH V 7,845'. 05:30 - 06:00 0.50 PULL P DECOMP Circulated Bottoms Up at 8 bpm, 2,100 psi. 06:00 - 09:00 3.00 PULL P DECOMP POOH wi 4" DP. 09:00 - 09:30 0.50 PULL P DECaMP POOH w/ BHA, Racked Back 4-3/4" DC's, B I 0 and LID Bumper Jars and Oil Jars. 09:30 - 11 :30 2.00 PULL P DECOMP R I U 4-1/2" Tubing Handling Equipment. POOH, B I 0 and L I D 16 Joints 4-1/2" 12.6# 13Cr80 NSCT Tubing, 1 - GLM Assy, 4-1/2" Cut Joint = 6.26'. 11 :30 - 12:00 0.50 PULL P DECOMP RID 4-1/2" Tubing Handling Equipment, Cleared and Cleaned Rig Floor. 12:00 - 12:30 0.50 PULL P DECOMP Held PJSM, R I U 2-7/8" DP Handling Equipment. 12:30 - 13:00 0.50 PULL P DECOMP M I U Eclipse Packer Retrieving BHA: Weatherford Packer Retrieving Tool - XO - 5 X 2-7/8" DP Jts - XO - Bumper Jars - Oil Jars - Pump Out Sub - XO - 12 X 4-3/4" DC's = 556.46' 13:00 - 15:00 2.00 PULL P DECOMP RIH w/ Pkr Retrieving BHA on 4" DP to 8,500'. 15:00 - 15:30 0.50 PULL P DECOMP M I U Top Drive, Established Parameters, String Weight Up 173,000#, String Weight Down 163,000#, String Weight Rotating 170,000#,15 rpm, Torque 2,500 ft Ilbs. RIH and Tagged Up at 8,555'. Stacked Out 10,000# on Tool, PI U with No Overpull. Slowly Rotated in Hole, Stacked 3,000# on Tool, Killed Rotation. Stacked Out Total 1 0,000# on Tool, PI U with No Overpull. Repeated x 3, with No Overpull. Dropped Dart and Pumped Open Baker's Pump Out Sub. 15:30 - 20:30 5.00 PULL P DECaMP POOH wi Weatherford Eclipse Retrieval Tool on 4" DP. Drill Pipe Pulled Wet First 15 Stands. See Remarks. Did Not Retrieve Patch Packer. Retrival Tool was Plugged Off with Sand, Paraffin, Rust. B/O and UD Packer Retrieval Tool and 5 Jts. 2-7/8" Pac DP. 20:30 - 21 :00 0.50 PULL P DECOMP Clear and Clean Floor 21 :00 - 21 :30 0.50 PULL P DECOMP PIU and MIU 4-1/2" Overshot BHA: Guide-Bowl-Bushing-Bowl- Overshot Extension, Dressed w/2 x 4.5" Grapples-Top Sub-Bumper Sub-Oil Jar-Pump Out Sub-XO-12 x 4-3/4"DC's. Total Length 402.22' 21 :30 - 00:00 2.50 PULL P DECOMP RIH wi Overshot BHA on 4" DP V 8,450'. 4/4/2005 00:00 - 00:30 0.50 PULL P DECaMP MIU Top Drive, Established Parameters, Break Circulation 5 bpml 580 psi., String Weight Up 170,000#, String Weight Down 160,000#, Rotating String Weight 168,000#, Rotary 20 rpm at 2,500 ftIlbs Torque. Rotate Down f/8,450'· V 8,560'. Observe Printed: 4/11/2005 10:10:22 AM ) ) BPËXPLORATION . . . Op~rationsSllml"lärYFlE!þort . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-37 11-37 WORKOVER DOYON DOYON 16 Start: 3/27/2005 Rig Release: 4/9/2005 Rig Number: Spud Date: End: 4/9/2005 Date· From-To Hours Task Code >NPT' Description Of Oþëratibns 4/4/2005 00:00 - 00:30 0.50 PULL P DECaMP Pressure Increase, Reduce Pump Rate to 2.5 bpm/400 psi. Continue Rotating Down t/ 8,565'. Shut Down Pumps. Rotate Down t/8,568'. Shut Down Rotary. Stack 10,000# Down Weight on Tubing Stub. PIU 30,000# Over and Trip Jars. Slack Off to 5,000# Over. Apply 3 rds. to Left, 1-1/2 rds. Back. 3 rds. to Left, 3 rds. Back. 4 rds. to Left, 4 rds. Back. 5 rds. to Left, 5 rds. Back. 6 rds. to Left, 6 rds. Back. 7 rds. to Left, 1 rd. Back and Lost All Torque. 6,000 ft/lbs.Torque When Connection Broke. Apply 4 rds to Left, 1 Back. 2 rds. to Left, 1/2 rd. Back. PIU wi No Overpull. POH t/8,540'. Break Circulation 5 bpml 580 psi. 00:30 - 01 :30 1.00 PULL P DECaMP Circulate Surface to Surface at 5 bpm/580 psi. 01 :30 - 04:30 3.00 PULL P DECaMP POH wi 4" DP. 04:30 - 05:00 0.50 PULL P DECOMP POH wi Overshot BHA: Stand 4-3/4" DC's Back, Left Top Sub- OS Extension-Bowl-Bushing-Bowl-Guide on Tubing Stub. Total Length 9.2' 05:00 - 05:30 0.50 PULL P DECOMP Service Top Drive, Blocks, Crown and Drawworks 05:30 - 06:00 0.50 PULL P DECOMP RIH wi Bumper Sub-Oil jars-12 x 4/3/4" DC's. Total Length 393.02' 06:00 - 08:00 2.00 PULL P DECOMP RIH wi 4" DP t/ 8,550' 08:00 - 08:30 0.50 PULL P DECOMP M/U Top Drive, Established Parameters, String Weight up 170,000#, String Weight Down 163,000#, Rotary String Weight 168,000#, Rotary 15 rpm, Toruque 2,000 ft/lbs. Pump 5 bpml 560 psi. Washed Down and Tagged Fish. Shut Down Pump. Screwed into BHA Connection on Top Sub. Work Right Hand Torque into String. Worked Overshot Grapples Off of Tubing. P/U wi 7,000# Drag. 08:30 - 09:00 0.50 PULL P DECOMP Circulate Bottoms Up at 10 bpml 2,200 psi. 09:00 - 12:00 3.00 PULL P DECOMP POH wi Overshot BHA on 4" DP. 12:00 - 13:00 1.00 PULL P DECOMP POH wi BHA, Stand Back 4-3/4" DC's. BIO and LID Oil Jars-Bumper Sub-Top Sub-Overshot Extension- Bowl-Bushing-Bowl-G uide. 13:00 - 14:00 1.00 PULL P DECOMP Clear and Clean Floor 14:00 - 14:30 0.50 PULL P DECOMP PJSM-Pulled Wear Ring, Installed Test Plug wI Test Jt., RIU BOPE Test Equipment. 14:30 - 21 :00 6.50 BOPSUR P DECOMP Test BOPE's: Test Annular, Blind and 3-1/2" x 6" Variable Rams, Choke and Kill Line Valves, Choke Maniflod Valves, Floor Safety Valves and Top Drive IBOP Valves t/250 psi. Low and 3,500 psi High, Each Test Held 5 min. for Low test and 5 min. for High Test. Upper IBOP Failed, Repaired and Retested, OK. AOGCC Witness of Test Waived By Jeff Jones. BOPE Test Witnessed By BP Supervisors Casey Galloway and Rodney Klepzig. 21 :00 - 21 :30 0.50 BOPSUP P DECOMP RID Test Equipment, Remove Test Plug, BIO Test Plug and UD Test Jt., Install Wear Ring 21 :30 - 23:30 2.00 PULL P DECOMP PJSM-P/U and M/U Milling BHA: 6" Shoe-Pup. Jt.-Washpipe-Washover Boot Basket-Bumper Sub-Oil jars-XO-12 x 4-3/4" DC's. Total Length 433.18' 23:30 - 00:00 0.50 PULL P DECOMP RIH wi Mill Shoe On 4" DP. 4/5/2005 00:00 - 03:00 3.00 PULL P DECOMP RIH wi 6" Mill Shoe BHA On 4" DP t/8,520' 03:00 - 04:00 1.00 FISH P DECOMP M/U Top Drive, Established Parameters, Break Circulation 5 bpm/630 psi., String Weight Up 166,000#, String Weight Down 162,000#, Rotary String Weight 165,000#, Rotary 50 rpm, Printed: 4/11/2005 10: 1 0:22 AM ) ') . BP EXPLORATION OpE!rations SÜrfimary Reþort Þage90f11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-37 11-37 WORKOVER DOYON DOYON 16 Start: 3/27/2005 Rig Release: 4/9/2005 Rig Number: Spud Date: End: 4/9/2005 From· :i;.. ì 0 Hours ìask · Code NPT Phasé ·Desc þtiOh QfOperations 4/5/2005 03:00 - 04:00 1.00 FISH P DECOMP Torque 3,000 ft/lbs. Wash Down t/8,555', Rotate Down t/ 8,560'. Clean Out t/8,595'. Mill 4-1/2" Tubing Collar t/8,596'. Pumping Hi-Vis Sweeps Every 15' and When Done Milling 4-1/2" Collar 04:00 - 05:00 1.00 PULL P DECOMP Circulate Hi-Vis Sweep Surface to Surface at 9 bpm/1,850 psi. B/O Top Drive and Blow Down Same 05:00 - 08:00 3.00 PULL P DECOMP POH w/ Milling BHA on 4" DP. 08:00 - 09:00 1.00 PULL P DECOMP POH wi BHA, Stand Back 4-3/4" DC's. B/O and LID Milling BHA. Retrieved 4-1/2" Cut Off TBg. Jt. Length 35.21' 09:00 - 09:30 0.50 PULL P DECOMP Clear and Clean Rig Floor 09:30 - 10:30 1.00 PULL P DECOMP PJSM-P/U and M/U Packer Milling BHA; Packer Mill (stinger 1.26')-3 ea. Boot Baskets-Bit Sub-Bumper Sub-Oill Jar-XO-12 x 4-3/4" DC's. Total Length 406.99' 10:30 - 15:00 4.50 PULL P DECOMP RIH wi Pkr. Milling BHA on 4" DP t/8,575' 15:00 - 17:45 2.75 FISH P DECOMP M/U Top Drive, Established Parameters, Pump 6 bpm/780 psi, String Wt. Up 172 K, String WT. Dn. 162 K, Rot. String Wt. 170 K, Rotary 60 rpm, Off Btm Torque 2,500 ft/lbs. Mill fl 8,596' to . 8,608' and packer dropped free @ 1740 hrs. Lost Circulation occurred shortly after milling thru the Seal Section. SID pump and continued to Dry Drill. Required 35 Bbls to fill after 10 minutes of dry drilling. SID pump and resume dry drilling. Estimated fluid loss rate is 1-1/2 BPM after two cycles of pump SID followed by hole fill. 17:45 - 18:30 0.75 FISH P DECaMP Gas circulated to surface just after the packer dropped free. RIH -15' to get full joint across BOP stack, then circulate until gas out of returns. 18:30 - 19:30 1.00 FISH P DECOMP P/U DP from Pipe shed and push milled-up packer to 9,144' 19:30 - 22:30 3.00 FISH P DECOMP POH wi Pkr. Mill on 4" DP. 22:30 - 23:30 1.00 FISH P DECOMP POH wi BHA; Stand Back 4-3/4" DC's, B/O and UD Milling Assy 23:30 - 00:00 0.50 FISH P DECOMP P/U and M/U Spear BHA; Spear-Bumper Sub-Oil Jar-Pump Out Sub- XO-12 x 4-3/4" DC's. Total Length 397.84' 4/6/2005 00:00 - 02:30 2.50 FISH P DECOMP RIH wi Spear BHA on 4" DP. 02:30 - 03:30 1.00 FISH P DECOMP PJSM-Slip and Cut Drlg. Line. 03:30 - 04:00 0.50 FISH P DECOMP RIH wi 4" Dp t/9,040'. 04:00 - 05:00 1.00 FISH P DECOMP M/U Top Drive, Establish Parameters, Pump 4 bpm/570 psi. String Wt. Up 186K, String Wt. Dn. 160K. Slack Off and Tagged at 9,144'. Observed Pressure Increase, Shut Down Pumps. Continue to Slack Off Setting 15,000# Down on Fish. PIU 75,000# Over and Trip Jars. Work Pipe f/9,144'- t/9,040'. Intermediately Pulling 100,000# Over and Tripping Jars. String Freed up after 9,040'. 05:00 - 09:00 4.00 FISH P DECOMP POH wi Fish on 4" DP. Hit tight spot @ -8,475' and worked pipe through with jars and overpull to 50 to 80K. Continue POOH wi no problems. 09:00 - 10:00 1.00 FISH P DECOMP Break out and UD BHA. Recovered all of the fish from the Packer to the WLEG. The XN-Nipple is plugged and sand filled the entire length of the 10' pup jt above the XN-Nipple. Will send the nipple to the Baker shop for later break-out. 10:00 - 13:30 3.50 CLEAN P DECOMP M/U BHA #13: 6" Mill Shoe, 5-3/8" Scraper, Boot Baskets, Pump Out Sub, Oil Jar and RIH on 12-DC's, and DP from Derrick to cleanout to +1- 9,100'. Did not encounter any Printed: 4/11/2005 10: 1 0:22 AM ) ) BPEXPLORA TION OperatiQn$ Sum maryRep.ort Page.1 00f11 Legal Well Name: 11-37 Common Well Name: 11-37 Spud Date: Event Name: WORKOVER Start: 3/27/2005 End: 4/9/2005 Contractor Name: DOYON Rig Release: 4/9/2005 Rig Name: DOYON 16 Rig Number: Date Frorn"7To Hours Task Pha.se DesGription of Opera.tions·.. 4/6/2005 10:00 - 13:30 3.50 CLEAN P DECOMP restrictions while RIH. 13:30 - 15:00 1.50 CLEAN P DECOMP Circulated Safe-Clean Pill followed by 40-Bbls Hi-Vis Sweep for a total of 7,800 strokes @ 9-BPM. Final returns were clean seawater. 15:00 - 18:00 3.00 CLEAN P DECOMP POH and SIB DP and DC's in Derrick. Break-out and LID Baker BHA assembly. 18:00 - 19:00 1.00 CLEAN P DECOMP Driller Shut In Well; Reported Seawater Exiting Drill String. M/U circulating line to floor safety valve and check pressures. No SIDP or SICP. Notified 5700 that a 2 bbl. discharge of seawater from DP on the rig floor. Discussed with Jack Bowland the circumstances syrrounding the discharge. Notified AOGCC and BPX HSE Advisor, Anchorage engineer that the well was shut in. Open choke and bring pump rate to 35 spm (3.5 bpm) and atttempt to establish circulation wlo success. Bring pump rate up to 70 spm, still no circulation. Shut down pumps and open annular. No fluid in well bore. Fill hole through Dp with rig pumps and down annulus with trip tank to fill hole. Established circulation and circulated bottoms up. Shut down pumps, monitor well, well static. 19:00 - 20:00 1.00 CLEAN P DECOMP POH wi DP and Clean Out BHA. Stand back 4 3/4" DC's. LID 7" Scraper BHA 20:00 - 20:30 0.50 CLEAN P DECOMP PJSM-M/U Halliburton RTTS and 12 x 4-3/4" DC's. Total Length 386.39' 20:30 - 00:00 3.50 CLEAN P DECOMP RIH wi RTTS on 4" DP t/ 8,500' 4/7/2005 00:00 - 00:30 0.50 EVAL P DECOMP Established Parameters, String Wt. Up 180K, String Wt. Dan. 160K. SIO to 8,528', P/U t/ 8,519'. Set slips, turn string 3 rds. to right, got 1 back. Pull slips and SIO t/ 135,000# down weight. Set slips. Rtts Packer set @ 8,518'. 00:30 - 03:30 3.00 EVAL P DECOMP Close Annular and R/U to Test Casing. Pressure Up t/ 3,500 psi. Observe Pressure Loss of 700 psi/5 Min. R/U Test Chart to Upper Annulus (4-1/2" x 7"). Pressure Up t/ 3,500 psi, Close Kill Line HCR. Pressure Loss 100 psi perl min. Open Kill Line HCR and Repressure t/ 3,500 psi. Pop-Off on Mud Pump Blew. Repair Pop-Off and Retest t/ 3,500 psi. Closed Manual Kill Line Valve. Same Bleed Off Rate. Bled Off Pressure and R/U Rig Test Pump and Retest t/ 3,500 psi. Pressure Loss of 100 psi perl min. 03:30 - 04:00 0.50 EVAL P DECOMP Unseat Rtts and POH t/ 8,422'. Reset RTTS, Install Floor Safety Valve and RIU to Test Casing. 04:00 - 04:30 0.50 EVAL P DECOMP Test Casing t/ 3,500 psi. Bleed Down Rate 100 psi perl min. Bled Off Pressure. RID Test Equipment. 04:30 - 08:00 3.50 EVAL P DECOMP POH wi RTTS t/ 3,500' for Retest. Test good. RIH 10 stands to 4,497' and re-test. Test Good. 08:00 - 10:45 2.75 EVAL P DECOMP Confer wi town and decide to RIH to 8,231' and re-test. Did not hold pressure, but leak-off is reduced to -300 psi/10 minutes. P/U 2-stands to 8,040' and re-test. Test leaked off at -200 psi/10 minutes. 10:45 - 11 :30 0.75 EVAL P DECOMP POH 5-stands and re-test. Test held steady for 30 minutes. 11 :30 - 21 :00 9.50 EVAL P DECOMP POOH and LID DP. Break-out and LID HES RTTS. 21 :00 - 00:00 3.00 EVAL P DECOMP PJSM-R/U Schlumbergher E-Line Unit and Equipment. RIH wi CIBP on GRlCCL Tools. Correlate Depth wi 7" Marker Jts. Made 3' correction. Printed: 4/11/2005 10: 10:22 AM ') ) ·BÞ·EXPLQRATION OpèréltiónsSlIrnmäry Report Pagø1t öf11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-37 11-37 WORKOVER DOYON DOYON 16 Start: 3/27/2005 Rig Release: 4/9/2005 Rig Number: Spud Date: End: 4/9/2005 lDate From.~To Hours Task Code NPT Pha.se . Description öfQperatióhs 4/8/2005 00:00 - 00:30 0.50 EVAL P DECOMP RIH wi E-Line GR/CCL and ICBP t/9,050'. P/U to 8,990' and Set CIBP. POH 100' and RIH and Tag ICBP @ 8,990' to Confirm Setting Depth. 00:30 - 01 :30 1.00 EVAL P DECOMP POH wi E-Line 01 :30 - 02:00 0.50 EVAL P DECOMP RID Schlumberger Equipment and Clear Floor 02:00 - 02:30 0.50 RUNCOMP RUNCMP Pull Wear Ring, M/U Foor Safety Valves to Tbg XO's for Well Control 02:30 - 04:30 2.00 RUNCOMP RUNCMP PJSM-R/U Tubing Handling Equipment and Torque Turn Tools, Install Long Bails And Hang Jt. Compensator 04:30 - 16:00 11.50 RUNCOMP RUNCMP RIH wi 4-1/2 12.6# Cr-80 Vam Top Tubing. Torque all connections to 4,440 ft-Ibs Optimum Torque. 16:00 - 17:00 1.00 RUNCOMP RUNCMP M/U Landing Joint to Tubing Hanger (P/U wt = 123K, SIO wt = 123K) and land Hanger. RILDS. LID Landing Joint. 17:00 - 19:00 2.00 BOPSURP OTHCMP PJSM-P/U TWC and Install, Unable to Test from Below Because of Open Perferations. N/D BOPE's 19:00 - 21:00 2.00 WHSUR P OTHCMP N/U Adaptor Flange and Production Tree 21 :00 - 22:00 1.00 WHSUR P OTHCMP Test Adaptor Flange and Tree t/5,000 psi 22:00 - 23:30 1.50 WHSUR P OTHCMP R/U Circulating Lines t/ Reverse Circulate Down 7" x 4-1/2' Annulus Taking Returns Up 4-1/2" Tbg. Test Lines t/3,500 psi. 23:30 - 00:00 0.50 WHSUR P OTHCMP Reverse Circulate Heated Seawater Down Annulus Taking Returns Off Tubing. 4/9/2005 00:00 - 02:00 2.00 WHSUR P OTHCMP Reverse Circulate 140 bbls 120 deg. Heated Seawater Down 4-1/2" x 7" Annulus at 3 bpm @ 625 psi. Followed By 140 deg. Heated Corrosion Inhibited Seawater. 02:00 - 04:00 2.00 WHSUR P OTHCMP Drop 1-7/8" Ball & Rod. Pressure Up 4-1/2" Tbg. t/3,500 psi to Set Pkr. and Test Tbg. Chart and Hold 30 min. Bleed Tbg. Down t/1 ,500 psi. Pressure Up on Annulus t/ 3,500 psi to Test Pkr. Chart and Hold 30 min. Bleed Off Tbg. Pressure, DCk Sheared at 2,800 psi. Circulate Down Tbg. and Annulus @ 2 bpm/600 psi to Confirm Valve Fully Opened. 