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STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOC REGo IF= 1VEED DEC 31 2019 t����� rwci2a3�4n)2r7 3BD SEW AN 0 21020 , ✓. � ' la. well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned IZ • Suspended ❑ 1b. Well Class: . 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero G /q o ry Dev ri �r- to ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 12/14/2019 193-186 • 319-446 3. Address: 7. Date. Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 4/29/1994 50-029-20107-01-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 5/2/1984 PBU 04 -OSA Surface: 742' FNL, 420' fEL, Sec. 34, T11 N. R15E, UM g Ref Elevations KB 53.26 17, Field/Pool(s): Top of Productive Interval: 1538' FSL, 3339' FEL, Sec. 27, TI 1N, R15E, UM GL 32.5 BE Surface PRUDHOE BAY, PRUDHOE OIL Total Depth: 1734' FSL, 3425' TEL, Sec. 27, T11N, R15E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: Surface/Surface ADL 028325 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 712433 y- 5951119 Zone - ASP 4 • 10294'/8944' 70-039 TPI: x- 709447 y- 5953316 Zone- ASP 12. SSSV Depth(MD/TVD): 20Thickness of Permafrost MD/IVD: Total Depth: x- 709355 y- 5953510 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No Q 13. Water Depth, if Offshore: 21, Re-drill/Lateral Top Window Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) MD/TVD: 8254'17297' 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, jewelry, and perforator, record. Acronyms may be used. Attach a separate page if necessary Cal/AC/DLV CNL/GR/MWD 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 30" 157.5# B Surface 105' Surface 105' 39" 257 sx Fondu 20" 94# H-40 Surface 961' Surface 961' 26" 935 sx PF II, 190 sx Fondu 13-3/8" 72# N-80 Surface 2700' Surface 2700' 17-1/2" 1000 sx PF II, 100 sx PF II 9 5/8" 47#/43.5# 40#/53.5# spo-s5/n�eo Surface 8254' Surface 7297' 12-1/4" 800 sx Cless'G', 250 sx PF II, 100 sx PF II T' 29# L-8Q113Cra0 8048' 10294' 7124' 8944' 8-1/2" 400 sx Cless'G' 24. Open to production or injection? Yes ❑ No m 25. TUBINGRECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perf l): GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 9617' 9538'18266' n �Y.1r4l1rX / 4-1/2" 12.6# 13Cr80 10043' - 10058' 10043-18711- 0043'/8711'26. 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing usetl during completion?Yes ❑ No 0Per 20 AAC 25.283 (i)(2) attach electronic antl printedinformation APT D_- DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Prodction Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size Gas -Oil Ratio: Test Period --► Flow Tubing Press Casing Press: I Calculated 24 Hour Rate --*� Oil -Bbl: Gas -MCF: Water -Bbl' Oil Gravity -API (corn: Form 10407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only t����� rwci2a3�4n)2r7 3BD SEW AN 0 21020 , ✓. � ' 26. CORE DATA Conventional Cores) Yes ❑ No m Sidewall Cores Yes ❑ No 0 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 D Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9758' 8454' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top Sadlerochit-Zone 4 9758' 8454' CGL - Zone 3 9831' 8519' Base of CGL -Zone 2 9902' 8583' Zone 1 10138' 8799' Base of Sadlerochit - Kavik 10177' 8835' Formation at total depth: Kavik 10177' 8835' 31. List of Attachments: Summary of Daily Work, Photo Documentation, 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 Orwell test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Worthington, Area J Authorized Tile: cialist Contact Email: Aras. Worthington@bp.mm Authorized Signature: ate: l %J�/q Contact Phone: +1 907 564 4102 INSTRUCTIONS General: This forth 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 10-407 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 1b. 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 in other given 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 details of 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 Orwell test results. Forth 10-407 Revised 5/2017 Submit ORIGINAL Only DRYHOLE OA CMT(1189/19) SURF -1312' 04,_05A 3o" cDND, 113' TX OOA PLUG SURF -500' 123/19) 20" CSG• 971' H40/ 133#, K-55 D=19.124" ANGLE AT TOP PERF: 23'@ 9760' Note: Refer to Production DB fpr historical perf data /COLLAR LEAK Q 10120" =�3800'"CHROME TBG& MCEVOY ATORLHEAD = REMOVED ELEV = 64' SHOT I SQZ 3-0/8' ELEV = 5326' 9760-9770 5' IA CMT PLUG (1026/19) X IAX OA PUNCH (11/13/19) :LEV = SURFACE = 3396'(1 PUNCHTBG&w(11/4119) WE nMD= 10199' L TAGGED TOC (11/04/19) TBG nTVD= 8800'SS• 06/18/16 -12' CAM BAL-O SSSV NP, D = 4.56- 3-3/8" 1 I TBG CMT(11109/19) —1000'-1312' TBG PUNCH, 4 SPF (1027119) 2700'-2705' 3/8" CSG, 72#, N-80 _, D =12.347" 2711' 5-12" TBG, 17#, 13CR-80 NSCC, _3092- .0232 bpf, D = 4.892" TOP OF T LNR 8048' 9-58" CSG, 47#, N -80/S-95, D = 8.6817—C8254' Minimum 1D= 3.813'@9517' 4-1/2" OTIS X NIPPLE ABANDONED WELLHEAD CUT 3.4' BELOW TUNDRA 12/14/19 4-1/2' TBG, 12.6#, 13CR-80 961 .0152 bpf, D = 3.958' ITOP OF 4-1/2'TBG I 4-12" TBG, 12.69, 13CR-80 FOX, .0152 bpf, D = 3.958' PERFORATION SUMMARY REF LOG: BHCS 05/03/94 ANGLE AT TOP PERF: 23'@ 9760' Note: Refer to Production DB fpr historical perf data S12E SPF INTERVAL NS z SHOT I SQZ 3-0/8' 6 9760-9770 C 01/09/16 RK 2-7/8' 6 9842-9852 C 06/18/16 41 3-3/8" 1 9960-9964 S 10/14/94 1126194 3-38' 4 9976-9980 S 08/09/94 1126/94 3-38' 1 10022 -10025 S 10/1484 112684 2-78" 6 10110 -10150 C 11/1887 5 2-7/8" 48 10150-10176 C 08/0984 RK T LNR 29#, 13CR-80 , .0371 bpf, D = 6.184' 5-112" X 4-12' XO, D = GAS LFT MAM]RR S STJ DATE REV BY COMMENTS PRUDHOE BAY UNIT 1081/19 BTMJMDTBG&14CMT(1028/19) WELL: 04-05A 11/11/19 TJS/JMD PUNCHED TBG&A-ELTAGGEDTOC PERMITNo: 1931860 11/11/19 MRD/JMD OACMT&TBGCMT- 11/09!19 APINo: 50-029-20107-01 11/18/19 MS/JMD TX AX OA PUNCH (11/13/19) SEC 34 T11 N R15E 742' FNL & 420' FEL 12!02!19 JJL/JMD TX ODA SURFACE CMT PLUG 1123119) 1280/19 JNL/JMD ABANDONED (12/14/19) BP Exploration (Alaska) DATE REV BY COMMENTS 1977 ORIGINAL COMPLETION VLV LATCH PORT DATE 1 3323 3320 9 MMG DOME RK 16 11/01/13 2 5295 5050 41 MMG SO RK 20 11/01/13 3 6668 6054 42 MMG DMY RK 0 10/31/13 4 7220 6467 40 MMG OMY RK 0 11/18/94 5 7727 6863 37 MMG OMY RK 0 0723/08 6 8019 7101 34 MMG DMY RK 0 0223/19 17052-- 9525' 1�TBG & IA CEMENT TAGGED 04 MLLOUT WNDOW (04-06A) 8254' - 951 T 4-12" OTIS X NIP, ID = 3.81" 1 9616' 1 1i09T�1 12' OTIS X NP, ID = 3.81' 1/2' XX PLUG (04/30/17) 12" WLEG, D = 3.958" FBWALL 363-700 HEX PLUG, 12" FN (06/18/16) X 4-1/2" BKR F7 ISOLATION N2'OTIS X NP n=381• ' 10049' H4-1/2" XX PLUG (1127/09) 10053' 4-1/2'OTS XN NP,D=3.725 10058' 4-12' WLEG, 1)=2.992' 1005T ELMD TT LOGGED 05/17/94 1 10294' 1 _za- 1.1 • DATE REV BY COMMENTS PRUDHOE BAY UNIT 1081/19 BTMJMDTBG&14CMT(1028/19) WELL: 04-05A 11/11/19 TJS/JMD PUNCHED TBG&A-ELTAGGEDTOC PERMITNo: 1931860 11/11/19 MRD/JMD OACMT&TBGCMT- 11/09!19 APINo: 50-029-20107-01 11/18/19 MS/JMD TX AX OA PUNCH (11/13/19) SEC 34 T11 N R15E 742' FNL & 420' FEL 12!02!19 JJL/JMD TX ODA SURFACE CMT PLUG 1123119) 1280/19 JNL/JMD ABANDONED (12/14/19) BP Exploration (Alaska) DATE REV BY COMMENTS 1977 ORIGINAL COMPLETION 05107194 LAST WORKOVER 04/17/19 RD/JMD CMTTBG&b 0381119 04/17/19 JMD+ TOC TAG (04/16/19) 05/15/19 JNUJMD CORRECTED TAGGED TOC 10(31/19 BTMJMD TBG PUNCH (1027/19) WELL NAME: 04 -OSA 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 2700'- 2705' Punch Tubing 1808' 161 Bbls Class'G' 1312'- 1322' Perforate Tubing & Casing 1000' 130 Bbls Class'G' 500' - 510' Perforate Tubing & Casing Surface 125 Bbls Class'G' Surface -1 Gal AS I ***JOB STARTED ON 24-OCTOBER-2019*** (SLB ELINE TBG PUNCH) PUNCH TUBING AT 2,700'- 2,705' ELMD WITH MEDIUM CHARGES, 4 SPF, 21 SHOTS, 0 DEG PHASED. VERIFIED TxIA COMMUNICATION. 10/24/2019 ***JOB COMPLETE ON 24-OCTOBER-2019*** ***JOB STARTED ON 27-OCTOBER-2019*** (SLB ELINE TUBING PUNCH) PUNCH TUBING FROM 2700' TO 2705'. PUNCHER LOADED WITH LARGE CHARGES, 21 SHOTS, 4 SPF, 0 DEG PHASED. 500 PSI LOST IN TUBING AFTER PUNCHING. VERIFIED GOOD TXIA COMMUNICATION WITH TRIPLEX. 10/27/2019 ***JOB COMPLETE ON 28-OCTOBER-2019*** SLB Cementing - IA Surface Cement Plug (PLUG AND ABANDONMENT) Attempt to establish circulation by pumping 60/40 down TBG through TBG punch holes at 2700' with IA returns to OTT. Pressure up to 2286 psi in 0.8 bbls with immediate stabilization and no returns at tank. Bleed down pressure and reattempt to gain circulation without success by pressuring up to 2515 psi. Establish circulation down IA with TBG returns. Reattempt to establish circulation down TBG with IA returns, pressured up to 2480 psi. Unable to pump into TBG punches. Live GI-Vs allowing flow from IA to TBG. RDMO to allow E-Line to MIRU and Repunch TBG. 10/27/2019 FWHPS = 41/3/161 ***JOB INCOMPLETE*** SLB Cementing - IA Surface Cement Plug (PLUG AND ABANDONMENT) Pump the following down TBG with IA Returns to OTT: 5 BBLS 60/40 spear to establish circulation, 5 BBLS FW spacer, 161 BBLS 15.8 PPG Class G CMT, 2 BBLS FW flush, drop 1 x 7" wiper ball, 40.5 BBLS 9.8 PPG, 3.9 BBLS 60/40 Surface FP. FWHPS = 659/5/182 TOC: TBG @ 2000' MD/TVD, IA Surface 10/28/2019 BOC: TBG x IA @ 2705' MD/TVD T/1/0=0/00/5 Temp=Sl MIT-T (P&A) MIT-T PASSED to 2679 psi, Max Applied Pressure=2750 Target Pressure=2500 psi. Pressured TBG to 2711 psi with .6 bbls 60/40. MIT-T lost 21 psi in 1 st 15 minutes and 11 psi in 2nd 15 minutes for a total of 32 psi during 30 minute test. Bled TBG to 0 psi. 11/2/2019 Valve Positions=SV's, closed WV and CV's OTG FWHP=0/0/5 ***JOB STARTED ON 3-NOVEMBER-2019*** (SLB ELINE PERFORATING 2.5 INCH GUN) BEGIN RIG UP 11/3/2019 WIND SPEEDS >30 MPH UNABLE TO RIG UP CRANE ***JOB CONTINUED ON 4-NOVEMBER-2019 ***(SLB ELINE TAG TOC AND TUBING PUNCH) TAG TOC AT 1808' ELM. PUNCH THROUGH TUBING/IA @ 1312'- 1322' W/2.5" POWERJET HMX, 6 SPF, 60 11/4/2019 DEG PHASING, CCL STOP DEPTH=1308.75', CCL TO TOPSHOT=3.25', T/1/0/00=0/1/226 Temp=S/I (LRS Unit 46 - Circ-Out OA Pre Cement Pumped the following Down TBG taking returns up the OA to OTT(.Remaining volume pumped on folloing day.) 50 bbls of 180* Diesel 30 bbls of 160* 9.8 Brine 11/7/2019 *** WSR continued on 11/08/19*** SLB fullbore pumping crew Objective: Cement TBG to — 1000" and OA to surface. MI/RU/PT SLB pumpers. 11/8/2019 **Cont. on 11/09/19 WSR** Daily Report of Well Operations PBU 04-05A *** WSR continued from 11/07/19 *** (LRS Unit 46 - Circ -Out OA Pre Cement) Continue to pump the following down TBG up the OA taking returns to OTT. 58 bbis of 130* HOT Surfactant Wash 130 bbls of 160* 9.8 ppg NaCl brine T/OA shell test to 1000 psi with 8 bbls 9.8 brine. Pressured T/OA.to 400/350 psi pressure fell off in - 3 minutes to 6/16 psi. (Tank returns show a loss of - 28 bbls) . Freeze protected Hardline with 3 bbls 60/40. Establish TxOA LLR of -1.3 bpm @ 500 psi using 24 bbls 9.8 brine. WSL Discusses with Town on loading out additional cement Freeze Protect Surface Lines w/ 2 bbls DSL. DSO notified of well status per LRS departure. 11/8/2019 FWHP's=0/0/0 **Cont. from 11/08/19 WSR** Pumped down TBG taking returns from the OA: 8 bbls 60/40, 5 bbls FW spacer, 130 bbls 15.8 ppg Class G cement, 2 bbls FW spacer. Launched 1x7" foam wiper ball and spotted cement w/ 16 bbls 9.8 NaCl and 5 bbls 60/40 (to FP surface lines and TBG to - 100'). Arctic Pack returns after 81 bbls cement away, cement cleaned up after 114 bbls away. 15.8 ppg Class G Cement in TBG and OA Est TOC in TBG = 1 000'MD TOC in OA = surface 11/9/2019 EST BOC in Tx OA = 1312' MD ***WELL S/I ON ARRIVAL*** (Plug & Abandonment) INITIAL T/1/0=0/0/250/0. MIRU & PT. PUNCH 500'- 510'W/ 2-7/8" POWERJET PUMP DOWN TBG W/ TRIPLEX AND ABLE TO SEE PRESSURE RESPONSE ON OOA (see log for details). FINAL T/1/0/00 = 0/0/150/10. 11/13/2019 ***JOB COMPLETE ON 13-NOV-2019*** T/1/0= 29/11/152/17. Temp= S/I (Circ out Artic pack and Hydrocabons from OOA). Pumped 30 bbls 160* DSL down TBG w/returns up OOA, followed by 12 bbls 160* 9.8 brine. Let hot DSL soak in OOA. Pumped 31 bbls 160* freshwater/surfactant, down TBG w/returns up OOA, followed by 150 bbls 160* 9.8 brine. Pumped 14 bbls 60/40 meth down TBG for U tube FP TBG X OOA. Pumped 2 bbls 60/40 meth to FP surface lines. FWHP's - 11/20/2019 10/18/251/-11. Well shut in upon departure SLB Cementing Services Job Scope: T x OOA cement P&A from 500' to surface. RU SLB cement pump on TBG and pumped the following. 5 bbls FW spacer, 125 bbls of neat 15.8 ppg Class G cement taking returns from OOA. Good cement at surface in OOA. Block in casing valve at OOA & Swab valves. Wash up surface lines. RDMOL **Job Complete** 15.8 ppg Class G Cement in TBG and OOA TOC in TBG/OOA = Surface 11/23/2019 *** Permanent P&A. *** Excavate around wellhead to 12.6'. 30" conductor casing full of gravel. Removed 7" of gravel and topped with AS -1 cement. Pad elevation 287, tundra elevation 22.1'. Wellhead cut = 3.4' below tundra grade. AOGCC witness of TOC and marker plate install is Guy Cook. 12/14/2019 *** JOB COMPLETE*** sp . olt id rN MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg `e1 1z'ib'�ri DATE: 12/14/19 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector PBU 04-05A - BPXA PTD 1931860; Sundry 319-446 12/11/19: 1 arrived on site and met with Rob Liddelow with BPXA. We discussed the job and I witnessed good cured cement to the surface of the conductor. I also confirmed the depth of the final casing cut to be 3 feet 4 inches below tundra. I then left location, to return later the same day to witness the identification plate installation. I witnessed the ID plate install and confirmed the plate was fully welded onto the conductor. 12/13/19: While preparing this inspection report, I noticed from the marker plate photo that the PTD # on the plate was incorrect, missing a "1" (i.e., 193860). 