04:00 - 05:30 1.50 WHSUR P OTHCMP R/U Hot Oil and Test Lines t/3,000 psi. Pump 100 bbls Diesel Down 4-1/2" x 7" Annulus @ 2 bpm/850 psi 05:30 - 07:30 2.00 WHSUR P OTHCMP U-Tube Diesel from Annulus to Tbg. 07:30 - 08:00 0.50 WHSUR P OTHCMP P/U and install BPV and test to 1,000 psi. 08:00 - 12:00 4.00 WHSUR P POST Secure Cellar and Tree and Rig down Drilling Sub. Release rig @ 1200 hours. Printed: 4/11/2005 10:10:22 AM WELLHEAD = FMC ACTUATOR = bkr C • 1 -37 Completion• BF. aEV _ Revised DRLG DRAFT 05/05/05 KOP = 6970 VW • • Max Angle = 94 @ 9483' 4 • • Datum MD = 9120' 1 , •• Datum TV D = 8800' SS ► • � 4 *64 N ' , •I I 2087' H4 -1/2" X NIP, ID = 3.813" I 414 •4 •4 1 • • 4 • � • 4 • •4 • GAS LIFT MANDRELS • 9 -5 /8" CSG, 40 #, L -80, ID = 8.835" H 3809' l • •�4 • ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2978 KBG DOME BK 16 04/11/05 4 4081 KBG DMY BK 0 3 5890 KBG SO BK 20 04/11/05 2 6580 KBG DMY BK 0 Minimum ID = 3.725" @ 7567' 1 7309 KBG DMY BK 0 4 -1/2" HES XN NIPPLE I ' I 7460' I_l 1 1/2" HES X NIP, ID= 3.813" I ► >K,/-I 7481' H7" X 4 -1/2" BAKER S -3 PKR I I I I 7546' H4-1/2" HES XN NP, ID= 3.813" I 14 -1/2" TBG,12.6 #,13Cr80,.0152 bpf, ID=3.958 "I---I 7558' I I 7558' H4 -1/2" WL.EG I 1 17" HES CIBP I I 8990' I ��--- ff 9205' I "X 4 -112" TW SS HORIZONTAL PKR. • • • • 9252' H 4-1/2' PORTED JOINT I PERFORATION SUMMARY REF LOG: LDT /CNL ON 11/20/96 1111°11*. 9272' H 4" BAKER CIBP I ANGLE AT TOP PERF: 40 @ 8800' • • • • 9293' IH 4-1/2' PORTED JOINT I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE • 9327' H 7" CSG,29 #, 13CR -80,1 D = 6.814" 3 -3/8" 6 8800 - 8808 O 09/25/97 3 -3/8" 12 8812 - 8814 O 07/17/97 3 -3/8" 6 8815 - 8820 O 12/10/01 3 -3/8" 6 9160 - 9165 O 08/23/97 I 3 -3/8" 4 9291 - 9292 O 05/10/97 3 -3/8" 0 9293 - 10417 SLTD 12/01/96 I I I V /VV•y.•.v, PBTD H 10416' I 4 -1/2 "12.6# CR80 LINER 1D= 3.958" I 10440' '••••••• ∎•••••••. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/01/96 ORIGINAL COMPLETION 06/01/03 MH/TLP GLV CIO WELL:11 -37 02/20/01 SIS -MD FINAL 1 05/03/05 DTR/PJC GLV C/O (4/11/05) PERMIT No:1961740 01/02/02 RN/TP CORRECTIONS 05/05/05 Hubble RWO Corrections API No: 50- 029 - 22716 -00 09/29/02 MH/KAK GLV C/O SEC 34, T11 N, R15E, 4029.09' FEL & 4884.04' FNL 03/15/03 PWETLH SET CHROME PATCH 04/06/03 JJ /KAK GLV C/O I BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ SET PATCH Pull tubing _ Alter casing _ Repair well _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development mX RKB 53 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 652' FNL, 4639' FEL, Sec. 34, T11 N, R15E, UM (asp's 708212, 595109,,1) i 11-37 At top of productive interval"~ 9. Permit number / approval number 358' FNL, 5010' FEL, Sec. 27, T11 N, R15E, UM (asp's 707676, 5956652) 'J 196-174 At effective depth 10. APl number 320' FNL, 4956' FEL, Sec. 34, T11 N, R15E, UM (asp's 707886, 5951414) 50-029-22716-00 At total depth 11. Field / Pool 4886' FNL, 4031' FEL, Sec. 27, T11 N, R15E, UM (asp's 708789, 5952153) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10440 feet Plugs (measured) 4-1/2" ClBP @ 9272' MD. (05/08/1997) true vertical 8858 feet Effective depth: measured 9272 feet Junk (measured) true vertical 8887 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 260 sx ArcticSet 145' 145' Surface 3774' 9-5/8" 1640 sx Fondu, 400 sx 3809' 3803' PF 'C' Production 9292' 7" 500 sx Class 'G', 300 sx 9327' 8890' PF 'C' Liner 1235' 4-1/2" 325 sx Class 'G' 9205'- 10440' 8876'- 8858' Perforation depth: measured Open Perfs 8800'-8808', 8812'-8814', 8815'-8820', 9160'-9165', Open Perfs Below CIBP 9291'-9292'. Slotted Liner Isolated Below CIBP 9293'-10417'. true vertical Open Perfs 8679'-8695', 8689'-8690', 8691'-8695', 8865'-8867', Open Perfs Below CIBP 8889'-8889', Slotted Liner Isolated Below CIBP 8889'-8856'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR-80, TBG @ 8666' MD. ~-' ,. ;.~'~ ;-'-.:-, ;...:-':':~ ~ ~,~ .'i'--.:~ ~,~ Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker 'S-3' Packer @ 8609'. ~! ~'---~-~'"-~-~J?~-----'~' '"'-" 4-1/2" Camco BAL-O SSSV Nipple @ 2209' MD. 13. Stimulation or cement squeeze summary il'~R Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure -'~ ".~,~-"" ¢'~- ......... -'~' '" ~'" ;; ' ;~i~, ~i,.'_}P. ." 14. Representative Daily Averaqe Production or Iniection Data '~- OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SHUT-IN Subsequent to operation 03/18/2003 1582 26977 623 1162 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __ Oil __X Gas __ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~:~~.~,~..~,,,~ Title: TechnicalAssistant Date March 20, 2003 DW RS~ ~ ~=._.~e a]/ne . chnorr Prepared by DeWa]/ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE 11-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/14/2003 PATCH TUBING / LINER: AC-EVAL; AC-FLUID LEVEL 03/15/2003 PATCH TUBING / LINER: PATCH TUBING / CASING 03/15/2003 PATCH TUBING / LINER: MIT-IA; PATCH TUBING / CASING 03/16/2003 PATCH TUBING / LINER: AC-MONITOR EVENT SUMMARY 03/14/03 TIO= 160/350/600 TBG & IA FLs for TBG Patch. TBG FL @ surface; IA FL @ 640'. 03/15/03 4.5" CHROME ECLIPSE PATCH SET OVER GLM #4 TO STOP LEAK @ 7775.5'. PATCH WAS 37' IN LENGTH, MIN ID 2.255", MAX O.D. WAS 3.74" BEFORE SETTING. TIED INTO SWS LDL 12-21-02. TOP OF PATCH AT 7753', BOTTOM PACKER @ 7791' AND TOP PACKER @ 7756'. RDMO. LRS MIT-IA TO 3000 PSI PASSED. WELL RETURNED TO DSO TO POP. 03/15/03 T/I/O=100/300/560 MIT IA to 3000 psi ---PASSED---/PUMP TO ASSIST E-LINE SETTING PATCH. 03/16/03 T/I/O = 130/470/590. MONITOR WHP's. (POST MITIA, TBG PATCH). Fluids Pumped BBLS 25 60/40 METHANOL WATER 25 TOTAL Page I PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 96-174 MWD SRVY R 0-10442 96-174 MWD SRV~f R 0-10440 96-174 BHC/SL ~00-9283 96-174 ON ~800-9297 96-174 CN/LDT U~00-9310 96-~74 MOF~ ~00-9310 96-~74 MCF~ MICRO j.~00-9310 96-174 SSTVD ~000-9330 96-174 ~C ~O~ ~000-~0 96-174 AIT ~000-9330 Page: 1 Date: 11/05/98 RUN RECVD o2/os/97 02/12/97 FINAL 03/07/97 FINAL 03/07/97 FINAL 03/07/97 FINAL 03/07/97 FINAL 03/07/97 FINAL 03/07/97 FINAL 03/07/97 FINAL 03/07/97 FINAL 03/07/97 1 03/07/97 FINAL 03/12/97 FINAL 03/12/97 4-7 04/02/97 10-407 ~'~'COMPLETION DATE // ~3 0/~/ DA~LY WELL OPS R !//~ /~&/ TO /1/~/~/ Are dry ditch samples required? yes ~And received? Was the well cored? yes ~lysis & description received? Are well tests required? ~ ~Received?· .... ~~ Well is in compliance / ~ ~ / Inftial COMMENTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 53' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 4628' NSL, 4639' WEL, Sec 34, T11N, R15E, UM. 11-37 At top of productive interval: 9. Permit number/approval number: 4922' NSL, 5010' WEL, Sec 27, T11N, R15E, UM. 96-174 At effective depth: 10. APl number: ~ 50-029-22716 Attotal depth: 11. Field/Pool: 0 R [ /""' i j"'~~ / iL 393' NSL, 4033' WEL, Sec 27, T11 N, R15E, UM. Prudhoe Bay Oil Pool i - 12. Present well condition summary Total Depth: measured 10440 feet Plugs (measured)Cast Iron Bridge Plug @ 9272' MD. true vertical 8858 feet Effective Depth: measured 9272 feet Junk (measured) true vertical 8887 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 260 Sx Arcticset 110' 110' Surface 3783' 9-5/8" 2231 Sx CS III & 3809' 3803' 335 Sx Class G Production 9302' 7" 320 Sx Class G 9327' 8890' Slotted Liner 1235' 4-1/2" Uncemented 10440' 8858' Perforation Depth measured 9160 - 9165'; 9220 - 9240' (Slotted Liner is isolated below CIBP at 9293- 10417') true vertical 8865- 8867'; 8878- 8882' (Slotted Liner is isolated below CIBP at 8889- 8858') Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80, Tubing @ 8666' MD. i~ ~ C' ~' I V ~__ D Packers and SSSV (type and measured depth) Baker S-3 Packer @ 8609' MD; Camco BaI-O SSSV @ 2209' MD JUL 2 !99 13. Stimulation or cement squeeze summary ,~8~;j¢...~ 0ii & ~.~ ':~ .......... Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut In Subsequent to operation 305 2609 3882 224 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~,.,,~t.,.,,~ ')'~J · ~ Title: Engineering Supervisor Date '~- ,2_... ~-~ ~' -- . Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 11-37 DESCRIPTION OF WORK COMPLETED CTU MARASEAL GEL & CEMENT SQUEEZE FOR GAS SHUTOFF 6/16/98: RIH & tagged PBTD at 9100' MD. 6/17/98: MIRU CTU & PT equipment. RIH w/CT loading the wellbore w/Crude & 1% KCI Water. Tagged PBTD, then PU & pumped gelled sand slurry containing 8300 lbs of sand, to place an isolation sand plug across the open lower perforations located at: 9160 - 9165' MD 9220 - 9240' MD POOH w/CT leaving final TOS at an estimated 8835' MD. RD. 6/19/98: RIH & tagged TOS at 8868' MD. 6120198: RIH w/dump bailer & spotted 3 gallons of liquid sand on top of the sand plug to raise TOS to 8861' MD. 6/22/98: A CTU Acid Wash & Maraseal Gel/Cement Squeeze for Gas Shutoff were performed as follows: MIRU CTU & PT equipment. RIH w/CT loading the wellbore w/1% KCI Water. Tagged TOS at 8857' MD, then PU & reciprocated an acid wash across the open perforation intervals at: 88OO - 88O8' MD 8812 - 8814' MD Pumped: a) 10 bbls 70% Diesel/20% Xylene/10% Musol, followed by b) 15 bbls 12% HCI w/10% Xylene w/3% Acetic Acid, followed by c) 10 bbls 6% HCI- 0.75% HF w/3% Acetic Acid, followed by d) 10 bbls 12% HCI w/10% Xylene w/3% Acetic Acid, followed by e) 22 bbls 2% NH4CI Water, followed by f) 150 bbls 1% KCI Water down tubing & 73 bbls Crude down backside. Swapped to pumping 36 bbls of Maraseal Gel, followed by followed by 35 bbls of Latex Acid Resistive Cement, to squeeze the open perforation intervals (above). Attained a maximum pressure of 2400 psi during the squeeze after several large pressure breaks. Squeeze pressure bled off from 2400 psi to a steady 1624 psi over 75 minutes. Contaminated cement w/biozan & jetted contaminated cement from wellbore to 8762' MD. POOH w/CT. RD. 7/17/98.' RIH w/CT underreamer & reamed cement / sand plug from 8781 to 8868' MD, then jetted sand fill from wellbore to CIBP while circulating biozan & 1% KCI Water, to uncover the lower open perf intervals (above). Tagged CIBP at 9264' MD (CIBP set 5/8/97). POOH w/underreamer. RD. Returned the well to production w/gas lift & obtained a Valid welltest. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIL,,, REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate._ Plugging _ Perforate _X Pull tubing Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_X 53' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic _ Anchorage, AK 99510-0360 service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 4628' NSL, 4639' WEL, Sec 34, T11N, R15E, UM. 11-37 At top of productive interval: 9. Permit number/approval number: 4922' NSL, 5010' WEL, Sec 27, T11N, R15E, UM. 96-174 At effective depth: 10. APl number: 50-029-22716 At total depth: 11. Field/Pool: 393' NSL, 4033' WEL, Sec 27, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10440 feet Plugs (measured) Cast Iron Bridge Plug @ 9272' MD. true vedical 8858 feet Effective Depth: measured 9272 feet Junk (measured) true vedical 8887 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 260 Sx Arcticset 110' 110' Surface 3783' 9-5/8" 2231 Sx CS III & 3809' 3803' 335 Sx Class G Production 9302' 7" 320 Sx Class G 9327' 8890' Slotted Liner 1235' 4-1/2" Un cemented 10440' 8858' Perforation Depth measured 8800 - 8808'; 8812 - 8814'; 9160 - 9165'; 9220 - 9240' (Slotted Liner is isolated below CIBP at 9293 - 10417') true vertical 8679 - 8686'; 8689 - 8690'; 8865 - 8867'; 8878 - 8882'ORIGINAl.. (Slotted Liner is isolated below CIBP at 8889- 8858') Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80, Tubing @ 8666' MD. Packers and SSSV (type and measured depth) Baker S-3 Packer @ 8609' MD; Camco Bal-O SSSV @ 2209' MD. . ,. ': · , 3. Stimulation or cement squeeze summary . · Intervals treated (measured) see attached ~ '~' ' ~' ~ Intervals treated (measured) !4. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 568 772 4043 - 243 Subsequent to operation 6110 21129 3410 - 606 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "'~./~j,~ ~ , ~ Title: Engineering Supervisor Date /¢'"~'- '~ '7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 11-37 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9~25~97: MIRU & PT equipment. Added perforations: RIH w/perforating gun & shot 8' of add perforations as follows: 8800-8808' MD Used a 3-3/8" carder & shot 6 spf at 60 degree phasing at over balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS i. Operations performed: Operation Shutdown _ Stimulate._ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_)( 53' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 4628' NSL, 4639' WEL, Sec 34, T11N, R15E, UM. 11-37 At top of productive interval: 9. Permit number/approval number: 4922' NSL, 5010' WEL, Sec 27, T11N, R15E, UM. 96-174 At effective depth: 10. APl number: 50-029-22716 At total depth: 11. Field/Pool: 393' NSL, 4033' WEL, Sec 27, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10440 feet Plugs (measured) Cast Iron Bridge Plug @ 9272' MD. true vertical 8858 feet Effective Depth: measured 9272 feet Junk (measured) true vertical 8887 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 260 Sx Arcticset 110' 110' Surface 3783' 9-5/8" 2231 Sx CS III & 3809' 3803' 335 Sx Class G Production 9302' 7" 320 Sx Class G 9327' 8890' Slotted Liner 1235' 4-1/2" Uncemented 10440' 8858' Perforation Depth measured 8812 - 8814'; 9160 - 9165'; 9220- 9240'; (Slotted Liner -isolated below ClBP: 9293 - 10417') true vertical 8689 - 8690'; 8865- 8867'; 8878- 8882'; (Slotted Liner - isolated below ClBP: 8889 - 8858') Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 136R-80, Tubing @ 8666' MD. Packers and SSSV (type and measured depth) Baker S-3 Packer @ 8609' MD; Camco BaI-O SSSV @ 2209' MD. Si!:P 9 1997 13. Stimulation or cement squeeze summaryORIGINAL Intervals treated (measured) see attached ' '~.' ~rlcfi.erage Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 547 641 3504 - 235 Subsequent to operation 590 709 3688 - 240 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢,'~ ~- ~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 11-37 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 8~23~97: MIRU & PT equipment. RIH w/perforating gun & shot add perforations as follows: Added perforations: 9160 - 9165' MD Used a 3-3/8" carrier & shot 6 spf at 60 degree phasing at over balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. STATE OF ALASKA AL~,..4KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I1. Operations performed: Operation Shutdown Stimulate.__ Plugging Per/orate _X Pull tubing_ Alter casing _ Repair well_ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 53' RKB ;3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 4628' NSL, 4639' WEL, Sec 34, T11N, R15E, UM. 11-37 At top of productive interval: 9. Permit number/approval number: 4922' NSL, 5010' WEL, Sec 27, T11N, R15E, UM. 96-174 At effective depth: 10. APl number: 50-029-22716 At total depth: 11. Field/Pool: 393' NSL, 4033' WEL, Sec 27, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10440 feet Plugs (measured) Cast Iron Bridge Plug @ 9272' MD. true vertical 8858 feet Effective Depth: measured 9272 feet Junk (measured) true vertical 8887 feet Casing Length Size Cemented Measured depth True vedlcal depth Conductor 110' 20" 260 Sx Arcticset 110' 110' Surface 3783' 9-5/8" 2231 Sx CS III & 3809' 3803' 335 Sx Class G Production 9302' 7" 320 Sx Class G 9327' 8890' Slotted Liner 1235' 4-1/2" Uncemented 10440' 8858' Perforation Depth measured 8812- 8814'; 9220 - 9240'; (Slotted Liner- isolated below CIBP: 9293- 10417') true vertical 8689 - 8690'; 8878 - 8882'; (Slotted Liner- isolated below CIBP: 8889 - 8858') Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80, Tubing @ 8666' MD. Packers and SSSV (type and measured depth) Baker S-3 Packer @ 8609' MD; Camco BaI-O SSSV @ 2209' MD. - 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached O~NIGI~'~kL '~!