1 contacted John Arend, Rob Liddelow's alternate with BPXA, and informed him the PTD on the identification plate was incorrect and needed to be corrected. He informed me it would take at least a couple of days to get through the permitting process to be able to uncover the plate and fix the problem. I asked him to let us know when they had fixed the problem so we can confirm the change. 12/14/19: 1 arrived on site and met with Jon Arend with BPXA. The identification plate had been uncovered and the welder began to change the incorrect PTD (193860) that was currently on the plate to the correct PTD (1931860). Once the welder had completed the correction, I witnessed the correct PTD on the plate and left location. Attachments: Photos (4) 2019-1214_Surface_Abandon_PBU_ 04-05A gc.docx Pagel of 3 59 M 1 w/� L r � , } �, 1 � '� , • :r ( �� � `) � \ A �� Y)' I ' L• r 1 '' �.G :, ,..� . J 1 . I ,� . , r n s� / : ' •11� ���� �� � / � �� ..1, j % ` t ��4 �' t ' � � e ,'� F � i�. �� �� �, -t, i�q'���� � .. +. � r ° � , �, �a.: '..Si' .� � Sok �� _ 6 � ��,� THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Aras Worthington Interventions and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 04-05A Permit to Drill Number: 193-186 Sundry Number: 319-446 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.276.7542 www.00gcc.alasko.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, Lie . Chmielowski Commissioner DATED this q day of October, 2019. RBDMS LAPAINT 0 7 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend [I Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program,❑ Plug for Rednll ❑ 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. 193-186 3. Address: P.O. Box 196612 Anchorage, AK 9951 M612 Stretigrephic ❑ Service ❑ 8. API Number: 50-029-20107-01-00 7, If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 04 -OSA r 9. Property Designation (Lease Number): 10. Field/Pools:ADL 028325 PRUDHOE BAY. PRUDHOE OIL r 11. PRESENT WELL CONDITION SUMMARY Total Depth MD 00: Total Depth TVD(e): Effective Depth MD: Effective Depth TVD: MPSP (psi). Plugs (MD): 7062, Junk (MD): 10294 8944 7062 6346 9604,9935,10049 Casing Length Size MD TVD Buret Collapse Structural Conductor 80 30" 25-105 25-105 880 Surface 937 20" 24-961 24-961 1530 520 Intermediate 2678 13-3/8" 22-2700 22 - 2700 5380 2670 Intermediate 8236 9-5/8" 18-8254 18-7297 815016820/7510/887019410 508013330/4130/47607!330 Liner 2246 7" 1 8048-10294 7124-8944 1 8160 1 7020 Perforation Depth M (R): Perforation Depth ND (ft): Tubing Size: Tubing Grade Tubing MD (R): None 5-1/2"17#x4-1/7'12.6# 13Cr80 16 - 9617 / 10043 -10058 Packers and SSSV Type: 4-1/2" Baker SABL-3 Packer Packers and SSSV MD (ft) and TVD (ft): 9538/8265 4-1/2" Baker FB -1 Packer 1 OQ4318711 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: October 15, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑. Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 ' 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Area J be deviated from without prior written approval. Contact Email: Aras.Worthington(Mbp.wm Authorized Name: Worthington, Area J Contact Phone: +1 907 564 4102 Authorized Title: Interventiops & Integrity Engineer Authorized Signature: Date: F COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3 Plug Integnly ❑ BOP Test ❑ / `Mechanical Integrity Test Q/ Location Clearance Other: Ar Cool at, '1` Jry 1 agp.Scrr b� d 0/0 a 424 Post Initial Injection MIT Req'd? Yes ❑ No ❑✓ RBDMS_''0CT U 7 20 '7 L7 Spacing Exception Required? Yes ❑ No 11(Subsequent Form Required: �+S/Q� APPROVED BYTHE Approved by:1 /�. COMMISSIONER COMMISSION Date: to y / C �S)-c'oi� GRIGINAL iii PO��'"�Attachm Submit Fomn and Duplicate Form 10-403 Revised 0412017 Approved application is valid for 12 months from the date of approval. nye a� BiIG'y�ii 04-05 P&A Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Meredyth Richards (907) 564-4867 Expected Start Date October 15`" 2019 History 04-05A was completed with Gen 1 wellhead and three string casing design in 1977. The outer casing string is set in permafrost. GWO has determined that these wells are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. Objective Place cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. This P&A was designed to conform to BP Practice 100221: Zonal Isolation and BP Alaska's deviations captured in eMOC 10439. Procedural steps Slickline/E-line/Relay 1. MU 5' tubing punch and punch from 2700'— 2705' MD. (This step may be moved to E -Line or Relay if E -fire is not available). Fullbore 1. Pump cement job down tubing with returns from IA. The top of cement in the IA will be at surface and at 2000' MD in the tubing. Keep track of brine returns from the IA. Maximum tubing pressure 2500 psi. ➢ 5 bbls MEOH ➢ 5 bbis FW spacer ➢ 155 bbls of Class G cement per design (20 bbls excess) ➢ 2 bbls FW spacer ➢ Foam wiper ball ➢ 44 bbls 9.8 ppg brine *Adjust this volume per the below table if cement returns are not seen out of IA Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours Fullbore 1. MITT to 2500 psi target pressure. Max pressure 2750 psi. Slickline or EL 1. Tag TOC 2. Perforate @ -1300' MD through 5-1/2" tubing and 9-5/8" casing. • 10 ft gun, 2.5" Millenium II HMX, 60deg phasing, 6 spf, random orientation. Fullbore 1. RU to pump down the tbg and take returns from the OA. Maximum tubing pressure 2500 psi. ➢ 50 bbls hot (160F) diesel ➢ 30 bbls hot (160F) 9.8 ppg brine ➢ SD for one hour to let diesel soak in OA and loosen Arctic Pack ➢ 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 130 bbls hot (160F) 9.8 ppg brine 2. Once clean brine is consistently returned from the OA indicating that all hydrocarbons have been circulated out of the annuli, pump OA surface cement plug as follows down Tubing. The TOC in the OA will be at surface and at -1000' MD in the tubing. Maximum tubing pressure 2500 psi. ➢ 5 bbls MEOH ➢ 5 bbls freshwater spacer ➢ 100 bbls 15.8 ppg cement per design (17 bbls excess) ➢ 2 bbls FW ➢ Foam wiper ball ➢ 21 bbls 9.8 ppg brine Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 4 hours Slickline or E -Line 1. Perforate @ -500' MD through 5-1/2" tubing, 9-5/8" casing, and 13-3/8" casing. • 10 ft gun, 2.75" Millenium II HMX, 60deg phasing, 6 spf, random orientation. Fullbore 1. RU to pump down the tbg and take returns from the OOA. Maximum tubing pressure 2500 psi. ➢ 30 bbls hot (160F) diesel ➢ 12 bbls hot (160F) 9.8 ppg brine ➢ SD for one hour to let diesel soak in OA and loosen Arctic Pack ➢ 30 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 125 bbls hot (160F) 9.8 ppg brine 2. Once clean brine is consistently returned from theindicating that all hydrocarbons have been circulated out of the annuli, pump OOA and Tubing cement plug as follows down Tubing. Top of cement will be at surface in both the OOA and the Tubing. Maximum tubing pressure 2500 psi. ➢ 5 bbls MEOH ➢ 5 bbls freshwater spacer ➢ 125 bbls 15.8 ppg cement per design (22 bbls excess) Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. 20" 94# x Thickening Time: I Minimum 4 hours Volume Calculations: volume tnn mn hnt Mr) Ri7A Ir) hhls/ft Ft_ hbls 3 19.124" 20" 94# x x 20" x 13-3/8" annulus to Surface 500' 13-3/8" 13.375" 0.182 500' 91 12.347" 13-3/8" 72# x 13-3/8" x 9-5/8" Surface 1300' x 9-5/8" 9.625" 0.0581 1300' 76 8.681" 9-5/8" x 5-1/2" annulus Surface 2700' 9-5/8" 47# x 5-1/2" 0.0438 2700' 118 8.681" 9-5/8" x 4-1/2" annulus 3092' 3900' 9-5/8" 47# x 4-1/2" 0.0535 808' 43 8.835" 9-5/8" x 4-1/2" annulus 3900' 5150' 9-5/8" 40# x 4-1/2" 0.0561 1250' 70 8.755" 9-5/8" x 4-1/2" annulus 5150' 6850' 9-5/8" 43.5# x 4-1/2" 0.0548 1700' 93 8.681" 9-5/8" x 4-1/2" annulus 6850' 8048' 9-5/8" 47# x 4-1/2" 0.0535 1198' 64 6.184" 7" x 4-1/2" annulus 8048' 9538' 7" 29# x 4-1/2" 0.017 1490' 25 5-1/2" tubin Surface 3092' 5-1/2" 17# 4.892" 0.0232 3092' 72 4-1/2" tubing3092' 9604' 4-1/2" 12.6# 3.958" 0.0152 6512' 99 3 5-1/2" tubin Surface 1300' 5-1/2" 17# 4.892" 0.0232 1300' 30 Special Projects 1. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job the 30" x 20" annulus and all other annuli and tubing with cement as needed. Photo -document per AOGCC, 2. AOGCC witness cement tops in all annuli. 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows and photo - document: BP Exploration Alaska, Inc. 04-05A PTD # 193-186 API # 50-029-20107-01 TREE= DRY HOLE WELLHEAD MCEVOYI ACTUATOR REMOVED bid ELEV = 64' W ELEV = 53.26' BF. R_EV = 35.0' KOP= Max Angle = 3396' 47" @ 8987' Datum MD= 10199' Datum TVD --88W SS 94#, 14401 133#, K-55 D= 19.124 13-378' CSG, 729, N-80 . D =12.347" 5-12' TBG, 17#, 13CR-80 NSCC, { .0232 bpi, D = 4.892' Minimum ID = 3.813'@9517' 4412" OTIS X NIPPLE 9-518" 4-12' TBG, 12.60, 13CR-80 .0152 bpf, D = 3.958' TBG 1 9617' 1 4-172' TBG, 12.6#, 13CR-90 FOX, 10056' .0152 bpf, D = 3.958• PERFORATION SUMMARY REF LOG: BHCS 05/03194 ANGLE AT TOP PERF: 23' @ 9760' Nota: % far to Pmduclion DB forbistodcal perfdata S¢E SPF WMRVAL N 2 SHOT SOZ 3-318" 6 9760-9770 C 01/09/76 RK 2-79" 6 9842-9852 C 06148/16 42 3-318" 1 9960-9964 S 10/14194 7 726/94 3-3/8" 4 9976-9980 S OBID9/94 112601 3-318" 1 10022 - 10025 S 10/1494 1726194 2-718" 6 10110 -10150 C '11/18M7 6 2-718" 418 10150-10176 C 0BM9194 w 7• LNR, 290, 13CR-80 .0371 bpf, D = 6.184' CAM � 9092' �— j 5-12•x4-trz• xG, o = s.9on- I GAS LFT MANDRELS STI ND I Ab I DEV ITYPEI VLV I LATCH PORTTDYATE 1 3323 3320 9 1 9616' 1 HEX RUG, 17- X 4-1/2• BKR F-1 ISOLATION RCR D= 4.00- 1 4-12" OTIB X NP, D = 3.81• 10053' -i4-12" OTIS XN NP, D = 3.725 10055' 4-117 WLEG, D=2.492" 1 OO5T ELND TT —LO—GG-ED-0-5-117-/9-4 1 10294' 1 DATE REV BY I COMMENTS DATE I REV BY COMMENTB 1977 ORIWAL COMPLETION 04/17/19 RD/JMD CMTTBG 8 b (03/31/19) LM DONE RK 16 11101!13 2 5295 5050 41 MNG SO RK 20 11/01/13 3 6668 6054 42 IMG OMY RK 0 10/31/13 4 7220 6467 40 mm DAM w 0 11118/94 s 7727 6863 37 IMG DAM RK 0 0723108 6 8019 7101 34 MAG OM1' w 0 02123/19 7062'-9525' TBG 6N CEMENTTAGGED 04/16/19 MLLOUT WNDOW (04-05A) 8254' - _' 9517' 4-12'OTMX MP,ID=3.81' (CEMENTED 03/!1119) 9638' 7"X4-172" BKR SABL-3 PKR �BO� 4-12"OT6X NP.D=3.81" 1 9616' 1 HEX RUG, 17- X 4-1/2• BKR F-1 ISOLATION RCR D= 4.00- 1 4-12" OTIB X NP, D = 3.81• 10053' -i4-12" OTIS XN NP, D = 3.725 10055' 4-117 WLEG, D=2.492" 1 OO5T ELND TT —LO—GG-ED-0-5-117-/9-4 1 10294' 1 DATE REV BY I COMMENTS DATE I REV BY COMMENTB 1977 ORIWAL COMPLETION 04/17/19 RD/JMD CMTTBG 8 b (03/31/19) 05107194 LAST WORKOVER 04/17/19 JMD+ TOCTAG 04/16/19 0121/19 JNL4JMD ADDED REF 8 BF ELEV 05/15119 JNUJMD CORRECTED TAGGED TOC 04/16M9 0225119 CJN/JMD GLV C/O 223/19 03/07/19 KP/JMD DRYHOLETREE 03025119 MH/JMO TBG PUNCH 321/19 PBTD PRUDHOE BAYUNIT WELL: 04-05A PERMIT No: 51931860 API No: 50-02920107-01 SEC 34,T11N R15E,742'FNL5420 BP Exploration (Alaska) ODND. DS 5 P&A Status Fourth Cement Plug: TBG: Surface to 500' MD OOA: Surface to 500' MD 13-3/8' CSG. 72#, N-80 _, D -I Y.347- 271' 5-112' TBG, 170, 13CR-80 NSCC, —C .0232 bpf, D = 4.892' Mininwm ID = 3.813' @ 9517' 4-1l2" OTIS X NIPPLE TOPOF 7• LNR —F 801 19-5/8' CSG, 47#, "OTS -95, D = 8.681' 1--1 8264' F 4-12' TBG, 12.6#, 13CR-80 .0152 bpf, D = 3.958' TOPOF4-112'TBGH 10043' 1 412' TBG, 12.6#, 13CR-80 0152 bpi, D = 3.958' PERFORATION SID."RY REF LOG: Ell C 05/03/94 ANGLE AT TOP PERF: 23' @ 9760 Note- Refer to Roduction OB for historical pert data SIZE SPIFJ INTERVAL Opn/Sgz SHOT I SOZ 3-3/8' 6 9760-9770 O 01/09/16 0621116 MRDJKC SET HEX R.L1G(AOFERFS (06/18116) 2-7/8' 6 9842-9852 O 06118/16 06/01/15 3-318' 1 9960-9964 S 10114/94 1126194 33/8' 4 9976-9980 S 08109/94 11l 33/8' 1 10022 - 10025 S 10/14/94 111 2-718' 6 10110 - 10150 C 11/18/9 2-7/8' 4/8 10150 - 10176 C M09194 7 7- LW 29#, 13CR-90 , .0371 bpf, D = 6.184' 7 NOTES: LNR/COLLAR LEAK @ 10120"" SPOT Q 3300--3800.... CHROME TBG 8 Third Cement Plug: TBG: 1000' MD to 1300' MD OA: Surface to 1300' MD Second Cement Plug: TBG: 2000' MD to 2700' MD IA: Surface to 2700' MD First Cement Plug: TBG: 7062' MD to 9604' MD IA: 7500' to 9538' MD { 9638• H r X 4112' BKR SABL-3 RCR 9604' 412' OTB % FTP, D = 3.81' 9604' 4-1/2' XX RW (04/30H7) 9616' 412' WLEG, D = 3.958' 9935 NM 1E 363-700 ifX PLUG, 4-12- FN (DB/18/16) 10043' T X 4-1/2' BKR F-1 ISOLATION PKR D= 4.D0' 100{9' 4-12' OTB X NP, D = 3.61- 10049' 4-1/2' XX PLLIG(1127/09) 10063' 4-12.OTB XN NP, D = 3.725' 10058' 4-1/7 WLEG, D=2.992' 1005T ELKO TT LOGGED 05/17/94 MTD 10263' DATE REV BY COUVE4TS DATE REV BY COMMB4TS 1977 ORIGTNALCtOMPLEnON 11118/15 GTW)Jkt RAL-® PX FLLIG it vill15) 05107194 LAST WORKOVER 01112116 C&JMD ADFERFS (01/09/16) 0210M02 RWTP CORRECTIONS 0621116 MRDJKC SET HEX R.L1G(AOFERFS (06/18116) 0223115 PJC SET XX PLLIG(PRE TREE CIO) 05101/17 RCB/ SETXX R.UG(04130117) 06/01/15 PJC TBG CORRECTIONS 0725/17 R.HAV ADDED 30' CAPD 8 20' CSG wo 08/13115 DLMAO TREE aO(08101115) P(31DHOE BAY LM WELL 04 -OSA REFUT No: 1931860 AR Np: 50-029-20107-01 T11N, R15E, 747 FNL 8 420' FEL SP Exploration (Alaska) Aro i93-/86 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Thursday, June 20, 2019 7:23 PM To: Hayes, James C Subject: Re: Current 1 F-12(193-186, Sundry 319-277) RWO James, The 200' applies to injectors and a variance is required. Since this is a change to an approved program, approval is required. Approval is granted to move the packer to 6259' MD. Thanx, Victoria Sent from my iPhone On Jun 20, 2019, at 6:16 PM, Hayes, lames C <lames.C.Haves@conocophillips.com> wrote: Victoria, We currently found holes in our 7" casing on this well at 5,670' MD and would like to stack a packer above the holes to isolate them from the tubing string. This well is a producer and you will see that in my original sundry request I was going to place the packer at 6,239' MD / 5,742' TVD. This was greater than 200' above the lower perf's and I requested you to allow it but due to this being a producer it wasn't