(-'(~ 7]997 Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 583 771 3726 234 Subsequent to operation 793 582 3704 231 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~ ,~, ~ Title: Engineeri,g Supervisor Date ~:;>" ~"- ~"""~ Form 10-4.04 Rev 06/15/88 SUBMIT IN DUPLICATE 11-37 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/17/97: MIRU & PT equipment. RIH w/perforating gun & shot 2' of add perforations as follows: Added perforations: 8812- 8814' MD (Z2) Used a 3-3/8" carrier & shot 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. ~.~C~ ? !997 ~la[~ .0il .&. Gas Cons. C0mmis~', ~nc_~0rage STATE OF ALASKA ~_ASKA OIL AND GAS CONSERVATION COMMISSION 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: 6. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_X 53' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service _ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 4628' NSL, 4639' WEL, Sec 34, T11N, R15E, UM. 11-37 At top of productive interval: 9. Permit number/approval number: 4922' NSL, 5010' WEL, Sec 27, T11N, R15E, UM. 96-174 At effective depth: 10. APl number: 50-029-22716 At total depth: 11. Field/Pool: 393' NSL, 4033' WEL, Sec 27, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10440 feet Plugs (measured) Cast Iron Bridge Plug @ 9272' MD. true vedical 8858 feet Effective Depth: measured 9272 feet Junk (measured) true vertical 8887 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 260 Sx Arcticset 110' 110' Surface 3783' 9-5/8" 2231 Sx CS 111 & 3809' 3803' 335 Sx Class G Production 9302' 7" 320 Sx Class G 9327' 8890' Slotted Liner 1235' 4-1/2" Uncemented 10440' 8858' Perforation Depth measured 9220- 9240'; (Slotted Liner- isolated below CIBP: 9293- 10417')O~r~iG1NAL true vertical 8878 - 8882'; (Slotted Liner- isolated below CIBP: 8889 - 8858') Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80, Tubing @ 8666' MD. Packers and SSSV (type and measured depth) Baker S-3 Packer @ 8609' MD; Camco BaI-O SSSV @ 2209' MD. 3. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 60 107 238 223 Subsequent to operation 841 1154 3185 233 15. Attachments !16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .Signed "'~,~,f~ "~/7 - ~ Title: Engineering Supervisor Date ,~' ~ ~'-~:~ '7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 11-37 DESCRIPTION OF WORK COMPLETED CIBP INSTALLATION & FRACTURE TREATMENT OF ZONE I 5/8/97: MIRU CTU & PT equipment. Loaded the wellbore w/1% KCl Water, then RIH with a Cast Iron Bridge Plug. Set the CIBP in the blank section of the ported 4-1/2" liner at 9272' MD. POOH w/CT. Rigged down. 5/9/97: RIH w/CT & tagged CIBP. PU & pumped gelled sand slurry containing 24,000 lbs of 20/40 mesh sand to place a sand pack through the ported sub at 9252' MD, to isolate the open hole behind the slotted liner at 9293 - 10417' MD. PU to 3500 psi while pumping sand slurry into the well, and placed 17,500 lbs of sand behind the liner. Followed sand slurry w/biozan to jet sand plug from wellbore to the CIBP. POOH & RD. 5/10/97: RIH w/CTC perforating gun & shot 20' of add perforations at: 9220- 9240' MD (Z1) Used a 3-3/8" carrier & shot the perforations at 4 spf at 180 degree phasing. POOH w/perf gun. RD. 5/13/97: Performed a Zone 1 Hydraulic Fracture Treatment as follows: MIRU & PT equipment to 8900 psi. Pumped the Fracture Treatment using 20/40 mesh proppant, through the open perforation interval (listed above). Pumped: a) 210 bbls 20# Pre Pad Gel @ 6 - 16 bpm, followed by b) Shutdown. Resumed pumping Datafrac: c) 125 bbls 50# Crosslinked Gel @ 15 bpm, followed by d) 147 bbls Flush @ 15 bpm, followed by e) Shutdown. ISlP @ 1926. Pumped Fracture Treatment: f) 25 bbls 50# Crosslinked Pad @ 10 bpm, followed by g) 100 bbls Crosslinked Slurry w/proppant concentrations @ 1 - 10 ppg, followed h) 10 bbls 20# Crosslinked Gelled Flush, followed by i) 137 bbls 20# Gelled Flush @ 5 - 10 bpm, followed by j) Shutdown. ISlP @ 2393. Placed a total of 15,628 lbs of proppant into the formation. Rigged down. ~' 5/14/97: RIH w/CT & jetted a proppant fill cleanout to 9259' MD. 5/16/97: RIH & tagged PBTD at 9250' MD. Placed the well on production w/gas lift & obtained a valid welltest. I:) I~! I I--I-- I IM G WELL LOG TRANSMITTAL To: State of Alaska April 2, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 11-37, RE: AK-MM-60165 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attemion of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22716-00. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company CI Ft I I--I-- I IM G SEFI~JIC~ S WELL LOG TRANSMITTAL To: State of Alaska March 12, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 11-37, AK-MM-60165 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 11-37: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22716-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22716-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia . 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10839 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 3/6/97 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape D.S. 11-37 96376 PEX,AIT,&BHC ~ '~'"~."~--~ 961120 1 D.S. 11-37 96376 PEX-AIT 961120 1 1 D.S. 11-37 96376 PEX-AIT SW IMAGE 961120 I 1 D.S. 11-37 96376 PEX-MCFL 9611 20 I 1 D.S. 11-37 96376 PEX-MCFL MICROLOG 961120 I 1 D.S. 11-37 96376 PEX-COMP NEUTRON LITHODENSITY 961120 1 1 D.S. 11-37 96376 PEX-CNL 961120 1 1 D.S. 11-37 96376 PEX-QUALITY CONTROL LOG 961120 1 1 D.S. 11-37 96376 PEX-SSTVD 961120 I 1 D.S. 11-37 96376 BHC 961120 1 1 D.S. 11-37 96376 PEX-BOREHOLE PROFILE 961120 1 I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ¢ ECE VED DATE: Gas Oor~$. Come.ri A~mo~e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~wMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-174 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 __ _ 50-029-22716 4. Location of well at surface ;~, M::IC,,A~~ 9. Unit or Lease Name 4628' NSL, 4639' WEL, SEC. 34, T11 N, R15E ,/ ,~::"~',':.~'i~,~ i~,~_ . ,~, .~ '-:.. ~ Prudhoe Bay Unit At top of productive interval~?'z"//'"~~?~-!i:/;~- ~'~-'/-~:~~~r~.. 10. Well Number 4922' NSL, 5010' WEL, SEC. 27, T11N, R15E 11-37 At total depth ~']O'~ ~': ..... :~'~ i~' .. 11. Field and Pool ~,h,~ 393' NSL,'~4.6' WEL, SEC. 27, T11 N, R15E ............. _;-.-_-_-.¥;i~ Prudhoe Bay Field/Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 53.50'I ADL 028325 12. Date Spudded11/07/96 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' water depth' if °fish°re 16' N°' °f C°mpleti°nsl 1/26/96 11/30/96 N/A MSL One 17. Total Depth (MD+~T}/D) 18. Plug Back Depth (MD,+,TVD) 19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 10440 8858 FT 10440 8858 FT []Yes [] NO I (Nipple) 2209' MD ~ 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD (DIP/FL), GR, RES, DT, NPHI, DEN, CFTC, CNTC, PEFZ, 23. CASING, LINER AND CEMENTING RECORD CASING SE-FI'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP DO'i-rOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 26' 3809' 12-1/4" 2231 sx CS III, 335 sx Class 'G' 7" 26# / 29# L-80 / 13Cr 25' 9327' 8-1/2" 320 sx Class 'G' 4-1/2" 12.6# L-80/13Cr 9205' 10440' 6" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2", 12.6#, NT13CrS0 8666' 8609' MD TVD MD TVD 9293' - 10417' 8889' - 8858' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 Bbls of Diesel KEL. V EM 27. PRODUCTION TEST t: EB 1 8 1997 Date First Production IMethod of Operation (Flowing, gas lift, etc.) December 8, 1996 I Gas Lift ~,,,,~,,, n;i ~, r~.~:, r:,~,-.~ ¢,nmmissi0n Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF - WATER-BBL CH(~;:~'~'Z~' .... ~",~OO~!~£,RATIO TEST PERIOD I~ i, · Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marke,. 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Shublik 8538' 8441' Top of Sadlerochit 8621' 8520' Zone 3 8672' 8568' Zone 2C 8748' 8636' Zone 2B 8810' 8687' Zone 2A 8951' 8782' Zone 1B 9047' 8829' Zone lA 9206' 8876' 31. List of Attachments Summary of Daily Drilling Reports, Surveys i32. I hereby certify that ihb\foregoir~is~u~l_a~nd correct to the best of my knowledge D~n Storz ~/ (rVW ~~,,~ Title Senior Drilling Engineer Date~' !! Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24.' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO WellName: I 1-37 RigName: Doyon 16 AFE: 4J0340 Accept Date: I 1/06/96 Spud Date: I 1/07/96 Release Date: I 1/30/96 Nov 6 1996 (1) Rig moved 100 %. Nov 7 1996 (2) Held safety meeting. Rigged up Drillfloor/Derrick. Rigged up Divertor. Held drill (Spill). Rigged UP Fluid system. Held safety meeting. Rigged up Handling equipment. Made up BHA no. 1 . Held safety meeting. R.I.H. to 106 ft. Drilled to 164 ft. Serviced Shaker discharge line. Circulated at 164 ft. Held drill (Fire). Drilled to 196 ft. Nov 8 1996 (3) Held safety meeting. Drilled to 468 ft. Held drill (Fire). Drilled to 528 ft. Flow check. Pulled out of hole to 0 ft. Downloaded MWD tool. Held safety meeting. R.I.H. to 528 ft. Drilled to 745 ft. Held drill (H2S). Drilled to 861 ft. Nov 9 1996 (4) Held safety meeting. Drilled to 1361 ft. Held drill (H2S). Drilled to 1424 ft. Held safety meeting. Drilled to 2020 ft. Held drill (Kick while drilling). Drilled to 2203 ft. Circulated at 2203 ft. Flow check. Pulled out of hole to 1000 ft. Nov 10 1996 (5) Held safety meeting. Flow check. Pulled out of hole to 0 ft. R.I.H. to 2204 ft. Logged hole with LWD: Directional (DIR) from 2172 ft to 2204 ft. Drilled to 3045 ft. Held safety meeting. Drilled to 3101 ft. Serviced Mud pumps. Drilled to 3539 ft. Nov 11 1996 (6) Held safety meeting. Drilled to 3815 ft. Circulated at 3815 ft. Flow check. Pulled out of hole to 3000 ft. Held drill (Kick while tripping). Pulled out of hole to 2150 ft. R.I.H. to 3815 ft. Circulated at 3815 ft. Flow check. Pulled out of hole to 200 ft. Downloaded MWD tool. Held safety meeting. Pulled BHA. Ran Casing to 460 ft (9.625 in OD). Held drill (Spill). Ran Casing to 3815 ft (9.625 in OD). Alaska 0il & Gas Cons. Commission ~,nch0rago Operations Summary for: 1, .~7 Nov 12 1996 (7) Held safety meeting. Rigged down Casing handling equipment. Ran Drillpipe in stands to 3724 ft. Circulated at 3724 ft. Mixed and pumped slurry - 753 bbl. Circulated at 3720 ft. Held safety meeting. Circulated at 3720 ft. Laid down 660 ft of Drillpipe. Circulated at 15 ft. Rigged down Divertor. Held drill (Fire). Rigged up BOP stack. Nov 13 1996 (8) Held safety meeting. Rigged up Well control. Tested All functions. Held safety meeting. Tested All functions. Made up BHA no. 4. R.I.H. to 3570 ft. Serviced Block line. R.I.H. to 3724 ft. Held drill (Spill). Tested Other sub-surface equipment - Via string. Nov 14 1996 (9) Held safety meeting. Circulated at 3700 ft. Tested Casing - Via string. Drilled cement to 3818 ft. Circulated at 3838 ft. Serviced Fluid system. Circulated at 3838 ft. Performed formation integrity test. Drilled to 4621 ft. Nov 15 1996 (10) Drilled to 5689 ft. Circulated at 5689 ft. Pulled out of hole to 3800 ft. Circulated at 5689 ft. Pulled out of hole to 907 ft. Pulled BHA. R.I.H. to 3800 ft. Nov 16 1996 (11) Held safety meeting. R.I.H. to 5630 ft. Reamed to 5689 ft. Drilled to 6412 ft. Circulated at 6412 ft. Pulled out of hole to 5644 ft. R.I.H. to 6412 ft. Drilled to 6931 ft. Nov 17 1996 (12) Drilled to 7019 ft. Circulated at 7019 ft. Pulled out of hole to 6347 ft. Drilled to 7657 ft. Circulated at 7657 ft. Pulled out of hole to 7019 ft. R.I.H. to 7657 ft. Drilled to 7660 ft. Nov 18 1996 (13) Drilled to 7689 ft. Circulated at 7689 ft. Pulled out of hole to 368 ft. Pulled BHA. Downloaded MWD tool. Made up BHA no. 6. Set tool face. R.I.H. to 6545 ft. Held safety meeting. R.I.H. to 7689 ft. Set tool face. Drilled to 8060 ft. Nov 19 1996 (14) Drilled to 8346 ft. Pulled out of hole to 7680 ft, R.I.H. to 8346 ft. Drilled to 8889 ft. Page 2 Operations Summary for: 1..7 Nov 20 1996 (15) Drilled to 8953 ft. Pulled out of hole to 8315 ft. R.I.H. to 8953 ft. Drilled to 9337 ft. Circulated at 9337 ft. Pulled out of hole to 2100 ft. Nov 21 1996 (16) Held safety meeting. Pulled out of hole to 166 ft. Pulled BHA. Rigged down sub- surface equipment - Formation logs. Ran Drillpipe in stands to 7800 ft. Rigged up sub-surface equipment- Subs. Ran electric logs. Ran electric logs. Rigged down sub-surface equipment- Subs. Pulled out of hole to 92 ft. Rigged down sub- surface equipment - Formation logs. Retrieved Wear bushing. Tested BOP stack. Nov 22 1996 (17) Tested Kelly. Installed Wear bushing. Held safety meeting. Made up BHA no. 7. R.I.H. to 8740 ft. Reamed to 8838 ft. Circulated at 8838 ft. Reamed to 9106 ft. Pulled out of hole to 8583 ft. R.I.H. to 9106 ft. Washed to 9337 ft. Circulated at 9337 ft. Pulled out of hole to 8600 ft. R.I.H. to 9337 ft. Circulated at 9337 ft. Pulled out of hole to 1500 ft. Nov 23 1996 (18) Held safety meeting. Pulled out of hole to 0 ft. Rigged up sub-surface equipment - Formation logs. Ran Drillpipe in stands to 3800 ft. Serviced Block line. Ran Drillpipe in stands to 8800 ft. Rigged up sub-surface equipment - Subs. Ran electric logs. Rigged down sub-surface equipment - Subs. Held safety meeting. Laid down 8559 ft of Drillpipe. Rigged down sub- surface equipment - Formation logs. Ran HWDP in stands to 4540 ft. Laid down 540 ft of HWDP. Retrieved Wear bushing. Nov 24 1996 (19) Held safety meeting. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 5625 ft (7 in OD). Held safety meeting. Ran Casing to 9327 ft (7 in OD). Installed Casing hanger. Circulated at 9327 ft. Pumped spacers - volume 68 bbl. Mixed and pumped slurry- 65.7 bbl. Displaced slurry- 360 bbl. Rigged down Casing handling equipment. Installed Casing hanger %s seal assembly running tool. Serviced Kelly. Nov 25 1996 (20) Serviced Kelly. Installed Wear bushing. Held safety meeting. Made up BHA no. 8. Singled in drill pipe to 4275 ft. Serviced Drillstring handling equipment. Singled in drill pipe to 6835 ft. Held safety meeting. Singled in drill pipe to 8100 ft. Tested Kelly. Singled in drill pipe to 9242 ft. Tested Casing - Via string. Tested M.W.D. tool- Via string. Drilled cement to 9337 ft. Circulated at 9337 ft. Page Operations Summary for: 1. Nov 26 1996 (21) Circulated at 9337 ft. Drilled to 9865 ft. Serviced Kelly. Drilled to 10025 ft. Pulled out of hole to 9270 ft. R.I.H. to 10025 ft. Drilled to 10230 ft. Nov 27 1996 (22) Drilled to 10440 ft. Circulated at 10440 ft. Pulled out of hole to 9243 ft. Logged hole with LWD: Formation evaluation (FE) from 9327 ft to 10440 ft. Circulated at 10440 ft. Pulled out of hole to 9240 ft. Circulated at 9240 ft. Pulled out of hole to 186 ft. Pulled BHA. Rigged up Casing handling equipment. Ran Casing to 1250 ft (4.5 in OD). Nov 28 1996 (23) Held safety meeting. Ran Drillpipe in stands to 10440 ft. Circulated at 10440 ft. Tested Other sub-surface equipment - Via annulus. Circulated at 10440 ft, Held safety meeting. Circulated at 10440 ft. Circulated at 10350 ft. Laid down 9190 ft of Drillpipe. Laid down 1300 ft of Tubing. Nov 29 1996 (24) Held safety meeting. Rigged up Completion string handling equipment. Ran Tubing to 3150 ft (4.5 in OD). Held drill (Spill). Ran Tubing to 6000 ft (4.5 in OD). Held safety meeting. Ran Tubing to 8665 ft (4.5 in OD). Tested Dual control line. Circulated at 8665 ft. Conducted slickline operations on Slickline equipment- Retrival run. Nov 30 1996 (25) Held safety meeting. Conducted slickline operations on Slickline equipment - Setting run. Set packer at 8608 ft with 4000 psi. Rigged down BOP stack. Held safety meeting. Rigged up Surface tree. Rigged up Lubricator. Rigged up Sub sea tools. Rigged up Fluid system. Rig moved 0 %. Page 4 SP5 ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -53.50 146.00 146.00 92.50 240.00 240.00 186.50 329.00 329.00 275.50 418.00 418.00 364.50 509.00 509.00 455.50 599.00 599.00 545.50 689.00 689.00 635.50 781.00 781.00 727.50 838.00 838.00 784.50 932.00 931.99 878.49 1026.00 1025.99 972.49 1120.00 1119.98 1066.48 1214.00 1213.97 1160.47 1309.00 1308.96 1255.46 1403.00 1402.95 1349.45 1495.00 1494.95 1441.45 1589.00 1588.94 1535.44 1683.00 1682.94 1629.44 1777.00 1776.94 1723.44 1870.00 1869.93 1816.43 1902.00 1901.93 1848.43 1932.00 1931.92 1878.42 1964.00 1963.91 1910.41 1995.00 1994.87 1941.37 2025.00 2024.82 1971.32 2056.00 2055.73 2002.23 2088.00 2087.61 2034.11 2119.00 2118.48 2064.98 2146.00 2145.35 2091.85 2245.00 2243.86 2190.36 2339.00 2337.35 2283.85 2433.00 2430.81 2377.31 2527.00 2524.25 2470.75 2620.00 2616.71 2563.21 f SUN DRILLING SERVICES ~' q~ ' I~ W - PAGE ANCHORAGE ALASKA ~.O~C~--~~ DATE OF SURVEY: 112696 MWD SURVEY JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 FT. OPERATOR: ARCO ALASKA INC COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 0 0 N .00 E .00 .00N .00E .00 0 12 N 81.05 W .14 .04N .26W -.18 0 10 N 66.76 E .39 .12N .31W -.17 0 15 N 45.91 E .13 .32N .04W .16 0 2 N 40.78 E .25 .48N .13E .39 0 20 S 59.64 E .37 .37N .38E .52 0 6 S 69.83 E .26 .20N .69E .67 0 11 N 14.63 E .25 .32N .81E .84 0 7 N 73.62 E .18 .49N .94E 1.05 0 12 S 56.70 E .28 .45N 1.08E 1.14 0 11 N 86.40 E .14 .37N 1.38E 1.32 0 33 N 60.58 E .41 .60N 1.93E 1.90 0 58 N 41.44 E .53 1.42N 2.86E 3.13 1 4 N 16.62 E .48 2.87N 3.64E 4.64 0 35 N 20.76 E .52 4.19N 4.07E 5.78 0 28 S 67.08 W 1.04 4.49N 3.89E 5.82 0 36 S 65.63 W .14 4.15N 3.10E 4.99 0 36 S 65.53 W .02 3.74N 2.20E 4.02 0 29 S 66.17 W .13 3.37N 1.38E 3.14 0 27 S 46.22 W .18 2.94N .74E 2.38 0 33 S 38.83 W .13 2.33N .18E 1.56 0 49 S 55.53 W 1.05 2.08N .llW 1.18 1 26 S 71.54 W 2.27 1.83N .64W .61 2 17 S 67.73 W 2.71 1.46N 1.62W -.39 3 5 S 68.05 W 2.55 .92N 2.97W -1.80 3 50 S 71.75 W 2.61 .30N 4.67W -3.53 4 37 S 73.68 W 2.59 .385 6.86W -5.67 5 9 S 77.75 W 1.95 1.045 9.50W -8.17 5 33 S 76.85 W 1.32 1.685 12.32W -10.80 5 36 S 79.07 W .83 2.235 14.89W -13.17 5 48 S 80.62 W .25 3.965 24.58W -21.91 6 4 S 81.10 W .30 5.515 34.18W -30.46 6 15 S 80.97 W .19 7.085 44.16W -39.34 6 13 S 81.29 W .06 8.665 54.26W -48.30 6 11 S 82.96 W .20 10.035 64.21W -57.04 _Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 112696 MWD SURVEY JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2712.00 2708.19 2654.69 2805.00 2800.72 2747.22 2899.00 2894.29 2840.79 2991.00 2985.91 2932.41 3085.00 3079.55 3026.05 5 56 S 84.61 W .33 11.09S 73.87W 5 39 S 85.21 W .31 11.92S 83.24W 5 11 S 83.39 W .53 12.80S 92.08W 5 13 S 83.61 W .05 13.75S 100.38W 4 47 S 81.79 W .50 14.78S 108.52W -65.35 -73.28 -80.83 -87.99 -95.07 3116.00 3110.46 3056.96 3148.00 3142.38 3088.88 3177.00 3171.33 3117.83 3206.00 3200.30 3146.80 3240.00 3234.29 3180.79 4 13 S 87.14 W 2.26 15.02S 110.94W 3 36 N 86.82 W 2.32 15.03S 113.13W 3 5 N 82.62 W 1.98 14.88S 114.81W 2 9 N 75.00 W 3.42 14.63S 116.12W 1 13 N 57.22 W 3.13 14.27S 117.04W -97.14 -98.88 -100.12 -101.01 -101.52 3271.00 3265.28 3211.78 3300.00 3294.28 3240.78 3331.00 3325.28 3271.78 3424.00 3418.27 3364.77 3518.00 3512.26 3458.76 0 41 N 32.98 W 2.11 13.94S 117.42W 0 36 N 5.16 W 1.11 13.64S 117.53W 0 48 N 6.16 W .64 13.26S 117.57W 0 41 S 23.17 W 1.55 13.13S 117.86W 1 1 S 17.24 W .36 14.45S 118.33W -101.62 -101.52 -101.32 -101.47 -102.65 3612.00 3606.24 3552.74 3705.00 3699.23 3645.73 3765.00 3759.22 3705.72 3858.73 3852.94 3799.44 3951.07 3945.27 3891.77 0 56 S 24.98 W .16 15.95S 118.90W 0 56 S 29.71 W .09 17.30S 119.60W 0 55 S 17.59 W .33 18.20S 119.99W 0 56 S 22.91 W .09 19.63S 120.52W 0 49 S 24.28 W .13 20.93S 121.09W -104.02 -105.40 -106.25 -107.54 -108.79 4045.98 4040.17 3986.67 4140.25 4134.43 4080.93 4234.50 4228.67 4175.17 4326.53 4320.69 4267.19 4418.88 4413.03 4359.53 0 42 S 23.11 W .12 22.09S 121.60W 0 49 N 28.10 W 1.47 22.02S 122.15W 0 50 N 33.74 W .09 20.85S 122.85W 0 52 N 30.79 W .06 19.69S 123.59W 0 42 N 21.76 W .22 18.55S 124.16W -109.90 -110.29 -110.14 -110.01 -109.77 4511.16 4505.31 4451.81 4601.96 4596.10 4542.60 4692.72 4686.85 4633.35 4786.64 4780.77 4727.27 4879.96 4874.08 4820.58 0 41 N 29.27 W .10 17.54S 124.64W 0 45 N 21.80 W .13 16.50S 125.13W 0 38 N 21.30 W .13 15.47S 125.54W 0 29 N 36.92 W .23 14.66S 125.97W 0 33 N 33.64 W .08 13.96S 126.46W -109.54 -109.30 -108.99 -108.84 -108.81 4971.48 4965.60 4912.10 5063.09 5057.20 5003.70 5153.37 5147.48 5093.98 5246.91 5241.02 5187.52 5341.82 5335.93 5282.43 0 43 N 26.04 W .20 13.07S 126.96W 0 30 N 44.61 W .31 12.26S 127.50W 0 18 N 30.64 W .26 11.77S 127.91W 0 20 N 37.22 W .06 11.34S 128.20W 0 27 N 34.50 W .12 10.81S 128.58W -108.66 -108.60 -108.62 -108.59 -108.57 SPI Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 112696 MWD SURVEY JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 5434.08 5428.18 5374.68 0 22 5528.44 5522.54 5469.04 0 19 5625.30 5619.40 5565.90 0 37 5721.79 5715.88 5662.38 0 30 5818.46 5812.55 5759.05 0 49 N 44.49 W .11 10.295 129.00W N 51.50 W .07 9.905 129.43W N 39.47 W .32 9.325 129.99W N 41.60 W .13 8.595 130.61W N 36.64 W .34 7.705 131.31W -108.58 -108.69 -108.77 -108.82 -108.84 5913.82 5907.90 5854.40 6010.56 6004.63 5951.13 6106.81 6100.87 6047.37 6202.11 6196.16 6142.66 6297.56 6291.59 6238.09 48 43 4O 6 7 N 78.56 E 1.45 7.025 131.06W N 61.46 E .25 6.595 129.86W N 48.38 E .17 5.935 128.91W N 75.38 E .63 5.325 127.60W N 72.44 E .06 4.815 125.81W -108.23 -107.01 -105.85 -104.45 -102.71 6393.36 6387.37 6333.87 0 6488.94 6482.94 6429.44 1 6521.18 6515.17 6461.67 1 6553.24 6547.22 6493.72 1 6585.66 6579.64 6526.14 1 58 13 15 10 6 N 56.79 E .34 4.075 124.22W S 65.30 E 1.14 4.055 122.61W S 60.70 E .32 4.375 121.98W S 60.75 E .22 4.705 121.39W S 53.67 E .50 5.055 120.85W -101.01 -99.71 -99.41 -99.14 -98.93 6617.79 6611.76 6558.26 0 41 6649.08 6643.05 6589.55 0 14 6681.42 6675.38 6621.88 1 29 6713.55 6707.49 6653.99 3 7 6744.76 6738.63 6685.13 4 6 S 55.49 E 1.28 5.345 120.44W S 20.60 E 1.64 5.515 120.26W S 77.13 W 4.76 5.675 120.65W S 86.21 W 5.18 5.825 121.93W N 85.85 W 3.55 5.795 123.89W -98.78 -98.74 -99.14 -100.25 -101.79 6776.99 6770.76 6717.26 5 9 6810.45 6804.04 6750.54 6 28 6841.16 6834.52 6781.02 7 26 6873.37 6866.44 6812.94 7 55 6904.51 6897.27 6843.77 8 22 N 86.97 W 3.27 5.635 126.49W N 89.98 W 4.05 5.555 129.88W S 89.16 W 3.14 5.585 133.60W S 86.25 W 1.92 5.765 137.90W S 85.86 W 1.49 6.065 142.31W -103.76 -106.40 -109.37 -112.88 -116.56 6936.70 6929.09 6875.59 6969.68 6961.60 6908.10 7000.82 6992.17 6938.67 7032.96 7023.56 6970.06 7065.11 7054.92 7001.42 9 10 11 13 12 4 8 4O 4 31 S 83.65 W 2.41 6.515 147.17W S 84.24 W 3.26 7.095 152.65W S 80.69 W 5.36 7.885 158.49W S 76.89 W 5.04 9.235 165.24W S 79.08 W 2.30 10.715 172.21W -120.69 -125.39 -130.50 -136.68 -143 . 11 7096.01 7084.94 7031.44 7127.49 7115.34 7061.84 7157.70 7144.40 7090.90 71S0.03 7175.35 7121.85 7222.24 7206.03 7152.53 14 15 16 17 18 40 29 15 13 19 S 74.76 W 7.69 12.385 179.27W S 74.22 W 2.64 14.575 187.16W S 73.35 W 2.67 16.885 195.09W S 71.11 W 3.60 19.725 203.96W S 70.90 W 3.39 22.925 213.26W -149.72 -157.32 -165.02 -173.78 -183.11 SPZ f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 112696 MWD SURVEY JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7254.35 7236.43 7182.93 19 8 7285.79 7266.12 7212.62 19 21 7318.20 7296.66 7243.16 19 45 7350.30 7326.86 7273.36 19 48 7382.10 7356.72 7303.22 20 30 S 70.44 W 2.63 26.34S 222.99W S 70.90 W .80 29.77S 232.77W S 74.85 W 4.26 32.96S 243.13W S 79.87 W 5.29 35.33S 253.72W S 82.65 W 3.71 36.99S 264.55W -192.90 -202.75 -212.91 -222.75 -232.35 7413.27 7385.90 7332.40 20 38 7445.60 7416.20 7362.70 20 10 7477.17 7445.78 7392.28 20 42 7509.39 7475.88 7422.38 21 3 7542.17 7506.50 7453.00 20 51 S 83.19 W .76 38.34S 275.42W S 84.45 W 1.99 39.56S 286.62W S 83.53 W 1.99 40.71S 297.58W S 86.22 W 3.17 41.74S 309.02W S 85.14 W 1.33 42.62S 320.71W -241.79 -251.42 -260.82 -270.52 -280.33 7574.13 7536.39 7482.89 20 31 7606.37 7566.54 7513.04 20 57 7638.55 7596.58 7543.08 21 3 7671.79 7627.61 7574.11 21 1 7705.50 7659.00 7605.50 21 40 S 85.22 W 1.07 43.57S 331.97W S 84.57 W 1.54 44.58S 343.34W S 86.10 W 1.73 45.52S 354.84W S 85.80 W .34 46.36S 366.74W S 84.84 W 2.22 47.37S 378.97W -289.83 -299.47 -309.16 -319.11 -329.43 7737.18 7688.27 7634.77 7768.30 7716.82 7663.32 7800.06 7745.97 7692.47 7894.02 7833.09 7779.59 7926.22 7863.30 7809.80 23 23 23 20 19 21 28 19 40 47 S 84.26 W 5.32 48.52S 391.05W S 85.32 W 1.42 49.64S 403.36W S 84.49 W 1.15 50.76S 415.92W S 86.50 W 2.93 53.56S 450.99W S 85.98 W 2.76 54.29S 462.11W -339.71 -350.16 -360.80 -390.32 -399.58 8021.69 7953.04 7899.54 20 6 8117.73 8042.88 7989.38 21 16 8214.45 8132.79 8079.29 22 0 8308.88 8220.91 8167.41 20 4 8340.23 8250.42 8196.92 19 25 S 82.92 W 1.14 57.45S 494.52W S 85.35 W 1.51 60.89S 528.26W S 87.52 W 1.12 63.10S 563.84W S 87.12 W 2.05 64.68S 597.69W S 87.41 W 2.10 65.18S 608.27W -427.21 -456.07 -485.63 -513.45 -522.15 8372.84 8281.32 8227.82 17 46 8404.77 8311.93 8258.43 15 26 8436.68 8342.79 8289.29 14 18 8468.88 8374.07 8320.57 13 11 8501.16 8405.44 8351.94 14 11 N 88.24 W 6.58 65.28S 618.66W N 74.04 W 14.62 63.96S 627.63W N 56.35 W 14.61 60.60S 635.00W N 44.08 W 9.67 55.76S 640.86W N 33.07 W 8.63 49.80S 645.59W -530.44 -536.75 -540.55 -542.26 -542.37 8533.36 8436.58 8383.08 15 21 8565.70 8467.72 8414.22 16 6 8597.44 8498.05 8444.55 18 17 8629.76 8528.50 8475.00 20 56 8661.96 8558.48 8504.98 21 53 N 21.38 W 9.93 42.52S 649.30W N 6.74 W 12.46 34.07S 651.38W N 4.46 E 12.46 24.73S 651.51W N 13.71 E 12.61 14.06S 649.75W N 23.23 E 11.18 2.95S 646.02W -540.88 -537.39 -531.80 -523.90 -514.18 SP[ f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 112696 MWD SURVEY JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8693.24 8587.27 8533.77 8725.43 8616.25 8562.75 8756.15 8643.03 8589.53 8788.44 8669.95 8616.45 8820.59 8695.26 8641.76 24 10 27 23 31 14 35 46 40 19 N 28.31 E 9.69 8.05N 640.68W -503.24 N 30.86 E 10.55 20.22N 633.75W -490.34 N 30.73 E 12.53 33.14N 626.05W -476.37 N 30.28 E 14.08 48.49N 617.01W -459.84 N 29.86 E 14.18 65.64N 607.09W -441.53 8853.04 8719.32 8665.82 8885.41 8741.82 8688.32 8917.50 8762.52 8709.02 8948.52 8781.08 8727.58 8980.87 8798.74 8745.24 43 57 47 56 51 42 54 50 58 58 N 33.32 E 13.28 84.17N 595.67W -421.19 N 35.65 E 13.34 103.33N 582.48W -399.06 N 38.19 E 13.18 122.92N 567.75W -375.45 N 41.50 E 13.25 141.99N 551.82W -351.19 N 43.08 E 13.41 162.02N 533.58W -324.52 9011.34 8813.53 8760.03 9043.54 8827.34 8773.84 9075.11 8839.20 8785.70 9107.64 8849.79 8796.29 9139.89 8859.40 8805.90 62 55 66 15 69 38 72 21 72 56 N 44.92 E 14.03 181.17N 515.07W N 48.27 E 13.97 201.15N 493.94W N 51.45 E 14.20 220.00N 471.57W N 52.69 E 9.11 238.90N 447.31W N 53.19 E 2.33 257.45N 422.75W -298.18 -269.26 -240.04 -209.28 -178.50 9172.11 8868.37 8814.87 9204.37 8875.79 8822.29 9236.74 8881.60 8828.10 9267.84 8886.18 8832.68 9300.07 8889.37 8835.87 74 43 78 41 80 37 82 25 86 12 N 55.09 E 7.93 275.57N 397.67W N 55.47 E 12.33 293.45N 371.87W N 54.67 E 6.47 311.68N 345.77W N 54.90 E 5.83 329.41N 320.64W N 54.91 E 11.73 347.85N 294.40W -147.58 -116.23 -84.42 -53.69 -21.65 9323.92 8890.55 8837.05 9356.17 8890.45 8836.95 9388.58 8888.85 8835.35 9418.79 8887.11 8833.61 9450.93 8885.13 8831.63 88 4 92 16 93 23 93 12 93 51 N 53.55 E 9.69 361.77N 275.08W N 52.21 E 13.67 381.23N 249.37W N 52.95 E 4.12 400.90N 223.67W N 53.89 E 3.16 418.87N 199.45W N 53.27 E 2.79 437.92N 173.64W 2.15 34.40 66.76 96.92 128.99 9482.88 8882.81 8829.31 9515.38 8880.49 8826.99 9547.88 8878.49 8824.99 9579.27 8877.03 8823.53 9611.72 8876.28 8822.78 94 28 93 43 93 19 91 58 90 40 N 54.15 E 3.35 456.78N 147.95W N 52.96 E 4.30 476.03N 121.88W N 52.78 E 1.35 495.61N 96.01W N 52.33 E 4.56 514.67N 71.12W N 52.75 E 4.18 534.40N 45.37W 160.85 193.26 225.69 257.05 289.49 9643.92 8875.69 8822.19 9676.19 8874.72 8821.22 9708.69 8873.55 8820.05 9740.36 8872.68 8819.18 9958.43 8867.39 8813.89 91 26 91 58 92 9 90 59 91 47 N 52.64 E 2.42 553.92N 19.76W N 52.77 E 1.69 573.46N 5.90E N 53.03 E .97 593.05N 31.80E N 52.34 E 4.29 612.24N 56.98E N 50.38 E .97 748.35N 227.23E 321.68 353.93 386.41 418.07 635.99 SP5 .f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 112696 MWD SURVEY JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9995.46 8866.18 8812.68 91 56 N 52.75 E 6.41 771.35N 256.21E 10027.78 8865.16 8811.66 91 40 N 53.32 E 1.95 790.77N 282.02E 10060.04 8864.39 8810.89 91 4 N 53.45 E 1.87 810.01N 307.91E 10092.09 8863.83 8810.33 90 55 N 52.32 E 3.56 829.34N 333.46E 10125.11 8863.36 8809.86 90 40 N 49.31 E 9.15 850.20N 359.05E 672.99 705.29 737.54 769.58 802.58 10157.40 8862.88 8809.38 91 1 N 51.63 E 7.26 870.75N 383.95E 10189.32 8862.40 8808.90 90 42 N 52.17 E 1.95 890.44N 409.06E 10221.25 8861.60 8808.10 92 9 N 51.94 E 4.60 910.07N 434.23E 10253.19 8860.48 8806.98 91 51 N 52.13 E 1.11 929.70N 459.40E 10273.64 8859.82 8806.32 91 51 N 51.96 E .83 942.27N 475.51E 834.84 866.76 898.67 930.59 951.03 10316.64 8858.47 8804.97 91 43 N 51.83 E .44 968.80N 509.33E 10378.70 8857.64 8804.14 89 49 N 51.47 E 3.12 1007.29N 557.99E 10440.00 8857.83 8804.33 89 49 N 51.47 E .00 1045.48N 605.95E 994.01 1056.05 1117.34 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1208.39 FEET AT NORTH 30 DEG. 5 MIN. EAST AT MD = 10440 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 52.48 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 10,440.00' MD SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 112696 JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -53.50 .00 N .00 E 1000.00 999.99 946.49 .48 N 1.72 E 2000.00 1999.86 1946.36 .82 N 3.22 W 3000.00 2994.88 2941.38 13.84 S 101.19 W 4000.00 3994.20 3940.70 21.56 S 121.37 W .00 .01 .01 .14 .13 5.12 4.99 5.80 .68 5000.00 4994.12 4940.62 12.75 S 127.12 W 6000.00 5994.07 5940.57 6.65 S 129.98 W 7000.00 6991.37 6937.87 7.85 S 158.32 W 8000.00 7932.67 7879.17 56.53 S 487.12 W 9000.00 8808.24 8754.74 174.03 N 522.11 W 5.88 .08 