necessary. However now that we have found our leaks in casing we will be moving the packer up to 5,690' MD / 5,271' TVD. This is 471' TVD above the original permit request. Again because this is a producer I believe I don't need approval but I want to run this by you just in case. Do you have any issues with this? Thanks, James Hayes COP - Alaska RWO Engineer C: +1918.914.9609 O: +1907.265.6927 <1F-12 WV Schematic.pdf> <1F-12 APPROVED 10-403 Pull Tubing, Repair Well Sundry Application.pdf> Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Thursday, June 20, 2019 7:23 PM To: Hayes, James C Subject: Re: Current 1 F-12 RWO James, The 200' applies to injectors and a variance is required. Since this is a change to an approved program, approval is required. Approval is granted to move the packer to 6259' MD. Thanx, Victoria Sent from my iPhone On Jun 20, 2019, at 6:16 PM, Hayes, James C <James.C.Hayes@conocophillips.com> wrote: Victoria, We currently found holes in our 7" casing on this well at 5,670' MD and would like to stack a packer above the holes to isolate them from the tubing string. This well is a producer and you will see that in my original sundry request I was going to place the packer at 6,239' MD / 5,742' TVD. This was greater than 200' above the lower perf's and I requested you to allow it but due to this being a producer it wasn't necessary. However now that we have found our leaks in casing we will be moving the packer up to 5,690' MD / 5,271' TVD. This is 471' TVD above the original permit request. Again because this is a producer I believe I don't need approval but I want to run this by you just in case. Do you have any issues with this? Thanks, James Hayes COP - Alaska RWO Engineer C: +1918.914.9609 0: +1907.265.6927 <1F-12 WV Schematic.pdf> <1F-12 APPROVED 10-403 Pull Tubing, Repair Well Sundry Appiication.pdf> IJ -10 Proposed CTD Schematic r91 Si Hid shoe ®120' MD 9518^Ma L40 shoe � 8915' MD 7^ 281 LA0Shoe G 10231' MD KOP 10,283' MD KOP®10,30t'MD afar par 10850'-106]8' MD 1Y 12.w 1,90 ahoa Q 10,843' MD 3-1/ Camw 085 nipple ® 508' MD (3.875"min ID) �t2-t2.6/ IBT EUE Ertl Tubing to sonata a1z 4110- Carrico DB landing nipple C 9933' MD (mdbtl 3.8T min ID) Baker 4=2 GBH -22 L ci for Baker SSY aeaemby ®9980' MD (3.958" ID) Baker PYierar Sleeve BkerUlnerTop Packer 9905'MD (093810) Baker User Hanger Camco (Nipple ®10,328 MD handed 3.87" ID) FISH ®-10.a0B MD: Ped Gun OBSX Nipple a 10,521' MD (.&d 3.725" ID) -- uwpwnewiY ll/)'93I t<O MdSr) ).)/9'Ablar Y3/f ONY STATE OF ALASKA 9_,S K C E I w E ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 44 AV ; r _ 1. Operations Performed- 16 - 9542 110043 - 10058 16 - 8269 / 8711 - 8725 " 'J 9538 Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program -_p❑ measured Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Secure Reservoir 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work true vertical 5. Permit to Dni Number: 193-186 feet 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ Effective Depth: measured 7062 AK 99519{612 Stratigraphic ❑ Service 1 6. API Number: 50-029-20107-01-00 7. Property Designation (Lease Number): ADL 028325 e. Well Name and Number: PBU 04-05A Packer 9. Logs (List logs and submit electronic and panted data per 20AAC25.071): 10. Field/Pools: Casing: Length: Size: MD. TVD: PRUDHOE BAY, PRUDHOE OIL Burst: Collapse. 11. Present Well Condition Summary: 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 16 - 9542 110043 - 10058 16 - 8269 / 8711 - 8725 Packers and SSSV (type, measured and 4-1/2" Baker SABL-3 Packer 9538 8266 true vertiwl depth) a12" Baker FB -1 Packer 7082, 9604 8711 Total Depth: measured 10294 feet Plugs measured 9935, 10049 feet true vertical 8944 feet Junk measured None feet Effective Depth: measured 7062 fast Packer measured 9538, 10043 feet true vertical 6346 feet Packer true vertical 8266.8711 feet Casing: Length: Size: MD. TVD: Burst: Collapse. Structural Conductor 80 30" 25-105 25-105 880 Surface 937 20" 24-961 24-961 1530 520 Intermediate 2678 13-3/8" 22-2700 22-2700 5380 2670 Intermediate 8226 9-5/8" 18-8254 18-7297 8150168200510/6870/9410 5060x3330/4130/4760/7380 Liner 2246 7" 8048-10294 7124-8944 8160 7020 Perforation Depth: Measured depth: 9760-10176 feet True vertical depth: 8455-8834 feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 16 - 9542 110043 - 10058 16 - 8269 / 8711 - 8725 Packers and SSSV (type, measured and 4-1/2" Baker SABL-3 Packer 9538 8266 true vertiwl depth) a12" Baker FB -1 Packer 10043 8711 12. Stimulation or cement squeeze summary: Intervals treated (measured): descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcr Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: Shut -In 14.Attachments:(.,a,.d=r2onac25.070.25.071.s25283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 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: 319-023 Authorized Name: Worthington, Aras J Contact Name: Worthington, Area J Authorized Title: Interveptions 8 Integrity Engineer Contact Email: Ares.WorthingtonObp.com Authorized Signature: /_�fl Date: f/l-r10Z0) A Contact Phone: +1 907 564 4102 Form 10-404 Revised 04/2017 ��011^ y ,�,�r�,q�t� MMSH MAY 16 2019 Submit Original Only T/1/0/00 = 280/280/220/0. Temp = SI. TBG & IA FL level secure). No well house or flow line. Temporary scaffold installed. T FL @ 9226'(165 bbis), IA FL @ 5400'(259 bbls). 1/31/2019 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 20:00. T/1/0/00 = LOTO/280/220/0. Temp = SI. No wellhouse or flowline. Temporary scaffolding installed. IAP, OAP, OOAP unchanged since 1/31/19. 2/3/2019 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 23:00 T/l/O/00 = LOTO280/220/0. Temp = SI. Injrectivity test (Pre P & A). No AL, flowline or wellhouse. Temporary scaffolding is installed. Pumped - 2.5 gallons of hydraulic oil down each of the control and balance lines. 2/12/2019 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 0945 T/1/0/00 = LOTO/280/220/0. Temp = SI. Job Objective: Cement Control & Balance line with SqueezeCrete ultra fine cement. Injected 2.3 gallons of SqueezeCrete cement down Balance line and 2.3 gallons down the Control line Wait 48 hours before pressure testing. No red line 2/18/2019 required. ***Job Complete*** T/I/O/00 = LOTO/3001220/0. Temp = SI. PT C&B lines (Pre P&A). No AL, flowline or wellhouse. Temporary scaffolding installed around well. Control line PT PASSED to 3127 psi. Balance line PT PASSED to 2843 psi. 2/21/2019 SV, WV = LOTO. SSV = C. MV = O. IA, OA, OOA = OTG. 11:50 ****CONT WSR FROM 2-21-19***(reg comp) SET 4-1/2" BAIT SUB, 3.50" LIB ON XX-PLUG @ 9604' MD. PULL RK-DGLV FROM STA6 (8019' MD) PULL 4-1/2" BAIT SUB, 3.50" LIB FROM 4-1/2" XX-PLUG FROM 9604' MD (impression of 4- 1/2" G-FN) LRS CIRC OUT T X IA W/ 620 BBLS 9.8 ppg BRINE (see LRS log for details) PERFORM PASSING STATE WITNESSED CMIT T x IA STATE WITNESSED TAG 4-1/2" XX-PLUG @ 9604' MD. SET 4-1/2" WHIDDON CATCHER @ 9604 MD. 2/22/2019 ****CONT WSR ON 2-23-19**** T/1/0= 330/224/ Assist SLine w/ Circ Out and CMIT (P&A) Pumped 5 bbls 60/40 followed by 50 bbls FW+F103+UO67 followed by 634 bbls 9.8 brine, followed by 7 bbls 60/40 down TBG taking returns up IA to well 04-51 FL. U-Tube TBG & IA for 45 minutes to FP. Pumped 3.2 bbls 60/40 meth down Tbg for AOGCC CMIT-TxIA to 2473 psi PASS. Took Tbg/IA to 2514/2518 psi. Tbg/IA lost 28/27 psi in 1st 15 mins and 13/12 psi in 2nd 15 imns for a total loss of 41/39 psi in 30 min test. Bled Tbg/IA to 800 psi and got back -3.1 bbls. 2/22/2019 SLine in control of well per LRS departure. FWHP's=800/811/240 IA,OA=OTG ****CONT WSR FROM 2-22-19****(reg comp) SET RK-DGLV IN STA #6 (8019' MD) PULL EMPTY 4-1/2" WHIDDON CATCHER SUB FROM 9604' MD 2/23/2019 ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED**** T/110=110/160/230. Temp = SI. WHPs (WIE Req). No Flowline, AL or Well house. Temp scaffolding installed around tree. 2/26/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:00 T/1/0=200/200/200 R/D production tree, R/U Dryhole tree Temp. #09. Torqued to specs, 2/27/2019 PT'd... ass. see "Field Charted Tests" FWP"s 200/200/200 see log for details. T/l/O = 140/120/230. Temp = SI. T & IA FL (WIE request). Dryhole tree installed. Wellhouse removed. Temporary scaffold installed. T FL @ near surface. IA FL @ 310'(14 bbls). TP increased 30 psi, IAP decreased 40 psi, OAP unchanged from 2/26/19. 3/2/2019 SV = C. MV = O. IA, OA = OTG. 22:00 Daily Report of Well Operations 04-05A TWO = 140/150/230. Temp = SI. T & IA FL (WIE request). Dryhole tree installed. Wellhouse removed. Temporary scaffold installed. T FL @ 74' (2 bbls). IA FL @ 430'(19 bbls). IA FL depressed 120', IAP increased 30 psi from 3/2/19. 3/7/2019 SV = C. MV = O. IA, OA = OTG. 13:50. T/1/0/00 = 140/100/230/3. Temp = SI. TBG / IA FL (WIE Req.). Dryhole tree installed. No AL, flowline, or wellhouse. Tbg FL @ near surface. IA FL @ 440' (19 bbls). TP unchanged, IAP decreased 50 psi, OAP unchanged since 03/07/19. 3/10/2019 SV = C. MV = O. IA, OA, OOA = OTG. 09:00 T/I/O/00 = 160/100/230/0+. Temp = SI. TBG / IA FL (WIE Req.). Dryhole tree installed. No AL, flowline, or wellhouse. Tbg FL @ near surface. IA FL @ 450' (20 bbls). The TP increased 20 psi, IAP, OAP & OOAP remained unchanged since 3-10-19. 3/17/2019 SV = C. MV = 0. IA, OA, OCA = OTG. 15:00 ***WELL S/I ON ARRIVAL***(P&A) TAGGED PLUG WITH 3.5" LIB AT 9611' SLM - T= 9604' MD. 3/20/2019 ***CONT ON 3-21-19 WSR*** ***CONT FROM 3-20-19 WSR***(P&A) PUNCHED TBG WITH SLB E -FIRE FROM 9525' TO 9530' MD. 3/21/2019 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** T/I/O/00 = 30/120/230/0+. Temp = SI. TBG / IA FL (WIE Req.). Dryhole tree installed. No AL, flowline, or wellhouse. Tbg FL @ near surface. IA FL @ 320' (20 bbls). IA FL rose 130'. TP decreased 130 psi, IAP increased 20 psi, OAP & OOAP remained unchanged since 3-17-19. 3/23/2019 SV, MV = C. IA, OA, OOA = OTG. 22:00 T/I/O = NAM 10/230. Temp = SI. IA FL (pre P&A). Dryhole tree & P -sub w/ loaded ball installed. IA FL @ 440' (20 bbls). 3/29/2019 SV, MV = C. IA, OA = OTG. 15:30 **SLB Fullbore Pumping Crew** Job Scope: Plug and Abandommnet w/balanced cement plug (TBGxIA). LRS pumped 5 bbls 60/40 spear down the TBG taking returns from the IA to tanks. SLB pumped down the TBG taking returns from the IA to tanks: 5 bbls fresh water bbls 15.8 ppg class G cement, 2 bbls FW spacer. Launched 2x7" foam wiper balls. L displace cement down the TBG and into the IA w/133 bbls 9.8 ppg NaCL and 11 bbls 60/40. U -tubed 60/40 to FP TxlAto -150'. FWHP's=644/687/20 15.8 ppg Class G cement in TxIA Est. TOC in TBG and IA = 7500' MD/6682' TVD Est BOC in TBG and IA= 9525' MD/8255'TVD 3/31/2019 ** Job complete** T/1/0/00 = SV/110/230/2. Temp = SI. TBG & IA FL (WIE request). No wellhouse, AL, or flowline. Dryhole tree with P -sub installed, loaded with wiper balls for cement job. Unable to acquire TBG FL. IA FL @ 440' (20 bbls). 3/31/2019 SV, MV = C. IA, OA, OOA = OTG. 03:00 T/I/OA/OOA=25/107/216/vac Temp=Sl (LRS Unit 70 -Assist Schlumberger Cement Van) Pump the following down the tubing, up the IA, to open top tanks 5 bbls of 60/40 SLB pump cement recipe 133 bbls of 90* 9.8 ppg brine 11 bbls of 60/40 to freeze protect surface lines Swab master valves shut Casing valves open to gauges 3/31/2019 1 Final Whp's=644/687/240 Daily Report of Well Operations 04-05A T/I/O/00 = 20/70/200/0+. TBG & IA FLs (WIE Req). No wellhouse or flowline. TBG FL @ near surface. IA FL @ near surface. 4/6/2019 SV, MV = C. IA, OA, OOA = OTG. 13:15 T/1/0/00 = 10/70/220/01. Temp = SI. TBG & IA FLs (WIE request). No wellhouse or flowline. TBG FL @ near surface, IA FL @ near surface. 4/15/2019 SV, MV = C. IA, OA, ODA = OTG. 04:30 T/1/0/00=5/65/235/5 (LRS 42, Assist SL w/ AOGCC state witnessed) CMIT-TxIA PASSED Per State AOGCC to 2627/2610 psi ***PASSED Per State AOGCC***, Max Applied Pressure=2750 Target Pressure=2500 psi. Pressured T/IA to 2717/2725 psi with 3.8 bbls DSL. CMIT-TxIA lost 22124 psi in is---minutes and 20/22 psi in 2nd 15 minutes for a total of 42/46 psi during 30 minute test. Bled TBG to 20/23/236 psi. Bleed back 4 bbls DSL. ***WSR continued on 04/17/2019*** 4/16/2019 ***WELL S/I ON ARRIVAL***(plug and abandonment) DRIFT W/ 3.00" CENT, 2-1/2" SAMPLE BAILER TO TOC @ 7,062' SLM LRS PERFORMED STATE WITNESSED CMIT-TxIA 4/16/2019 ***WELL S/1, LRS IN CONTROL OF WELL UPON DEPARTURE*** ***WSR Continued from 04-16-2019*"* CMIT-TxIA ***PASSED*** to 2610/2575 psi, Max Applied Pressure=2750 Target Pressure=2500 psi. Pressured T/IA to 2705/2713 psi with 3.8 bbls DSL. CMIT-TxIA lost 14/20 psi in 1st 15 minutes and 12/18 psi in 2nd 15 minutes for a total of 26/38 psi during 30 minute test. Bled TBG/IA to 25/25 psi. Bleed back 4 bbls DSL. Notify WSL. Hang tags on SV/IA Valve Positions= Both SV's Closed CV's IA,OA, OOA OTG FWHP=25/25/235 4/17/2019 CRY HOLE 30' -C-0—ND, #, WELLHEAD MCEVOY ACTUATOR REMOVED OKB. R_EV : 64' REF ELEV = 532V BF. AEV = WA' KOP= 3396' Max Angle = 47.4 8987' Datum MD= 10199' Datum TVD: 8800'SS 94#, H-40/ 1330, K-55 D = 19.124' 9' CSG, 729, W80 _, D = 12.347'2711' 5-12' TBG, 17#, 13CR-80 NSCC, 3092- .0232 bpf, D = 4.892' Minimum 113= 3.813'@9517- 4-112m .813'@9517'4-112" OTIS X NIPPLE 9-58' 3,12-6#, 13CR-M I 9617 - ID = 3.958' TOPOF4-1/2'TBG 10043' 4-12' TBG, 12.6#, 13CR-80 FOX, 10056• .0152 bpf, D = 3.958' PERFORATION SUMMARY REF LOG: BHCS 0510394 ANGLE AT TOP PERF: 23• @ 9760' Note: Refer ID Production DB forhistaricai perfdata SI2E JSPFJ INTERVAL OprWSqz I SHOT SOZ 338' 6 9760-9770 C 01/09/16 2-7/8' 6 9&42-9852 C 06/18/16 33/8' 1 9960-9964 S 10/1494 1126194 3-3/8' 4 9976-9980 S 08/09194 112694 3-38' 1 10022 -10025 S 10/14194 112694 2-78' 6 10110 -10150 C 11/1697 2-78' 49 10150-10176 C 08/09/94 7- 04-05A 2084' N5-12' CAM BAL-O SS O 3082' 5-12' X 