5.93 .05 8.63 2.70 67.33 58.70 191.76 124.43 10000.00 8866.03 8812.53 774.09 N 259.82 E 10440.00 8857.83 8804.33 1045.48 N 605.95 E 1133.97 942.21 1582.17 448.19 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP5 PAGE 8 f-SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 112696 JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -53.50 53.50 53.50 .00 153.50 153.50 100.00 253.50 253.50 200.00 353.50 353.50 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .05 N .29 W .00 .00 .14 N .27 W .00 .00 .39 N .04 E .00 .00 453.50 453.50 400.00 553.50 553.50 500.00 653.50 653.50 600.00 753.50 753.50 700.00 853.51 853.50 800.00 .50 N .14 E .00 .00 .24 N .59 E .00 .00 .21 N .78 E .00 .00 .48 N .89 E .00 .00 .42 N 1.13 E .01 .00 953.51 953.50 900.00 1053.51 1053.50 1000.00 1153.52 1153.50 1100.00 1253.54 1253.50 1200.00 1353.55 1353.50 1300.00 .37 N 1.46 .73 N 2.16 .85 N 3.24 .59 N 3.86 .58 N 4.20 E .01 .00 E .01 .00 E .02 .01 E .04 .02 E .05 .01 1453.55 1453.50 1400.00 1553.55 1553.50 1500.00 1653.56 1653.50 1600.00 1753.56 1753.50 1700.00 1853.57 1853.50 1800.00 4.32 N 3.49 E .05 .00 3.89 N 2.54 E .05 .01 3.47 N 1.61 E .06 .01 3.07 N .87 E .06 .00 2.46 N .28 E .07 .00 1953.59 1953.50 1900.00 2053.76 2053.50 2000.00 2154.19 2153.50 2100.00 2254.69 2253.50 2200.00 2355.24 2353.50 2300.00 1.60 N 1.27 .33 S 6.69 2.38 S 15.68 4.12 S 25.54 5.77 S 35.88 W .09 .02 W .26 .18 W .69 .43 W 1.19 .50 W 1.74 .55 2455.83 2453.50 2400.00 2556.42 2553.50 2500.00 2657.01 2653.50 2600.00 2757.55 2753.50 2700.00 2858.04 2853.50 2800.00 7.47 S 46.62 9.14 S 57.41 10.52 S 68.17 11.53 S 78.56 12.38 S 88.39 W 2.33 .59 W 2.92 .59 W 3.51 .59 W 4.05 .54 W 4.54 .48 2958.45 2953.50 2900.00 3058.85 3053.50 3000.00 3159.14 3153.50 3100.00 3259.22 3253.50 3200.00 3359.23 3353.50 3300.00 13.42 S 97.43 14.47 S 106.36 14.99 S 113.83 14.06 S 117.34 12.87 S 117.61 W 4.95 .41 W 5.35 .40 W 5.64 .29 W 5.72 .08 W 5.73 .01 SPE SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 112696 JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3459.23 3453.50 3400.00 3559.25 3553.50 3500.00 3659.26 3653.50 3600.00 3759.27 3753.50 3700.00 3859.29 3853.50 3800.00 13.52 S 118.02 15.15 S 118.54 16.65 S 119.23 18.11 S 119.96 19.64 S 120.52 W 5.73 .01 W 5.75 .01 W 5.76 .01 W 5.77 .01 W 5.79 .01 3959.30 3953.50 3900.00 4059.31 4053.50 4000.00 4159.32 4153.50 4100.00 4259.33 4253.50 4200.00 4359.34 4353.50 4300.00 21.04 S 121.14 22.24 S 121.66 21.78 S 122.28 20.54 S 123.06 19.26 S 123.84 W 5.80 .01 W 5.81 .01 W 5.82 .01 W 5.83 .01 W 5.84 .01 4459.35 4453.50 4400.00 4559.36 4553.50 4500.00 4659.37 4653.50 4600.00 4759.37 4753.50 4700.00 4859.38 4853.50 4800.00 18.09 S 124.34 17.02 S 124.92 15.82 S 125.40 14.85 S 125.83 14.13 S 126.35 W 5.85 .01 W 5.86 .01 W 5.87 .01 W 5.87 .01 W 5.88 .00 4959.38 4953.50 4900.00 5059.39 5053.50 5000.00 5159.39 5153.50 5100.00 5259.39 5253.50 5200.00 5359.39 5353.50 5300.00 13.21 S 126.90 12.29 S 127.48 11.75 S 127.92 11.28 S 128.24 10.70 S 128.66 W W W W W 5.88 .00 5.89 .01 5.89 .00 5.89 .00 5.89 .00 5459.40 5453.50 5400.00 5559.40 5553.50 5500.00 5659.40 5653.50 5600.00 5759.41 5753.50 5700.00 5859.42 5853.50 5800.00 10.17 S 129.12 9.79 S 129.57 9.03 S 130.23 8.34 S 130.83 7.23 S 131.67 W 5.90 .00 W 5.90 .00 W 5.90 .00 W 5.91 .01 W 5.92 .01 5959.43 5953.50 5900.00 6059.44 6053.50 6000.00 6159.44 6153.50 6100.00 6259.46 6253.50 6200.00 6359.48 6353.50 6300.00 6.89 S 130.43 6.29 S 129.32 5.53 S 128.39 5.03 S 126.52 4.39 S 124.71 W 5.93 .01 W 5.94 .01 W 5.94 .01 W 5.96 .02 W 5.98 .02 6459.50 6453.50 6400.00 6559.52 6553.50 6500.00 6659.53 6653.50 6600.00 6759.67 6753.50 6700.00 6860.30 6853.50 6800.00 3.79 S 123.18 4.77 S 121.28 5.55 S 120.25 5.72 S 124.96 5.64 S 136.11 W 6 . 00 . 02 W 6.02 .02 W 6.03 .01 W 6.17 .14 W 6.80 .64 SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 10 ARCO ALASKA, INC. PRUDHOE BAY/ DS 11-37 500292271600 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/11/97 DATE OF SURVEY: 112696 JOB NUMBER: AK-MM-60165 KELLY BUSHING ELEV. = 53.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6961.45 6953.50 6900.00 6.95 S 151.21 W 7.95 1.15 7063.66 7053.50 7000.00 10.65 S 171.90 W 10.16 2.21 7167.19 7153.50 7100.00 17.67 S 197.67 W 13.69 3.53 7272.42 7253.50 7200.00 28.32 S 228.60 W 18.92 5.23 7378.67 7353.50 7300.00 36.83 S 263.36 W 25.17 6.25 7485.43 7453.50 7400.00 41.01 S 300.50 W 31.93 6.76 7592.41 7553.50 7500.00 44.13 S 338.39 W 38.91 6.99 7699.58 7653.50 7600.00 47.17 S 376.79 W 46.08 7.16 7808.24 7753.50 7700.00 51.06 S 419.11 W 54.74 8.66 7915.79 7853.50 7800.00 54.05 S 458.55 W 62.29 7.55 8022.18 7953.50 7900.00 57.47 S 494.68 W 68.68 6.39 8129.12 8053.50 8000.00 61.23 S 532.37 W 75.62 6.94 8236.79 8153.50 8100.00 63.46 S 572.20 W 83.29 7.67 8343.49 8253.50 8200.00 65.22 S 609.34 W 89.99 6.70 8447.72 8353.50 8300.00 59.00 S 637.11 W 94.22 4.22 8550.92 8453.50 8400.00 38.00 S 650.59 W 97.42 3.21 8656.60 8553.50 8500.00 4.79 S 646.72 W 103.10 5.68 8768.59 8653.50 8600.00 38.91 N 622.64 W 115.09 11.99 8903.27 8753.50 8700.00 114.19 N 574.45 W 149.77 34.69 9119.89 8853.50 8800.00 245.98 N 438.03 W 266.39 116.62 9140.00 8859.44 8805.94 257.51 N 422.66 W 280.56 14.17 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS D Fi I I_1-- I I~1 CS S~:I~UI r' ~ S February 11, 1997 AOGCC Lori Taylor 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 11-37 Dear Ms. Taylor, The distributed MWD surveys for this well had an error. The final TD was incorrect. Please destroy the previous data delivered and replace it with this corrected information. Enclosed are two hard copies of the above mentioned file(s). Well 11-37 MWD survey, tie-in point at surface 0.00', interpolated depth 10,440.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 6, 1996 Blair Wondzell, ~ P. ,. Superv~r_~("~ FROM: Bobby Foster,"//~ ~) SUBJECT: Petroleum lnspbctor FILE NO: EFGIKFDD.doc Diverter Test PBU - DS11-37 PTD # 96-0174 Doyon Rig 16 Wednesday1 November 6, 1996: I traveled this date to ARCO's PBU DS 11-37 well and inspected and function tested the diverter. As the attached AOGCC Diverter Inspection Report shows~ the system is installed correctely and all systems functioned properly. I requested that another 40' of dirverter line be added and this was done and the line was tied down. The location was clean and all components on the rig seemed to be working properly. Summary: I witnessed the function test and inspected the instalation of the diverter system on Doyon 16 drilling ARCO's PBU well DS 11-37. Attachment: EFGIKFDD.XLS X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA .... ALASKA ,..,. AND GAS CONSERVATION CO,...~flSSlON Diverter Systems Inspection Report Operation: Drlg Contractor: DOYON DRILLING Rig No. Operator: ARCO Oper. Rep.: Well Name: DS 11-37 Rig Rep.: Location: Sec. 14 T. 12 N. R. 14 E. Development 16 PTD # Date: 11/6/96 X Exploratory: 96-0174 Rig Ph. # 659-4610 DINK HELMS SNAKE WILLINGHAM Merdian UMIAT MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: OK Systems Pressure: 3,000 psig Housekeeping: OK (Gen.) Ddg. Rig: OK Pressure After Closure: 1,700 psig Reserve Pit: N/A Flare Pit: N/A 200 psi Attained After Closure: 0 min. 31 sec. Systems Pressure Attained: 2 min. 58 sec. Nitrogen Bottles: ~4). BOTTLES 2150 (AVE.) 31VERTER SYSTEM INSPECTION: )iverter Size: ~)ivert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Tums Targeted / Long Radius: 20 Yes , Yes 16~ in. 85~ ff. No Yes Yes N/A MUD SYSTEM INSPECTION: Light Alarm Trip Tank: OK OK Mud Pits: OK OK Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: OK OK P~g NORTH Prevailing Wind Direction Northeast to Southwest 16" Hydraulically Operated Full Opening Knife VaNe 20" Annular Preventer 16" Vent Line 85' ~--- Rig & Sub Base Non Compliance Items None Repair Items VV'~ir N/A Day (s) And contact the Inspector @ 659-3607 Remarks: Requested crew install 40 more feet of vent line. The line was installed and tied down as requested. Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c - lnsoector AOGCC REP.: EFGIKFDD.XLS TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 13, 1996 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279~1433 FAX: (907) 276-7542 Dan Stolz, Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Prudhoe Bay Unit 11-37 ARCO Alaska, Inc. Permit No. 96-174 Surf Loc 4628~NSL, 4639'WEL, Sec 34, T11N, R15E, UM Btmhole Loc 332%1SL, 4087'WEL, Sec 27, T1 IN, R15E, UM Dear Mr Stoltz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling belo~v the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope David . Johnston , ~- ~ Chairm~n ~ BY ORDER OF TI't-E-~OMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - ~v/o encl Dept of Environmental Conservation - w/o encl , '--' STATE OF ALASKA ALASKA ~J~L AND GAS CONSERVATION COrv~MISSION PERMIT TO DRILL 20 AAC 25.005 ila. Type of work [] Drill [] Redrill I lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator :5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 53.4' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028325 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025i" 4628' NSL, 4639' WEL, SEC. 34, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 5003' NSL, 4881' WEL, SEC. 34, T11 N, R15E 11-37 Attotal depth 9. Approximate spud date Amount $200,000.00 332' NSL, 4087' WEL, SEC. 27, T11 N, R15E 11/05/96 12. Distance to nearest property line113. Distance to nearest well i14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028324, 4082'I No Close Approach 2560 10177' MD / 8858' TVD 16. To be completed for deviated wells 117. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 2000' Maximum Hole Angle 92° Maximum surface 3300 psig, Attotal depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 31' 31' 111' 111' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 47# L-80 BTC-Mod 3769' 30' 30' 3799' 3792' 1227 sx CS, 335 sx Class 'G' 8-1/2" 7" 29# L-80 BTC-Mod 8571' 29' 29' 8600' 8566' (See Below) 8-1/2" 7" 29# 13Cr NSCC 577' 8600' 8566' 9177' 8892' 288 sx Class 'G' 6" 4-1/2" 12.6# 13Cr NSCT 1150' 9027' 8875' 10177' 8858' 164 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production R ~ C ~ IV F D Liner ' OCT ~ 4. Perforation depth: measured Alaska 0il & G~s r;or~s. true vertical Anchorage, 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Tim Burns, 564-4315 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that ~kf~ ~'~)rego~ ~and correct to the best of my knowledge Signed Dan Stoltz /t~,,/~/Cf~~ . Title Senior Drilling Engineer Date Commission Use Only Permit Number APl Number Approval Date I See cover letter /~/'=-.//,,~.y 50- CD.2_¢ - ~-. Z ~,/~ / a '%=~-- ~'~tI for other requirements Conditions of Approval: Samples Required [] Yes ,~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures /l:~Yes [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2M; []3M; [] 5M; [] 10M; [] 15M Other: by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IDS 11-37 Type of Well (producer or injector): Surface Location: Pilot Hole Bottom Hole Location: Start of Horizontal Location: I New Well Summary IProducer I 4,628' FSL 4,639' FEL Sec 34 T11N R15E Not applicable Sadlerochit Zone 1 Lateral 5,003' FSL 4,881' FEL Sec 34 T11N R15E End of Horizontal Location: I AFL Number: I 4J0340 I 332' FSL 4,087' FEL Sec 27 T11N R15E Rig: I Doyon 16 Earliest Anticipated Spud: I Nov. 5, 1996 I I Operating days to complete: MD.. I ~0,177' II TVD= I 8,~5~' I I ET-GL I KBE: Well Design (conventional, slimhole, etc.) Formation Markers: 125 +_25.5' +53.4' Ultra Slimhole Horizontal Formation Tops MD TVD (SS) Base Permafrost 1873' 1820' T5 3789' 3730' Surface Casing Point 3799' 3740' 9-5/8", 47#, BTC-Mod K15 4905' 4840' Ugnu 5814' 5745' West Sak 6582' 6510' K10 7296' 7220' K5 7873' 7795' LCU 8450' 8370' Shublik 8450' 8370' Sadlerochit (Z4) 8476' 8395' Z3 8605' 8519' Z2C 8667' 8576' CGOC 8672' 8580' Zl B 8919' 8770' Int. Casing Point 9177' 8840' 7", 29#, L-80 x 13 Cr liner (+92°) TD of Well 10177' 8805' 4-1/2", 12.6#, 13 Cr slotted liner (_+92°) Casing/Tubing Program: Csg/ Top Btm Hole Size Tbg O.D. Wt/Ft Grade Conn Length MD/TVD MD/I'VD 30" 20" 91.5# H-40 Weld 80' 31 '/31' 111 '/111' 12-1/4" 9-5/8" 47# L-80 BTC-Mod 3769' 30'/30' 3799'/3792' 8-1/2" 7" 29# L-80 BTC-MOD 8571' 29'/29' 8600'/8566' 7" 29# 13 Cr NSCC 577' 8600'/8566' 9177'/8892' Production Liner (slotted) 6" I 4-1/2" 12.6# 13 Cr NSCT 1150' 9027'/8875' 10177'/8858' Production Tubing I 4-1/2" 12.6# 13 Cr BTC-MOD 4872' 28'/28' 9000'/8860' Cementing Program: T Lead Cement Tail Cement Casin~/Liner Sx ! Wt ! Yield Sx / Wt / Yield Comments Cold Set Lead; Class G Tail; estimate 9~5/8" 1,227 / 12.2 / 1.92 335 / 15.8 / 1.15 200% excess (will use stab-in equipment and pump lead until returns to surface); Pump time = 4+ hrs; TOC = Surface Premium; Tail FW = 0; 50% excess; 7" N/A 288 / 15.8 / 1.15 Pump time = 4+ hrs; TOC = _+7,450' MD (_+1,000' above LCU) 4-1/2" N/A 164/15.7 / 1.17 Class G: 50% excess; TOC = _+200' above liner top Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Logging Program: I Lo~Is: 12-1/4" Hole 8-1/2" Hole 6" Hole Cased Hole: MWD Directional; MWD Directional / GR; Optional DPC logs; MWD Directional / GR; None planned. Mud Program: Surface Mud Properties: I 12-1/4" hole section: SPUD Density Marsh Yield 10 sec 10 min Fluid (PPG) Viscosity Point ~lel gel pH Loss Initial 8.5 _+ 300 40-60 25-45 50-80 9-10 15-20 Final 9.4-9.8 250-300 30-40 15-30 40-60 9-10 15-20 Hazards/Concerns Gravel beds, bridging, lost circulation. Frequent sweeps to aid hole cleaning. Intermediate Mud Properties: I 8-1/2" hole section: 6% KCL Biozan Density 10 sec 10 min Fluid (PPG) PV LSR YP ~lel ~lel pH Loss Initial 9.8-10.2 8-12 6-9 15-25 20-35 9.0-9.5 8-12 Final 9.8-10.2 8-12 6-12 15-25 20-35 9.0-9.5 <6 Hazards/Concerns Cretaceous overpressure expected from nearby injection; Utilize hi vis sweeps to assist hole cleaning; Baranex additions below K5 for enhanced borehole stability; Potential high torque could require lubricant use; Lost circulation, differential sticking due to higher MW; Production Mud Properties: I 6" hole section: BARADRILn (solids free) Density Yield Fluid (PPG) PV Point LSR YP LSRV pH Loss Initial 8.6-8.9 5-7 33-35 16-20 45,000+ 8.0-9.0 N/A Final 8.6-8.9 6-8 33-35 16-20 45,000+ 8.0-9.0 N/A Hazards/Concerns Lost Circulation, differential sticking due to overbalance in Sadlerochit; Perform report daily checks on KCI concentrations in Xanvis KCI system; High torque may be encountered and should be countered with lubricants. Directional: I KOP: I +_2,000' MD estimated (surface hole) Maximum Hole An~lle: +_92° Tangent Angle _+5°/with horizontal leg) Close Approach Well: None Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal: No annular injection permits will be submitted for the DS 11-37 well. DS 11-37 New Well (Ultra Slimhole) Operational Summary 1. MIRU. NU diverter and function test same. 2. Drill 12-1/4" hole to _+ 3,799' MD, (3,792' TVD, 10' into T5 or SV3). Run and cement 9-5/8", 47#, L-80 casing to surface. 3. Install blowout prevention equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer. Function test BOPE to 5,000 / 250 psi. 4. Test 9-5/8" casing to 3,500 psi for 30 minutes. A formation leak-off test will be performed 20' below the surface casing shoe. 5. Directionally drill 8-1/2" into the Sadlerochit (Zone 1) @ ___9,177' MD (8,893' TVD). 