4-12' XO, D CAS LFT MANDRELS D = 6.184• ST bD TVD DEV TYPE VLV LATCH PORT LATE 1 3323 3320 9 MMG DOME RK 16 11/01/13 2 5295 5050 41 MMG SO Po( 20 11/01/13 3 6668 6054 42 MG OW RK 0 10131/13 4 7220 6467 40 MMG DMY RK 0 11/18/94 5 7727 6863 37 MMG OM1' RK 0 07/23/08 6 8019 7101 34 MMG DMY R( 0 0223119 7062'-9525' TBG& IA CEMENT TAGGED 04 FALLOUT WINDOW (04-06A) 8254' - 8517' 442' OTIS X NIP, ID = 3.81' (CEMENTED 03131/19) F -9 -6—w --]—F7 X 4-12' BKR SABL-3 PKR 9935' MERWELL 363-700 HEX PLUG, 4-12' FN (06/18/16) 10043' 7•X4-12' BKR F-1 ISOLATION PKR, D= 4.00' 10j 053• I-14-12.0T1SXN NP, D = 3.725 10058' 4-t2• WLEG. D=2.992• 10057' ELMD TT LOGGED 05/17/94 DATE REV BY COMMENTS DATE REV BY COMMENTS 1977 ORIGINAL COMPLETION 04/17/18 JRD/JMQ CMTTBG&IA 03/31/19 068784 LAST WORKOVER 04/17/19 JMD+ TOCTAG 04116/19 0121119 JNL/JMD ADDED REF & BF ELEV 05/15/19 JMJJMD CORRECTED TAGGED TOC 04/16/19 02/25/19 CJWJFD GLV C/O 223119 03/07/19 KP/JMD DRYHOLETREE 0325/19 MWJMD TBG PUNCH 3121/19 m PRUDHOE BAY UNIT WELL: 04 -OSA PERMIT No: 1931860 API No: 50-029-20107-01 I, T11 N. R15E, 742' FNL & 420' BP Exploration (Alaska) MEMORANDUM TO: Jim Regg ZZl t`I P.I. Supervisor / FROM: Brian Bixby Petroleum Inspector Section: 34 1Township: Drilling Rig: N/A Rig Elevation: Operator Rep: Lee Grey Casing/Tubing Data (depths are MD): Conductor: 30" O.D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 13 3/8" O.D. Shoe@ Production: 9 5/8" O.D. Shoe@ Liner: 7" O.D. Shoe@ Tubing: 5 1/2" x 4 1/2" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 16th 2019 SUBJECT: Well Bore Plug & Abandonment PBU 04-05A - BP Exploration Alaska PTD 1931860; Sundry 319-023 11N Range: 15E Meridian: Umiat N/A Total Depth: 10294 ft MD ' Lease No.: ADL 28325 ' Suspend: P&A: XXX 105 Feet 961 Feet 2700 Feet 8254 Feet 10294 Feet 9617 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth to MW Above Ventieo Fullbore Bridge plug " 7062 ft MD ' 9.8 Brine Wireline tag 2632 P OA 236 239 239 239 Inifial 15 min 30 min 45 min Result Tubing 2717 2692 - 2669 2647 IA 2725 2683" 2656 2632 P OA 236 239 239 239 Initial 15 min 30 min 45 min Kesult Tubing IA OA Remarks: I witnessed the top -of -cement tag with slickline at 7062 ft MD (slickline measurement). Good hard cement. I then witnessed the tubing and IA jumperd together with the pump truck for the comboination MIT TxIA and it looked like a good passing test to me. Attachments: rev. 11-28-18 2019-0416_Plug_Verification_PBU_04-05A_bb MEMORANDUM TO: Jim Regg 0 3 J P.I. Supervisor '\ � /am/ I y FROM: Lou Laubenstein Petroleum Inspector Section: 34 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Robert Bryan Casing/Tubing Data (depths are MD): Conductor: 30" O.D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 13 3/8" - O.D. Shoe@ Production: 9 5/8" - O.D. Shoe@ Liner: 7" O.D. Shoe@ Tubing: 5 1/2" x 4 1/2" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 22, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 04-05A BP Exploration PTD 193-186; Sundry # 319-023 11N Range: 15E Meridian: Umiat NA Total Depth: 10294 ft MD Lease No.: ADL0028325 Suspend: P&A: X 105 Feet 961 Feet 2700 Feet 8254 Feet 10294 Feet 9617 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing Bridge plug - 9604 ft MD Wireline tag 2479 P OA 242 241 242 Initial 15 min 30 min 45 min Result Tubing 2514 2486 1 2473 IA 2518 _ 2491 - 2479 P OA 242 241 242 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I witnessed a sucessful tag and pressure test of the XX bridge plug, a gas lift was removed to perform a combo MIT of the tubing and casing. Attachments: none rev. 11-28-18 2019-0222_Plug_Verification_PBU_04-05A_II THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Aras J Worthington Interventions & Integrity Engineer BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 04-05A Permit to Drill Number: 193-186 Sundry Number: 319-023 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.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, Daniel T. eamount, Jr. Commissioner DATED this day of January, 2019. RBDMSMMAN 3 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 RECEIVED JAN 2 2 2019 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shuutdd�o/w'�n 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ChangFgl}1WGIbp/diOrO Plug for Rednll ❑ 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: 193.186 • 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6 API Number: 50-029.20107-01-00 r T If perforating: e. 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 04-05A 9. Property Designation (Lease Number): 10. Fieltl/Pools: ADL 028325 + PRUDHOE BAY, PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10294 8944 9604 8320 9604,9935,10049 None Casing Length Slze MD TVD Buret Collapse Structural Conductor 80 30" 25-105 25-105 880 Surface 937 20" 24-961 24-961 1530 520 Intermediate 2678 13-3/8" 22-2700 22-205380 2670 Intermediate 8226 9-5/8" 18-6254 18-7297 8150/6820/r51058]0/941 50B0/3330r4130/476W330 Liner 2246 7" 8048- 10294 7124-8944 8160 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size. Tubing Grade: Tubing MD (ft): 9760- 1 - 8834 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 16 - 9542 /10043 -10058 Packers and SSSV Type: 4-1/2" Baker SABL-3 Packer Packers and SSSV MD (ft) and ND (ft): 9538/8266 4-1/2" Baker FB4 Packer 1 OD43 / 8711 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: January 31, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Aras J be deviated from without prior written approval. Contact Email: Aras.Worthington@bp.cem Authorized Name: Worthington, Area J Contact Phone: +1 907 564 4102 Authonzed Title: Interventions & Integrity Engineer Authorized Signature: A �/v Date: J� f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: U L✓� Plug Integrity ❑1n'BOP Test ❑ Mechanics Integrity Test G� Location Clearance R Other: "1O CX ®C (J W% -'E W+ OL -s I YN �, r G(Li'eof Post Initial Injection MIT Req'd? Yes ❑ No ❑ter Spacing Exception Required? Yes ❑ No L'7 Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: a v Form 10-403 Revised 04/2017 ORIGINAL RBDMSA11'JAN 3 12019 P14-fe'KIR Submit Form and Approved application is valid for 12 months from the date of approval. ` �Achments in Duplicate 04-05 P&A Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Meredyth Richards (907) 564-4867 Expected start date: January 25'" 2019 History 04-05A was completed with Gen 1 wellhead and three string casing design in 1977. The outer casing string is set in permafrost. GWO has determined that these wells are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. Objective Place cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. Procedural steps Special Projects 1. Injectivity test into Control and Balance lines. 