6. Run 7", 29#, L-80 x 13 Cr Iongstring and cement with Class G cement to ___1,000' above the LCU (prognosed at ___8,450' MD). Test casing to 3,500 psi for 30 minutes. 7. Drill a 6" hole in the Sadlerochit Zone 1 interval to 10,177' MD (8,858' TVD). Planned inclination is 92° along an azimuth of ___52.4°. POOH. Note: Inclination, azimuth and overall lateral length may be adjusted by the onsite geologist. Run 4-1/2", 12.6#, 13 Cr slotted liner from total depth to ___150' inside 7" casing. Displace the liner with filtered seawater. 9. RU and run 4-1/2", 13 Cr, production tubing to +_9,000' MD (end of tubing above 65° inclination). 10. Set two way check and test to 1,000 psi. 11. ND BOPE. NU tree and test to 5,000 psi. 12. Freeze protect well and release rig. . Drilling Hazards Pore pressure may be as high as 9.8 ppg EMW in the Cretaceous interval due to nearby injection. No potential hydrocarbon-bearing zones expected above the LCU/Shublik. Lost circulation is possible in the Cretaceous sands and again in the Sadlerochit. DS 11 is a known H2S pad. Appropriate H2S precautions are to be observed at all times while the drilling rig is on location. These precautions include, but are not limited to: · Proper training of all onsite personnel, unescorted visitors and temporary onsite personnel; · Monitors with both audible and visual alarms; · Access to 5-minute emergency escape air packs; · Personal H2S monitors; ~ ~ ~ ~IV E D · Working wind indicator; · Posted evacuation routes (minimum of two); · Muster points in designated safe areas; ? Z' 4 996 · Frequent H2S drills; .0ct-18-96 02:02P Anadrill DPC 907 344 2160 P.07 · DS] 1-37 (P5) I I VERTICAL SECTION VIEW ': ' i '- I I I TVOScale..i ~ inch--~000 feet I Dap Scale.: t inch = 1000 feet ,~_ .1 ........ -..1. I . ) '~sr~l'l~?~ .... [ Marker Identification MD BKB SECTN INCLN ' mA) KB - 0 0 0 0.00 -- -) D) g-5/B' CASING Pi 3800 3793 -J~3 5.37 I1 END CURVE 14/100 9177 B892 ' 37 92.01 m J) TA~ET (Bi)M~* 9177'8892 ' 37 92.01 ' ~'L) TD / TARGET (ESL)~ 10176 8857 1036 92.01 ~_ Z~L~ .... ,~_~ .,__._q~ ....... ._.,_, . ' I...~' ~' " '~ , ...... __ .... "}" ' -~[C[~V[~) ~To' ~ ;' .... ~. ., ............ 0 C-~ _2 ~ ~[~ _ ~- ~-: .......... - -- ~Jask~ 0~1~& B~s Ce~]s. Corem ssion :I~ a~::::::_ :::~: :~ ~ . , ~ r ...............! I / -z~o -~5oo -~ooo -~oo o 5oo ~ooo ~5oo ~ooo 25oo 3ooo 35oo 4ooo 45oo 5ooo Sec(~on Depan(une (~aUrill (c)96 1137~ 3.0~.07 !: 47 Pl Pi ' ,4nad~ ] ] Sch ] ~ber'ger' ".," BS_11'37 (P5) VERTIO,AL SECTION VlEN Sect ion at: 52.48 " I J-- ' "' ' "" TVD Scale.: .1 inch = 200 feet · ' .JDep Scale.: 't inch = 200 feet ) i, ....... J! ' .,.. " .. ',:, .........-~~ j~ .JOrawn'i"": 18 Oct 1996 ). ~ J , ,, t , i ............ Mar~er Identification MD BKB SECTN INCU · i ' i A) 6URVE t4/~O0 B403 8375 -422 5.3 i I [' ' i B) E~ CURVE 14/.t00 8599 85~ -388 23.9 ~ ) ', ..C)~R~ t4/~O0 8689 8648 -352 ~3.9 ) ~' ) . ' .... .' ' .... O) 7' CASING PT 9t77 8892 37 92.0 ~ ~ E) ~O CURVE l'4/tO0 9177 8892 37 92.0 : A-- ~ i ' 'F) T~CET (BSL)~**~* 9577 8892 37 92.0~ ) .,, ~, ,, 6) 4-~/~' LINER PT ~0576 8857 ~036 92.0 ................. J -'---~3~-a~ .,H) ~ / TARCET (ESL)~** $0~76 8857 J036 92.0 , . ' ...... ~D'/I~ ~ ', ~- .[ k '~ ,, , ...... .... ~... ......... ,. ~ 'I .. i ' ............... ''~'~:~" : "m . ' , . .... '-I--'-- ~ '"'""~' ~ ~ ' ' ~ ~ . . ~.., ~ _ , ,''. , I .. ~' ~ .. ~ ,. .... . : I : , -600 -500 -400 ' -300 -200 -$00 0 t00 200 300 400 500 600. 700 ann ann 4nnn Sect ~on Oepantune 0 O~ 0 II 0 , _j (~na~ri]] (c)96 3137P5 3.0b,07 1:47 PM P! · Oct' 18-96 02:03P Anadrill DPC 907 344 2160 P.09 i ii SHARED SERVICES Marker Identification MD N/S E/W I1 END C~VE 14/100 g177 376 N 242 W J) TARGET (BSL)*~ww~ g177 376 .N 242 W K) 4-1/2' LINER PT t0i76 985 N 550 E L) TD / TARGET ,(E~)~ 10~76 985 N 550 E DRILLING ! DS11-37 (P5) PLAN VIEW CLOSURE · DECLINATION · SCALE. · DRAWN· · 1128 feet at Azimuth 29.17 +28.538 (E) I inch -- 200 feet lB Oct 1996 · AnadrJY] Schlumberger (Pc 500 400 300 200 100 0 t00 200 300 400 500 600 700 <- WEST' EAST -> ~nadniil (c)% 1137P5 3.0b.07 I:47 ~ P) ~ · WELL PERMIT CHECKLIST COMPANY WELLNAME FIELD & POOL ~ c-/'~./,~c~ INIT CLASS ~'~,~,,~ / -- ~ ¢ GEOL AREA ADMINISTRATION ENGINEERING APPR~ ~ 'G~oLOGY .... 1. Permit fee attached ....................... IY 2. Lease number appropriate ................... tY 3. Unique well name and number ................. IY 4. Well located in a defined pool .................. 5. Well located proper distance from ddg unit boundary ..... tY 6. Well located proper distance from other wells ......... 7. Sufficient acreage available in driving unit. .......... 8. If deviated, is wellbore pL~t inctuded .............. ~.Y 9. Operator only affected party .................. ./Y 10. Operator has appropriate bond in force ............ I.Y 11. Permit can be issued without conservation order ...... 12. Permit can be issued without administrative approvaJ .... 13. Can permit be approved before 15-day wait. ........ Conductor string provided .................. ~,.~,~N 15. Surface ca~ng protects ali known USDWs ......... '"-L~ N 16. CMT vol adequate to circulate on conductor & surf csg . . .~[~ 17. CMT vol adequate to tie-in long s~ng to surf csg ....... 18. CMT will cover all known productive horizons ......... 19. Casing designs adequate for C, T, B & permaJrosL ..... .~. N 20. Adequate tankage or reserve pit. .............. ..~ N 21. Ifare-drill, hasal0-403forabndnmntbeenappmved...-~,N '~'-'~ 22. Adequate wellbore separation proposed ............ 23. If diverter required, is it adequate ................ 24. Drilling fluid program schematic & equip list adequate .... 25. BOPEs adequate ....................... 26. BOPE press rating adequate; test to ~ psig.( 27. Choke manifold complies w/APl RP-53 (May 84) ....... 28. Work will occur without operation shutdown .......... 29. Is presence of H2S gas probable ............... ( 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y/I~ 32. Seismic analysis of shallow gas zones ............ ./Y N 33. Seabed condition survey (if off-shore) .......... .~.. Y N 34. Con4;act name/phone for weekJ~ progress, repoT.. . . ~ . . Y N lexp~ora~ory on~yj PROGRAM: exp [] dev~ redrll [] serv [] wellborn seg r"l ann. disposal para req [] UNIT# / ///~'j~'c::~ ON/OFF SHORE ~___~x~ REMARKS GEOLOGY: ENGINEERI~NG: COM .~.~N: JDH~ JDN TAB Comments/Instructions: HOW~I/3- A.'~-OR~ my ~ 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. Sperry-bun Drilling Services · LIS Scan Utility Mon Mar 31 16:59:43 1997 Reel Header Service name ............. LISTPE Date ..................... 97/03/31 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Services Tape Header Service name ............. LISTPE Date ..................... 97/03/31 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK~MM-60165 B. ZIEMKE M. JACKSON DS 11-37 500292271600 ARCO ALASKA, INC. SPERRY-SUN 31-MAR-97 APR 0 2 1°"9 ? ~.a~-~a Oil &. Gas Cons. r : ..... DRILLING SERVICES MWD RUN 5 AK-MM-60165 B. ZIEMKE M. JACKSON MWD RUN 6 AK-MM-60165 B. ZIEMKE M. JACKSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 7 AK-MM-60165 A. PIEPER M. JACKSON MWD RUN 7 AK-MM-60165 A. PIEPER M. JACKSON 34 liN 15E 54.80 53.50 GROUND LEVEL: WELL CASING RE'CORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 27.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 105.0 12.250 9.625 3810.0 8.500 7.000 9328.0 6.000 10442.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD), UNLESS OTHERWISE NOTED. 2. WELL 11-37, IS REPRESENTED BY RUNS 1 THROUGH 8. 3. RUNS 1, 2, AND 3, ARE DIRECTIONAL ONLY, AND NO DATA IS PRESENTED. 4. RUNS 4, 5, AND 6, ARE DIRECTIONAL WITH GAMMA RAY (SGRC) . 5. RUN 7, IS DIRECTIONAL WITH GAMMA RAY(SGRC), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWP4). 6. ALL GAMMA RAY DATA GATHERED WITH DUAL GAMMA RAY / GIEGER-MUELLER TYPE DETECTORS, AND IS DENOTED DGR / SGRC. 7. A MEASURMENT AFTER DRILLING (MAD) PASS WAS PERFORMED FROM 9320' TO 10442' MD (8891' TO 8858' TVD), DURING A SHORT TRIP AFTER DRILLING RUN 7 TO TD. 8. WELL 11-37, IS DRILLED TO TD @ 10442' MD(8858' TVD). SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME (RESISTIVITY SENSOR) CURVES WITH "MAD" EXTENSION, DENOTE MEASUREMENT AFTER DRILLING DATA. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3780.0 10391.0 ROP v~15.0 10439.5 FET · 9198.0 10398.0 RPD 9198.0 10398.0 RPM 9198.0 10398.0 RPS 9198.0 10398.0 RPX 9198.0 10398.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 3780.0 7907.5 7916.0 7925.0 7938.5 7952.0 7966.0 7978.0 7983.0 7992.5 8000.0 8003.0 8005.5 8013.0 8036.5 8043.5 8052.5 8057.0 8077.0 8131.5 8136.0 8142.0 8143.5 8157.5 8170.5 8179.5 8184.0 8187.0 8191.5 8214.0 8218.5 8224.0 8230.0 8237.5 8241.0 8243.0 8246.0 8247.5 8261.5 8263.0 8270.0 8273.5 8280.0 8287.0 8291.5 8295.5 8300.0 8309.0 8312.0 8316.5 8320.0 8323.0 GR 3783.0 7910.5 7916.5 7926.0 7939.5 7949.5 7965.5 7978.0 7985.0 7993.0 8001.0 8003.5 8006.5 8014.0 8038.0 8045.0 8054.0 8058.5 8078.0 8133.0 8138.5 8144.0 8145.5 8159.5 8172.5 8181.5 8185.0 8189.0 8192.5 8216 5 8220 0 8226 0 8231 5 8239 5 8243 0 8245.5 8248.0 8249.0 8263.0 8264.5 8271.5 8274.5 8281.0 8289.0 8293.5 8297.5 8302.0 8311.5 8314.0 8317.5 8321.5 8323.5 EQUIVALENT UNSHIFTED DEPTH --' 8325.5 8331o. 0 8334.0 8336.5 8345.0 8347.5 8350.5 8361.0 8368.0 8375.0 8380.0 8383.0 8391.0 8401.0 8406.0 8409.0 8412.0 8424.0 8430.0 8441.0 8443.0 8447.5 8454.0 8461.5 8468.5 8478.0 8482.0 8486.0 8489.0 8493.0 8497.5 8500.5 8505.5 8509.5 8513.0 8521.5 8536.0 8538.0 8544.5 8547.0 8548.0 8565.0 8569.0 8584.0 8593.5 8597.5 8601.5 8613.5 8635.5 8639.0 8649.0 8660.0 8672.0 8680.5 8710.5 8715 5 8763 5 8809 5 8845 5 8847 5 8849 5 8859 5 8870 0 8873 5 _324.5 8331.0 8334.5 8336.5 8346.0 8347.5 8351.5 8364.0 8371.0 8377.5 8383.0 8386.5 8395.5 8403.5 8408.5 8412.5 8415.5 8426.0 8433.5 8443.0 8445.5 8450.5 8457.0 8463.5 8471.0 8481.5 8484.0 8488.0 8491.5 8494.5 8499.0 8502.5 8509.5 8512.5 8516.0 8524.5 8538.5 8539.5 8547.5 8548.5 8549.5 8566.0 8570.5 8586.0 8595.5 8599.5 8604.0 8617.0 8638.0 8642.0 8652.0 8663.0 8675.0 8683.0 8713.5 8718.5 8767.0 8813.0 8849.0 8851.5 8853.5 8862.0 8874.5 8878.0 8891.0 ~96.5 8902.°0 8905.5 8906.5 8910.0 8915.5 8920.0 8924.0 8930.5 8928.5 8933.0 8940.5 8943.5 8946.5 8949.5 8949.5 8952.5 8950.5 8954.0 8967.0 8968.5 8994.0 8995.5 8997.5 8999.0 8999.5 9002.0 9006.0 9009.5 9023.0 9027.0 9045.0 9049.0 9094.5 9098.5 9100.5 9103.0 9111.0 9115.0 9117.5 9121.0 9132.5 9134.5 9143.5 9147.0 9160.0 9161.5 9165.5 9167.5 9182.5 9184.5 9210.0 9212.0 9235.5 9238.5 9239.5 9241.0 9247.5 9252.5 9265.5 ': 9267.0 9269.0 9270.5 9279.0 9281.5 10439.5 10442.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 4 MWD 5 MWD 6 MWD 7 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 3818.0 5689.0 5689.0 7-688.0 7688.0 9338.0 9338.0 10442.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD Om~M 4 1 68 RPM MWD, OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 16 20 24 28 Name Min Max Mean Nsam DEPT 3780 10439.5 7109.75 13320 ROP 4.062 2158.59 147,276 13250 GR 8.5764 368.761 72.906 13223 RPX -9991 2000 -943.762 2391 RPS -9991 2000 -942.665 2391 RPM -9991 2000 -938.81 2391 RPD -9991 2000 -929.086 2391 FET -9991 3.523 -960.143 2391 First Reading 3780 3815 3780 9198 9198 9198 9198 9198 Last Reading 10439.5 10439.5 10391 10398 10398 10398 10398 10398 First Reading For Entire File .......... 3780 Last Reading For Entire File ........... 10439.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name.,. Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE S~Y PBU TOOL CODE START DEPTH FET 9318.0 RPD 9318.0 RPM 9318.0 RPS 9318.0 RPX 9318.0 GR 9318.0 RAT 9318.0 $ STOP DEPTH 10398.0 10398.0 10398.0 10398.0 10398.0 10391.0 10439.5 MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: MAD RUN NO. MAD PASS NO. 7 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 9320.5 Name Service Order Units Size Nsam DEPT FT 4 1 RAT MAD FT/H 4 1 GR MAD AAPI 4 1 RPX MAD OHMS4 4 1 RPS MAD OHMM 4 1 RPM MAD OHMM 4 1 RPD MAD OHMM 4 1 FET MAD HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 MERGE BASE 10442.O First Name Min Max Mean Nsam Reading DEPT 9318 10439.5 9878.75 2244 9318 RAT 68.5419 4658.2 372.527 2244 9318 GR 24.1841 100.262 53.343 2147 9318 RPX 1.0801 47.1643 18.3915 2161 9318 RPS 7.6447 2000 20.4457 2161 9318 RPM 7.9804 2000 21.7149 2161 9318 RPD 10.6956 2000 25.9494 2161 9318 FET 6.5536 31.1662 17.5907 2161 9318 Last Reading 10439.5 10439.5 10391 10398 10398 10398 10398 10398 First Reading For Entire File .......... 9318 Last Reading For Entire File ........... 10439.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Con~nent Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3783.0 ROP 3818.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5653.0 5688.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 14-NOV-96 ISC 4.88 MWD 5.46 / SP4 5.03 MEMORY 5689.0 3818.0 5689.0 .3 .9 TOOL NUMBER P0606CG6 8.500 8.5 LSND 9.80 56.0 9.7 1100 7.4 .000 .000 .000 .000 36.7 REMARKS: $ Data Format Specification Rgcord Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 3783 5688.5 4735.75 3812 3783 GR 8.5764 109.589 60.9915 3741 3783 ROP 12.1336 1986.72 259.595 3742 3818 Last Reading 5688.5 5653 5688.5 First Reading For Entire File .......... 3783 Last Reading For Entire File ........... 5688.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE $~ART DEPTH GR 5500.0 ROP 5500.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7652.5 7687.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~ RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMI~)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 17-NOV-96 ISC 4.88 MWD 5.46 / SP4 5.03 MEMORY 7688.0 5689.0 7688.0 .5 21.1 TOOL NUMBER P0606CG6 8.500 8.5 LSND 9.90 45.0 9.4 1200 4.6 .000 .000 .000 .000 44.5 Name Service Order Un,ns Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5500 7687.5 6593.75 4376 5500 GR 8.5764 164.159 70.6902 4306 5500 ROP 6.0175 1381.07 138.445 4376 5500 Last Reading 7687.5 7652.5 7687.5 First Reading For Entire File .......... 5500 Last Reading For Entire File ........... 7687.5 File Trailer Service name ............. STSLIB..004 Service Sub Level Name... Version Number ........... 1.0.0 Date-of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Con~nent Record FILE HETkDER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7651.5 9314.5 ROP 7675.0 9338.0 $ LOG HEADER DATA DATE LOGGED: 20-NOV-96 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): ISC 4.88 MWD 5.46 / SP4 5.03 MEMORY 9338.0 7688.0 9338.0 HOLE INCLINATION (DmG MIRIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 13.2 86.2 TOOL NUMBER P0606CG6 8.500 8.5 LSND 9.80 58.0 9.2 900 4.0 .000 .000 .000 .000 52.2 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 7651.5 9338 8494.75 3374 7651.5 GR 15.5657 368.761 100.022 3327 7651.5 ROP 4.062 458.438 59.0617 3327 7675 Last Reading 9338 9314.5 9338 First Reading For Entire File .......... 7651.5 Last Reading For Entiz~ File ........... 9338 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 . Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9208.0 10393.5 RPD 9214.5 10400.5 RPM 9214.5 10400.5 RPS 9214.5 10400.5 RPX 9214.5 10400.5 FET 9255.5 10400.5 ROP 9257.0 10442.0 $ LOG HEADER DATA DATE LOGGED: 26-NOV-96 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.8 MAXIMUM ANGLE: 94.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ ISC 4.88 MWD 5.46 / SP4 5.03 MEMORY 10442.0 9338.0 10442.0 TOOL NUMBER P0388SP4 P0388SP4 BOREHOLE AND CASING DATA OPBN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.000 6.0 SHEARDRI L 8.80 43.0 8.7 9000 - 5.6 .47O .340 .430 .440 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 RPX MWD 7 OHMS4 4 1 68 8 3 RPS MWD 7 OHN~ 4 1 68 12 4 RPM MWD 7 OPrMM 4 1 68 16 5 RPD MWD 7 OHMM 4 1 68 20 6 FET MWD 7 HOUR 4 1 68 24 7 ROP MWD 7 FT/H 4 1 68 28 8 58.3 First Name Min Max Mean Nsam Reading DEPT 9208 10442 9825 2469 9208 GR 20.7544 85.7764 52.2601 2372 9208 RPX 0.7265 2000 19.3134 2373 9214.5 RPS 0.9534 2000 18.8478 2373 9214.5 RPM 0.1498 2000 116.862 2373 9214.5 RPD 0.271 2000 138.409 2373 9214.5 FET 0.3908 3.6787 1.0663 2291 9255.5 ROP 5.2313 2158.59 128.462 2371 9257 Last Reading 10442 10393.5 10400.5 10400.5 10400.5 10400.5 10400.5 10442 First Reading For Entl~e File .......... 9208 Last Rea~ing For Entire File ........... 10442 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NIIMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 7 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9320.5 10400.5 RPD 9320.5 10400.5 RPM 9320.5 10400.5 RPS 9320.5 10400.5 RPX 9320.5 10400.5 GR 9320.5 10393.5 RAT 9320.5 10442.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 26-NOV-96 ISC 4.88 MWD 5.46 / SP4 5.03 MEMORY 10442.0 9338.0 10442.0 89.8 94.5 TOOL NUMBER P0388SP4 P0388SP4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OH/~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.000 6.0 SHEARDRIL 8.80 43.0 8.7 9000 5.6 .470 .340 .430 .440 .5 Name Service Order Units Size Nsam DEPT FT 4 1 RAT MAD 7 FT/H 4 1 GR MAD 7 AAPI 4 1 RPX MAD 7 OHM~ 4 1 RPS MAD 7 OH~M 4 1 RPD MAD 7 OH/~M 4 1 FET MAD 7 HOUR 4 1 RPM MAD 7 OHMS4 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 58.3 Name Min Max DEPT 9320.5 10442 RAT 68.5419 4658.2 GR 24.1841 100.262 RPX 1.0801 47.1643 RPS 7.6447 2000 RPD 10.6956 2000 FET 6.5536 31.1662 RPM 7.9804 2000 First Last Mean Nsam Reading Reading 9881.25 2244 9320.5 10442 372.527 2244 9320.5 10442 53.343 2147 9320.5 10393.5 18.3915 2161 9320.5 10400.5 20.4457 2161 9320.5 10400.5 25.9494 2161 9320.5 10400.5 17.5907 2161 9320.5 10400.5 21.7149 2161 9320.5 10400.5 First Reading For Entire File .......... 9320.5 Last Reading For Entire File ........... 10442 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/31 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/03/31 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * . ............................ * ....... SCHLUMBERGER ....... . ............................ * COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 11-37 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292271600 REFERENCE NO : 96376 Date.._ RECEIVED LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE ' 97/02/27 ORIGIN : FLIC REEL NAME : 96376 CONTINUATION # : PREVIOUS REEL : CORR4ENT : ARCO ALASKA INC, D.S. 11-37, PRUDHOE BAY, API #50-029-22716-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/02/27 ORIGIN · FLIC TAPE NAME : 96376 CONTINUATION # : 1 PREVIOUS TAPE : COI~IENT : ARCO ALASKA INC, D.S. 11-37, PRUDHOE BAY, API #50-029-22716-00 TAPE HEADER Prudhoe Bay OPEN HOLE WIRELINE LOGS WELL NAME: API ~ER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB N[RVZBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION RUN1 96376 ERIC BARTZ JACKSON SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING DS 11-37 500292271600 ARCO Alaska Inc. SCHLUMBERGER WELL SERVICES 26-FEB-97 RUN 2 RUN 3 34 lin 1SE 4628 4639 53.40 25.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ................................ 8.500 9.625 3808.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE OPEN HOLE LDWG FORMATTED EDIT ON ARCO ALASKA, INC. WELL DS 11-37. LOGS ACQUIRED ARE ARRAY INDUCTION/PLATFORMEXPRESS/BOREHOLE COMPENSATED SONIC. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLENAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE .............. AIT SDN CNT BCS $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (FZEASURED DEPTH) START DEPTH STOP DEPTH 9328.0 7995.0 9310.0 7906.0 9297.0 7906.0 9281.0 7890.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: THIS FILE CONTAINS THE CLIPPED DATA ACQUIRED IN OPEN HOLE. NO DEPTH CORRECTIONS TO A BASE GAMMA RAY WERE APPLIED TO THIS DATA AS THESE ARE THE PRIMARY DEPTH CONTROL LOGS. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... AIT SDN CNT BCS ............................ RUN NO. PASS NO. ............... MERGE TOP MERGE BASE ................... LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 140 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 7 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 ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI O0 000 O0 0 1 1 1 4 68 0000000000 SP AIT MV O0 000 O0 0 1 1 1 4 68 0000000000 TENS AIT LB O0 000 O0 0 1 1 1 4 68 0000000000 TEND AIT LB O0 000 O0 0 1 1 1 4 68 0000000000 MRES AIT OH~ff~ O0 000 O0 0 1 1 1 4 68 0000000000 MTEMAIT DEGF O0 000 O0 0 1 1 1 4 68 0000000000 DEV AIT DEG O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 N-RAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN OH~ O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN OH~ O0 000 O0 0 1 1 1 4 68 0000000000 RiNOR SDN Otfi~I O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 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) CALl AIT IN O0 000 O0 0 1 1 1 4 68 0000000000 ATiO AIT OH~ O0 000 O0 0 1 1 1 4 68 0000000000 AT20 AIT OH~M O0 000 O0 0 1 1 1 4 68 0000000000 AT30 AIT OH~M O0 000 O0 0 1 1 1 4 68 0000000000 AT60 AIT OH~M O0 000 O0 0 1 1 1 4 68 0000000000 AT90 AIT OH~M O0 000 O0 0 1 1 1 4 68 0000000000 AFiO AIT OH~M O0 000 O0 0 1 1 1 4 68 0000000000 AF20 AIT OH~ O0 000 O0 0 1 1 1 4 68 0000000000 AF30 AIT OH~ff~ O0 000 O0 0 1 1 1 4 68 0000000000 AF60 AIT OH~M O0 000 O0 0 1 1 1 4 68 0000000000 AF90 AIT OHMM O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9329.000 GR.BCS TEND.AIT 579.742 ~I~ES.AIT CNTC. CNT -999.250 CFTC. CNT CRAT. CNT -999.250 NRAT. CNT DT. BCS -999.250 CAL1.SDN RHOB.SDN -999.250 MSFL.SDN CAL1.AIT -999.250 ATiO.AIT AT60.AIT -999.250 AT90.AIT AF30.AIT -999.250 AF60.AIT -999 250 0 765 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 DEPT. 7886.000 GR.BCS -999.250 TEND.AIT -999.250 ~ES.AIT -999.250 CNTC. CNT -999.250 CFTC. CNT -999.250 CRAT. CNT -999.250 NRAT. CNT -999.250 DT.BCS -999.250 CAL1.SDN -999.250 RHOB.SDN -999.250 MSFL.SDN -999.250 CAL1.AIT -999.250 ATiO.AIT -999.250 AT60.AIT -999.250 AT90.AIT -999.250 AF30.AIT -999.250 AF60.AIT -999.250 SP.AIT -999.250 TENS.AIT MTEM. AIT 159.928 DEV. AIT FCNT. CNT -999.250 NCNT. CNT NPHI.CNT -999.250 CPHI.CNT DRHO.SDN -999.250 PEF. SDN MINV. SDN -999.250 ~INOR.SDN AT20.AIT -999.250 AT30.AIT AFiO.AIT -999.250 AF20.AIT AF90.AIT -999.250 SP.AIT MTEM. AIT -999 FCNT. CNT -999 NPHI.CNT -999 DRHO. SDN -999 MINV. SDN -999 AT20.AIT -999 AFiO.AIT -999 AF90.AIT -999 -24 125 TENS.AIT 250 DEV. AIT 250 NCNT. CNT 250 CPHI.CNT 250 PEF. SDN 250 ~NOR.SDN 250 AT30.AIT 250 AF20.AIT 25O 3366.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 20 121 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE ' 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER 2 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUN~ER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH AIT 9330.0 PEX 9310.0 BHC 9283.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) LOGGING SPEED (FPHR) : STOP DEPTH .......... 8000.0 8000.0 8000.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 20-NOV-96 8B0-538 130 22-NOV-96 1630 22-NOV-96 9337.0 9330.0 7886.0 9329.0 1800.0 TOOL NUMBER ........... AMS-A SDT-C HILTB-DTB AIT-H 122 8.500 3808.0 3808.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 56.0 MUD PH : 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 165.0 RESISTIVITY (Ot~V~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.090 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1. 770 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 2. 030 MUD CAKE AT (BHT) .. 69.0 70.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: PLATFORM EXPRESS AND BHC RUN IN COMBINATION TOOLS CONVEYED BY DRILL PIPE (TLC). FIVE 1.5" STANDOFFS RUN ON SONIC. TWO 1.5" STANDOFFS RUN ON AIT. TWO TOOL TURNERS USED TO ORIENT DENSITY AND NEUTRON FACING BOTTOM SIDE OF HOLE. BRIDGED AT 8870 ON 1ST ATTEMPT & LOGGED OUT TO 8000'. REACHED TD ON 2ND ATTEMPT & LOGGED TO 8559' AS PER CLIENT REQUEST. MAIN LOG SPLICED 8700'. MCFL EXTREMELY SENSITIVE TO RUGOSE/WASHED OUT HOLE. UNDERGAUGE HOLE FROM TD TO 9260' PROBABLY DUE TO TOOL BEING ON ITS SIDE. RIG IS DOYON #16. THIS FILE CONTAINS THE RAW MAIN LOG DATA, ALL CURVES SAMPLED AT 0.5'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 164 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 7 TYPE REPR CODE VALUE 6 73 7 65 8 68 O. 5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAIN ** 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 GR BHC GAPI TENS AIT LB HTEN AIT LB f4RES AIT OHM~I MTEM AIT DEGF GDEV AIT DEG CNTC PEX CPS CFTC PEX CPS RCFT PEX CPS RCNT PEX CPS TNRA PEX RTNR PEX TNPH PEX PU NPHI PEJf PU NPOR PEX PU DT BHC US/F TT1 BHC US TT2 BHC US TT3 BHC US TT4 BHC US HCAL PEX IN RHOZ PEX G/C3 HDRA PEX G/C3 PEFZ PEX DPHZ PEX PU H~IN PEX OH~ H~NO PEX OH~ RXOZ PEX OH~4 AT10 AIT OH~ AT20 AIT OH~ AT30 AIT OH~4 AT60 AIT OH~M AT90 AIT O~ O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 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) AFiO AIT OH~k~ O0 000 O0 0 2 1 1 4 68 0000000000 AF20 AIT OH~ O0 000 O0 0 2 1 1 4 68 0000000000 AF30 AIT OH~4 O0 000 O0 0 2 1 1 4 68 0000000000 AF60 AIT OH~ O0 000 O0 0 2 1 1 4 68 0000000000 AF90 AIT OH~4~ O0 000 O0 0 2 1 1 4 68 0000000000 AIBD AIT IN O0 000 O0 0 2 1 1 4 68 0000000000 SP AIT MV O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9330.000 GR.BHC MRES.AIT 0.765 MTE~.AIT CFTC. PEX 1171.553 RCFT.PEX RTNR . PEX 2.823 TNPH . PEX DT. BHC 79. 500 TT1 . BHC TT4.BHC 351.200 HCAL.PEX PEFZ.PEX -999.250 DPHZ.PEX RXOZ.PEX 3.339 ATiO.AIT AT60.AIT 16.918 ATgO.AIT AF30.AIT 19.779 AF60.AIT SP.AIT -67.438 66.970 159 928 997 654 27 888 541 200 7 021 60721 211 11.285 16.295 17.354 TENS. AIT 2654. 000 HTEN. AIT GDEV. AIT -999. 250 CNTC. PEX RCNT. PEX 2774. 524 TNRA. PEX NPHI.PEX 29. 457 NPOR.PEX TT2. BHC 399. 200 TT3 . BHC RHOZ. PEX - 999.250 HDRA. PEX H~fIN. PEX 1.514 H~NO. PEX AT20.AIT 19. 436 AT30.AIT AFiO.AIT 11.284 AF20.AIT AF90.AIT 16. 365 AIBD.AIT -1136.220 3006.542 2.598 27.508 527.200 -999.250 1.887 18.575 19.458 7.021 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 9 FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING ~ER: 1 PASS ~ER : 2 DEPTH INCREMENT: 0.2500 FILE SUAg~ARY VENDOR TOOL CODE START DEPTH AIT 9330.0 PEX 9310.0 BHC 9283.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 8000.0 8000.0 8000.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (Otfi~4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): 20-NOV-96 8B0-538 130 22-NOV-96 1630 22-NOV-96 9337.0 9330.0 7886.0 9329.0 1800.0 TOOL NUMBER ........... SDT- C HILTB -DTB AIT-H 122 8.500 3808.0 3808.0 LSND 10.00 56.0 8.5 165.0 2. 090 69.0 1. 770 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 10 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 2. 030 THERMAL SANDSTONE 2.65 68.0 TOOL STANDOFF (IN): 1.5 REMARKS: PLATFORM EXPRESS AND BHC RUN IN COMBINATION TOOLS CONVEYED BY DRILL PIPE (TLC). FIVE 1.5" STANDOFFS RUN ON SONIC. TWO 1.5" STANDOFFS RUN ON AIT. TWO TOOL TURNERS USED TO ORIENT DENSITY AND NEUTRON FACING BOTTOM SIDE OF HOLE. BRIDGED AT 8870 ON 1ST ATTEMPT & LOGGED OUT TO 8000'. REACHED TD ON 2ND ATTEMPT & LOGGED TO 8559' AS PER CLIENT REQUEST. MAIN LOG SPLICED 8700'. MCFL EXTREMELY SENSITIVE TO RUGOSE/WASHED OUT HOLE. UNDERGAUGE HOLE FROM TD TO 9260' PROBABLY DUE TO TOOL BEING ON ITS SIDE. RIG IS DOYON #16. THIS FILE CONTAINS THE RAW MAIN LOG DATA, ALL CURVES SAMPLED AT O. 25 '. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 21 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-FEB-1997 14:11 PAGE: 11 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NURiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT O0 000 O0 0 3 1 1 ATIO AIT OH~ff~ O0 000 O0 0 3 1 1 AT20 AIT OI~4M O0 000 O0 0 3 1 1 AT30 AIT OPiMM O0 000 O0 0 3 1 1 AT60 AIT OH~ff~ O0 000 O0 0 3 1 1 AT90 AIT OI~4M O0 000 O0 0 3 1 1 AFiO AIT OH~M O0 000 O0 0 3 1 1 4 68 0000000000 AF20 AIT OHI4M O0 000 O0 0 3 1 1 4 68 0000000000 AF30 AIT OtflVlM O0 000 O0 0 3 1 1 4 68 0000000000 AF60 AIT OH~M O0 000 O0 0 3 1 1 4 68 0000000000 AF90 AIT OPi~ O0 000 O0 0 3 1 1 4 68 0000000000 AIBD AIT IN O0 000 O0 0 3 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** DEPT. 9330. 000 ATiO.AIT 11.285 AT20 .AIT 19. 436 AT30.AIT AT60.AIT 16. 918 AT90.AIT 16. 295 AFiO.AIT 11. 284 AF20.AIT AF30 .AIT 19. 779 AF60.AIT 17. 354 AF90 .AIT 16. 365 AIBD.AIT DEPT. 7886.250 ATIO.AIT 1.324 AT20.AIT 1.316 AT30.AIT AT60.AIT 1 . 338 AT90.AIT 1 . 297 AFiO.AIT 1 . 449 AF20.AIT AF30.AIT 1 . 476 AF60.AIT 1 . 482 AF90.AIT 1 . 435 AIBD.AIT 18.575 19. 458 7. 021 1.247 1. 473 8. 726 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~iE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 12 FILE HEADER FILE NDW~ER 4 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 FILE SU~4~zARY VENDOR TOOL CODE START DEPTH ........................... AIT 9330.0 PEX 9310.0 BHC 9283.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 8000.0 8000.0 8000.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 20-NOV-96 8B0-$38 130 22-NOV-96 1630 22-NOV-96 9337.0 9330.0 7886.0 9329.0 1800.0 TOOL NUMBER ........... AMS - A SDT-C HILTB-DTB AIT-H 122 8.500 3808.0 3808.0 LSND 10. O0 56.0 8.5 165.0 2. 090 69.0 1.770 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 13 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): 2. 030 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: PLATFORM EXPRESS AND BHC RUN IN COMBINATION TOOLS CONVEYED BY DRILL PIPE (TLC). FIVE 1.5" STANDOFFS RUN ON SONIC. TWO 1.5" STANDOFFS RUN ON AIT. TWO TOOL TURNERS USED TO ORIENT DENSITY AND NEUTRON FACING BOTTOM SIDE OF HOLE. BRIDGED AT 8870 ON 1ST ATTEMPT & LOGGED OUT TO 8000'. REACHED TD ON 2ND ATTEMPT & LOGGED TO 8559' AS PER CLIENT REQUEST. MAIN LOG SPLICED 8700'. MCFL EXTREMELY SENSITIVE TO RUGOSE/WASHED OUT HOLE. UNDERGAUGE HOLE FROM TD TO 9260' PROBABLY DUE TO TOOL BEING ON ITS SIDE. RIG IS DOYON #16. THIS FILE CONTAINS THE RAW MAIN LOG DATA, ALL CURVES SAMPLED AT O. 1667'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verifi'cation Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 14 ** 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 O0 000 O0 0 4 1 1 4 68 0000000000 RHOZ PEX G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 I{DRA PEX G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 PEFZ PEX O0 000 O0 0 4 1 1 4 68 0000000000 DPHZ PEX PU O0 000 O0 0 4 1 1 4 68 0000000000 H~dIN PEX OH~4 O0 000 O0 0 4 1 1 4 68 0000000000 HfflNOPEX OIk~4 O0 000 O0 0 4 1 1 4 68 0000000000 RXOZ PEX OI~ff4 O0 000 O0 0 4 1 1 4 68 0000000000 RX08 PEX OI~I O0 000 O0 0 4 1 1 4 68 0000000000 HCNT PEX CPS O0 000 O0 0 4 1 1 4 68 0000000000 HCFT PEX CPS O0 000 O0 0 4 1 1 4 68 0000000000 HGR PEX GAPI O0 000 O0 0 4 1 1 4 68 0000000000 RHFT PEX CPS O0 000 O0 0 4 1 1 4 68 0000000000 RHNT PEX CPS O0 000 O0 0 4 1 1 4 68 0000000000 HTNP PEX PU O0 000 O0 0 4 1 1 4 68 0000000000 HNPO PEX PU O0 000 O0 0 4 1 1 4 68 0000000000 TT1 BHC US O0 000 O0 0 4 1 1 4 68 0000000000 TT2 BHC US O0 000 O0 0 4 1 1 4 68 0000000000 TT3 BHC US O0 000 O0 0 4 1 1 4 68 0000000000 TT4 BHC US O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9330.000 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX DPHZ.PEX 60721.211 H~IN. PEX 1.514 BlviNO.PEX 1.887 RXOZ.PEX RXO8.PEX 3.333 HCNT. PEX 3006.543 HCFT. PEX 1171.553 HGR.PEX RHFT. PEX 997.654 RHNT. PEX 2774.524 HTNP.PEX 27.888 HNPO.PEX TT1.BHC 541.200 TT2.BHC 399.200 TT3.BHC 527.200 TT4.BHC DEPT. 7886.167 RHOZ.PEX 2.408 HDRA.PEX -0.034 PEFZ.PEX DPHZ.PEX 14.683 H~IN. PEX 3.622 H~iNO.PEX 3.154 RXOZ.PEX RXO8.PEX 3.797 HCNT. PEX 2314.580 HCFT. PEX 905.699 HGR.PEX RHFT. PEX 660.296 RHNT. PEX 2293.086 HTNP.PEX 27.379 HNPO.PEX TT1.BHC 613.600 TT2.BHC 434.400 TT3.BHC 612.800 TT4.BHC -999.250 3.339 66.970 27.508 351.200 3.449 3.797 184.702 28.434 422.800 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 15 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION - O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN~ER: TOOL STRING NUMBER: PASS NI]M~ER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER 5 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 2 0.0833 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 9330.0 8000.0 PEX 9310.0 8000.0 BHC 9283.0 8000.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 20-NOV-96 8B0-538 130 22-NOV-96 1630 22-NOV-96 9337.0 9330.0 7886.0 9329.0 1800.O TOOL NUMBER ........... LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 16 AMS BHC PEX AIT $ AUX. MEAS. BOREHOLE COMP. SONIC PLATFORM EXPRESS ARRAY INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. LOGGERS CASING DEPTH (FT) : AMS- A SDT- C HILTB -DTB AIT-H 122 8.500 3808.0 3808.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 56.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 165.0 RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.090 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1. 770 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 2.030 MUD CAKE AT (BHT) : 69.0 70.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: PLATFORM EXPRESS AND BHC RUN IN COMBINATION TOOLS CONVEYED BY DRILL PIPE (TLC). FIVE 1.5" STANDOFFS RUN ON SONIC. TWO 1.5" STANDOFFS RUN ON AIT. TWO TOOL TURNERS USED TO ORIENT DENSITY AND NEUTRON FACING BOTTOM SIDE OF HOLE. BRIDGED AT 8870 ON 1ST ATTEMPT & LOGGED OUT TO 8000'. REACHED TD ON 2ND ATTEMPT & LOGGED TO 8559' AS PER CLIENT REQUEST. MAIN LOG SPLICED 8700'. MCFL EXTREMELY SENSITIVE TO RUGOSE/WASHED OUT HOLE. UNDERGAUGE HOLE FROM TD TO 9260' PROBABLY DUE TO TOOL BEING ON ITS SIDE. RIG IS DOYON #16. THIS FILE CONTAINS THE RAW MAIN LOG DATA, ALL CURVES SAMPLED AT O. 0833'. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 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 O0 000 O0 0 5 1 1 4 68 0000000000 HCAL PEX IN O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9330.000 HCAL.PEX 7.021 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .005 SERVICE . FLIC VERSION . O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 18 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU7~CARY FILE HEADER FILE NUMBER 6 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 8872.0 8560.0 PEX 8870.0 8560.0 BHC 8874.0 8560.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... AMS AUX. MEAS. BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS 20-NOV-96 8B0-538 130 22-NOV-96 1630 22-NOV-96 9337.0 9330.0 7886.0 9329.0 1800.0 TOOL NUMBER ........... AMS-A SDT-C HILTB -DTB AIT-H 122 8.500 3808.0 3808.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 19 MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 56.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 165.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 090 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1. 770 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 2. 030 MUD CAKE AT (BHT) : 69.0 70.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN) '. 1.5 REM_ARKS: PLATFORM EXPRESS AND BHC RUN IN COMBINATION TOOLS CONVEYED BY DRILL PIPE (TLC). FIVE 1.5" STANDOFFS RUN ON SONIC. TWO 1.5" STANDOFFS RUN ON AIT. TWO TOOL TURNERS USED TO ORIENT DENSITY AND NEUTRON FACING BOTTOM SIDE OF HOLE. BRIDGED AT 8870 ON 1ST ATTEMPT & LOGGED OUT TO 8000'. REACHED TD ON 2ND ATTEMPT & LOGGED TO 8559' AS PER CLIENT REQUEST. MAIN LOG SPLICED 8700'. MCFL EXTREMELY SENSITIVE TO RUGOSE/WASHED OUT HOLE. UNDERGAUGE HOLE FROM TD TO 9260' PROBABLY DUE TO TOOL BEING ON ITS SIDE. RIG IS DOYON #16. THIS FILE CONTAINS THE RAW REPEAT LOG DATA ACQUIRED AT 0.5' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 2O TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 15 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 O0 000 O0 0 6 1 1 4 68 0000000000 GR BHC GAPI O0 000 O0 0 6 1 1 4 68 0000000000 TENS AIT LB O0 000 O0 0 6 1 1 4 68 0000000000 HTEN AIT LB O0 000 O0 0 6 1 1 4 68 0000000000 MRES AIT OH~M O0 000 O0 0 6 1 1 4 68 0000000000 MTEMAIT DEGF O0 000 O0 0 6 1 1 4 68 0000000000 GDEVAIT DEG O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PEX CPS O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PEX CPS O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PEX CPS O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PEX CPS O0 000 O0 0 6 1 1 4 68 0000000000 TN-RA PEX O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PEX O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PEX PU O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PEX PU O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PEX PU O0 000 O0 0 6 1 1 4 68 0000000000 DT BHC US/F O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 8874.000 GR.BHC 50.758 TENS.AIT 706.000 HTEN. AIT MRES.AIT 0.857 MTEM. AIT 147.424 GDEV. AIT -999.250 CNTC. PEX CFTC. PEX 1578.092 RCFT. PEX 1331.124 RCNT. PEX 2952.331 TNRA.PEX RTNR.PEX 2.232 TNPH. PEX 19.530 NPHI.PEX 19.714 NPOR.PEX DT.BHC 98.700 DEPT. 8558.000 GR.BHC 42.104 TENS.AIT 1166.000 HTEN. AIT M2~ES.AIT 0.908 MTEM. AIT 144.906 GDEV. AIT 16.869 CNTC. PEX CFTC. PEX 1716.866 RCFT. PEX 1422.810 RCNT. PEX 3242.220 TNRA.PEX RTNR.PEX 2.291 TNPH. PEX 18.666 NPHI.PEX 18.700 NPOR.PEX DT. BHC 95.800 1071.658 3201.268 2.054 19.241 1273. 296 3381. 656 1. 981 16. 888 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 21 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION . O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE - 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENt: FILE FILE HEADER FILE NUMBER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 8872.0 8560.0 PEX 8870.0 8560.0 BHC 8874.0 8560.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 20-NOV-96 8B0-538 130 22-NOV-96 1630 22-NOV-96 9337.0 9330.0 7886.0 9329.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 22 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM I~OLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : TOOL NUMBER AMS - A SDT-C HILTB -DTB AIT-H 122 8.500 3808.0 3808.0 LSND 10.00 56.0 8.5 165.0 2. 090 69.0 1. 770 70.0 2. 030 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: PLATFORM EXPRESS AND BHC RUN IN COMBINATION TOOLS CONVEYED BY DRILL PIPE (TLC). FIVE 1.5" STANDOFFS RUN ON SONIC. TWO 1.5" STANDOFFS RUN ON AIT. TWO TOOL TURNERS USED TO ORIENT DENSITY AND NEUTRON FACING BOTTOM SIDE OF HOLE. BRIDGED AT 8870 ON 1ST ATTEMPT & LOGGED OUT TO 8000 '. REACHED TD ON 2ND ATTEMPT & LOGGED TO 8559' AS PER CLIENT REQUEST. MAIN LOG SPLICED 8700'. MCFL EXTREMELY SENSITIVE TO RUGOSE/WASHED OUT HOLE. UNDERGAUGE HOLE FROM TD TO 9260' PROBABLY DUE TO TOOL BEING ON ITS SIDE. RIG IS DOYON #16. THIS FILE CONTAINS THE RAW REPEAT LOG DATA ACQUIRED AT 0.25' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 21 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 ELE~ CODE (HEX) DEPT FT O0 000 O0 0 7 1 1 4 68 0000000000 ATiO AIT OH~4 O0 000 O0 0 7 1 1 4 68 0000000000 AT20 AIT OH~ O0 000 O0 0 7 1 1 4 68 0000000000 AT30 AIT OH~ O0 000 O0 0 7 1 1 4 68 0000000000 AT60 AIT OH~4 O0 000 O0 0 7 1 1 4 68 0000000000 AT90 AIT OH~ O0 000 O0 0 7 1 1 4 68 0000000000 AFiO AIT OH~ O0 000 O0 0 7 1 1 4 68 0000000000 AF20 AIT OH~4 O0 000 O0 0 7 1 1 4 68 0000000000 AF30 AIT OH~ O0 000 O0 0 7 1 1 4 68 0000000000 AF60 AIT OH~M O0 000 O0 0 7 1 1 4 68 0000000000 AF90 AIT OH~ O0 000 O0 0 7 1 1 4 68 0000000000 AIBD AIT IN O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 8874. 000 ATiO.AIT 7. 754 AT20.AIT 10. 161 AT30 .AIT AT60.AIT 11. 720 AT90.AIT 15. 734 AFiO.AIT 7. 730 AF20 .AIT AF30.AIT 9. 988 AF60.AIT 11. 854 AF90.AIT 15. 714 AIBD.AIT 10.574 10. 101 8.508 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 24 DEPT. 8557. 750 ATIO.AIT AT60 .AIT 84. 682 AT90.AIT AF30 .AIT 76. 313 AF60.AIT 69. 777 AT20 .AIT 96. 653 AFiO.AIT 92.142 AF90. AIT 66. 713 AT30.AIT 69. 972 AF20.AIT 103. 810 AIBD.AIT 69. 768 71.376 8. 415 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT . 007 SERVICE · FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN ~ER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUAg~ARY FILE HEADER FILE NUMBER 8 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH AIT 8872.0 8560.0 PEX 8870.0 8560.0 BHC 8874.0 8560.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): 20-NOV-96 8B0-538 130 22-NOV-96 1630 22-NOV-96 9337.0 9330.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 25 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ 7886.0 9329.0 1800.0 TOOL NUMBER ........... AMS - A SDT-C HILTB-DTB AIT-H 122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 3808.0 3808.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 56.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 165.0 RESISTIVITY (OH~2~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 090 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1. 770 MUD FILTRATE AT (BHT): MUD CAKE AT (MT): 2. 030 MUD CAKE AT (BHT) : 69.0 70.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: PLATFORM EXPRESS AND BHC RUN IN COMBINATION TOOLS CONVEYED BY DRILL PIPE (TLC). FIVE 1.5" STANDOFFS RUN ON SONIC. TWO 1.5" STANDOFFS RUN ON AIT. TWO TOOL TURNERS USED TO ORIENT DENSITY AND NEUTRON FACING BOTTOM SIDE OF HOLE. BRIDGED AT 8870 ON 1ST ATTEMPT & LOGGED OUT TO 8000'. REACHED TD ON 2NDATTE~PT & LOGGED TO 8559' AS PER CLIENT REQUEST. MAIN LOG SPLICED 8700'. MCFL EXTRE~iELY SENSITIVE TO RUGOSE/WASHED OUT HOLE. UNDERGAUGE HOLE FROM TD TO 9260' PROBABLY DUE TO TOOL BEING ON ITS SIDE. RIG IS DOYON #16. THIS FILE CONTAINS THE RAW REPEAT LOG DATA ACQUIRED AT 0.1667' SAMPLE RATE. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 26 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 12 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 O0 000 O0 0 8 1 1 4 68 0000000000 RHOZ PEX G/C3 O0 000 O0 0 8 1 1 4 68 0000000000 HDRA PEX G/C3 O0 000 O0 0 8 1 1 4 68 0000000000 PEFZ PEX O0 000 O0 0 8 1 1 4 68 0000000000 DPHZ PEX PU O0 000 O0 0 8 1 1 4 68 0000000000 H~IN PEX Otff~ O0 000 O0 0 8 1 1 4 68 0000000000 H~NO PEX Otff~M O0 000 O0 0 8 1 1 4 68 0000000000 RXOZ PEX OH~M O0 000 O0 0 8 1 1 4 68 0000000000 RX08 PEX OH~M O0 000 O0 0 8 1 1 4 68 0000000000 HCNT PEX CPS O0 000 O0 0 8 1 1 4 68 0000000000 HCFT PEX CPS O0 000 O0 0 8 1 1 4 68 0000000000 HGR PEX GAPI O0 000 O0 0 8 1 1 4 68 0000000000 RHFT PEX CPS O0 000 O0 0 8 1 1 4 68 0000000000 RHNT PEX CPS O0 000 O0 0 8 1 1 4 68 0000000000 HTNP PEX PU O0 000 O0 0 8 1 1 4 68 0000000000 HNPO PEX PU O0 000 O0 0 8 1 1 4 68 0000000000 TT1 BHC US O0 000 O0 0 8 1 1 4 68 0000000000 TT2 BHC US O0 000 O0 0 8 1 1 4 68 0000000000 TT3 BHC US O0 000 O0 0 8 1 1 4 68 0000000000 TT4 BHC US O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 27 ** DATA ** DEPT. 8874.000 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX DPHZ.PEX 60721.211 H~IN. PEX 4.818 HYiNO. PEX 6.699 RXOZ.PEX RXO8.PEX 39.302 HCNT. PEX 3201.269 HCFT. PEX 1578.092 HGR.PEX RHFT. PEX 1331.124 RHNT. PEX 2952.331 HTNP. PEX 19.530 HNPO.PEX TT1.BHC 637.600 TT2.BHC 442.400 TT3.BHC 618.400 TT4.BHC DEPT. 8557.834 RHOZ.PEX 2.108 HDRA.PEX -0.009 PEFZ.PEX DPHZ.PEX 32.865 I~4IN. PEX 4.828 H~NO.PEX 6.828 RXOZ.PEX RXO8.PEX 41.559 HCNT. PEX 3310.943 HCFT. PEX 1629.240 HGR.PEX RHFT. PEX 1385.105 RHNT. PEX 3512.326 HTNP. PEX 19.595 HNPO.PEX TT1.BHC 617.600 TT2.BHC 426.000 TT3.BHC 612.000 TT4.BHC -999.250 39. 265 50. 758 19.241 418. 800 3.266 43.651 38.427 17.993 417.600 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE · FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUAIBER: 1 DEPTH INCREMENT: 0.0833 FILE SUR~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 28 AIT 8872.0 PEX 8870.0 BHC 8874.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 8560.0 8560.0 8560.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. BHC BOREHOLE COMP. SONIC PEX PLATFORM EXPRESS AIT ARRAY INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 20-NOV-96 8B0-538 130 22-NOV-96 1630 22-NOV-96 9337.0 9330.0 7886.0 9329.0 1800.0 TOOL NUMBER ........... AMS - A SDT-C HILTB -DTB AIT-H 122 8.500 3808.0 3808.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 56.0 MUD PH : 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 165.0 RESISTIVITY (OHN~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 090 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1. 770 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 2. 030 MUD CAKE AT (BHT) : 69.0 70.0 68.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: PLATFORM EXPRESS AND BHC RUN IN COMBINATION LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 29 TOOLS CONVEYED BY DRILL PIPE (TLC). FIVE 1.5" STANDOFFS RUN ON SONIC. TWO 1.5" STANDOFFS RUN ON AIT. TWO TOOL TURNERS USED TO ORIENT DENSITY AND NEUTRON FACING BOTTOM SIDE OF HOLE. BRIDGED AT 8870 ON 1ST ATTEMPT & LOGGED OUT TO 8000'. REACHED TD ON 2ND ATTEMPT & LOGGED TO 8559' AS PER CLIENT REQUEST. MAIN LOG SPLICED 8700'. MCFL EXTREMELY SENSITIVE TO RUGOSE/WASHED OUT HOLE. UNDERGAUGE HOLE FROM TD TO 9260' PROBABLY DUE TO TOOL BEING ON ITS SIDE. RIG IS DOYON #16. THIS FILE CONTAINS THE RAW REPEAT LOG DATA ACQUIRED AT O. 0833 ' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 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 O0 000 O0 0 9 1 1 4 68 0000000000 HCAL PEX IN O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1997 14:11 PAGE: 3O DEPT. 8874.000 HCAL.PEX DEPT. 8558. 084 HCAL. PEX 8.508 8. 690 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/02/27 ORIGIN : FLIC TAPE NAME : 96376 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 11-37, PRUDHOE BAY, API #50-029-22716-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/02/27 ORIGIN : FLIC REEL NAME : 96376 CONTINUATION # : PREVIOUS REEL : CO~k4ENT · ARCO ALASKA INC, D.S. 11-37, PRUDHOE BAY, API #50-029-22716-00