2. Cement Control and Balance lines with squeezecrete or finecem. Slickline/Fullbore 3. Pull bottom DGLV @ 8019' MD. 4. Circulate down tubing and up IA with surfactant wash followed by 9.8 ppg brine. ➢ 5 bbls MEOH 50 bbls hot (160 deg) freshwater + surfactant; ➢ 620 bbls 9.8 ppg brine 2 �S p 5. AOGCC Witnessed CMIT TxIA to 150. 'i. 6. AOGCC Witnessed tag top of XX plug @ 9604' MD. 7. Set DGLV @ 8019' MD. 2 gal/mgal F103 and 2 gal/mgal UO67 36 PK� Flag wire for depth control. 8. MU 5' tubing punch and punch from 9525' — 9530' MD. (This step may be moved to E -Line if E -fire is not available). Fullbore 1. Pump cement job down tubing with returns from at —2200' MD in the tubing. ➢ 5 bbls MEOH v 5 bbls FW spacer 570 bbls of Class G cement ➢ Foam wiper ball 2 bbls FW spacer 49 bbls 9.8 ppg brine IA. The�J p of cement in he IA will be at surface and 91 per design (20 bbls excess) Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab pp +/- 0.1 ppg Pressure Slurry Temperature: between 800 and 110°F 0 Fluid Loss: 40-200cc (20-100cc/30 min) 3000 Compressive Strength: 2000 psi in 48 hrs. 2500 Thickening Time: Minimum 5 hours 2000 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1.00 130 3000 2:00 120 2500 3:00 110 2000 400 100 1500 7:00 80 1000 15:00 40 0 E-Line/Fullbore 1. MITT to 2500 psi 2. Tag TOC 3. Perforate @ —1800' MD through 5-1/2" tubing and 9-5/8" casing. Fullbore 1. RU to pump down the tbg and take returns from the OA. Pump the following: ➢ 50 bbls hot (160F) diesel 42 bbls hot (160F) 9.8 ppg brine ➢ SD for one hour to let diesel soak in OA and loosen Arctic Pack 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 150 bbls hot (160F) 9.8 ppg brine Once clean brine is consistently returned from the OA indicating that all hydrocarbons have been circulated out of the annuli, pump OA surface cement plug as follows down Tubing. The TOC in the OA will be at surface and at —1000' MD in the tubing. ➢ 5 bbls MEOH ➢ 5 bbls freshwater spacer ➢ 135 bbis 15.8 ppg cement per design (11 bbls excess) ➢ Foam wiper ball ➢ 2 bbls FW ➢ 21 bbls 9.8 ppg brine Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Pressure Slurry Temperature: between 80° and 110°F 0 Fluid Loss: 40-200cc (20-100cc/30 min) 1000 Compressive Strength: 2000 psi in 48 hrs. 0 Thickening Time: Minimum 4 hours 0 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 70 1000 2:00 60 0 3:00 50 0 4:00 40 0 7:00 40 0 15:00 30 0 E -Line 1. Perforate @ —600' MD through 5-1/2" tubing, 9-5/8" casing, and 13-3/8" casing. Fullbore 1. RU to pump down the tbg and take returns from the OOA. Pump the following: ➢ 50 bbls hot (160F) diesel ➢ 14 bbls hot (160F) 9.8 ppg brine ➢ SD for one hour to let diesel soak in OA and loosen Arctic Pack ➢ 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 125 bbls hot (160F) 9.8 ppg brine 2. Once clean brine is consistently returned from the OA indicating that all hydrocarbons have been circulated out of the annuli, pump OOA and Tubing cement plug as follows down Tubing. Top of cement will be at surface in both the OOA and the Tubing. ➢ 5 bbls MEOH ➢ 5 bbls freshwater spacer ➢ 130 bbls 15.8 ppg cement per design (7 bbls excess) Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: I Minimum 4 hours Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 70 500 2:00 60 0 3:00 50 0 4:00 40 0 7:00 40 0 15:00 30 0 Volume Calculations: volume top MD bot MD Size ID bbls/ft. Ft. bbls Special Projects t�e�`Y a dl©C u we en �A o�),�S �cs� 1. Excavate and Cutoff all casings and wellhead 3' below original tundra level. Top job the 30" x 20" annulus and all other annuli and tubing with cement as needed. 2. AOGCC witness cement tops in all annuli 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows: BP Exploration Alaska, Inc. 04-05A PTD # 193-186 API # 50-029-20107-01 19.124" 20" 94# x x 20" x 13-3/8" annulus to Surface 600' 13-3/8" 13.375" 0.182 600' 109 12.347" 13-3/8" 72# x 13-3/8" x 9-5/8" Surface 1800' x 9-5/8" 9.625" 0.0581 1800' 105 8.681" 9-5/8" x 5-1/2" annulus Surface 3092' 9-5/8" 47# x 5-1/2" 0.0438 3092' 136 8.681" 9-5/8" x 4-1/2" annulus 3092' 3900' 9-5/8" 47# x 4-1/2" 0.0535 808' 43 8.835- 9-5/8" x 4-1/2" annulus 3900' 5150' 9-5/8" 40# x 4-1/2" 0.0561 1250' 70 8.755" 9-5/8" x 4-1/2" annulus 5150' 6850' 9-5/8" 43.5# x 4-1/2" 0.0548 1700' 93 8.681" 9-5/8" x 4-1/2" annulus 6850' 8048' 9-5/8" 47# x 4-1/2" 0.0535 1198' 64 6.184" 7" x 4-1/2" annulus 8048' 9538' 7" 29# x 4-1/2" 0.017 1490' 25 5-1/2" tubin Surface 3092' 5-1/2" 17# 4.892" 0.0232 3092' 72 4-1/2" tubin 3092' 9604' 4-1/2" 12.6# 3.958" 0.0152 6512' 99 5-1/2" tubing Surface 1800' 5-1/2" 17# 4.892" 0.0232 1800' 42 Special Projects t�e�`Y a dl©C u we en �A o�),�S �cs� 1. Excavate and Cutoff all casings and wellhead 3' below original tundra level. Top job the 30" x 20" annulus and all other annuli and tubing with cement as needed. 2. AOGCC witness cement tops in all annuli 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows: BP Exploration Alaska, Inc. 04-05A PTD # 193-186 API # 50-029-20107-01 TREE = CREF 6-3/8' CIW FLS 30. 141TiLFEAD MCE1/0Y 6e 64' REF EFE11= ACMTOR BAKER 35.0' #,J . - . s4 L713, 55 D = 19.124' 13-3/8' CSG, 72#, N-80 _, D = 12-347- 5-1/2" TBG, 17#, 13CR-80 NSCC, { .0232 bpf, D = 4.892" Minimum ID = 3.813'@ 9517' 4-112" OTIS X NIPPLE 4-1/2' TBG, 12.6#, 13CR-80 .0152 bpf, D = 3.958- 1 9617' 1 4-1/2" TBG, 12.6#, 13CR-80 FOX, 10058' .0152 bpf, D = 3.958' PERFORATION SLATMRY REF LOG: BRCS 05103/94 ANGLEAT TOP FEE: 23' @ 9760' OKE. aE1/ - 6e 64' REF EFE11= 53.28' BF. EFB7 = 35.0' KOP=3396' 6 Max Angle =_ 47" -6 8987' Dahnn MD= 10199' Dah1mTVD: 8800'SS s4 L713, 55 D = 19.124' 13-3/8' CSG, 72#, N-80 _, D = 12-347- 5-1/2" TBG, 17#, 13CR-80 NSCC, { .0232 bpf, D = 4.892" Minimum ID = 3.813'@ 9517' 4-112" OTIS X NIPPLE 4-1/2' TBG, 12.6#, 13CR-80 .0152 bpf, D = 3.958- 1 9617' 1 4-1/2" TBG, 12.6#, 13CR-80 FOX, 10058' .0152 bpf, D = 3.958' PERFORATION SLATMRY REF LOG: BRCS 05103/94 ANGLEAT TOP FEE: 23' @ 9760' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 3-3/8" 6 9760-9770 O 01/09/16 11101/13 2-7/8" 6 9842-9852 O 06118116 RK 3-3/8" 1 9960-9964 S 10/14/94 1/26/94 3-3/8" 4 9976-9980 S 08109/94 1/26194 3-38" 1 10022-10025 S 10/14/94 F11/26/94 2-7/8' 6 10110-10150 C 11/1819 RK 2-7/8' 4/8 10150- 10176 C 08/09/94 Mu1G 04-05A SAFETY NOTES: LNR/COLLAR LEAK @ 10120'*** TIGHT SPOT @ 3300'-3800'--- CHROME TBG & LNR"` r E i-1/2' X 4-1/2" XO, D = 3.958' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3323 3320 9 MMG DOBE RK 16 11101/13 2 5295 5050 41 Mo1G SO RK 20 11/01/13 3 6668 6054 42 MMG OMY RK 0 10131/13 4 7220 6467 40 MM1G DMY RK 0 11/18194 5 7727 6863 37 MdG DM/ RK 0 07/23/06 6 8019 7101 34 Mu1G [PAY RK 0 10/31/13 MLLOUT WINDOW (04- 4-1/2- OTE 04-4-1/2.OTE X NP In=3 Al XX PLUG 363-700 HEX PLUG, I L 10053' -�4-1/2' OTS XN NP, D= 3.725 10058' 4-1/2' WLEG, 0=2.992' 10057' ELM) TT LOGGED 05/17/94 7' LNR, 29#, 13CR-80 10294' 0371 bpf, D = 6.184' DATE REV BY COAMIBNTS DATE REI/ BY COMMENTS 1977 ORGINAL COMPLETION 11/18115 TWJ RILL®PX PLLIG(I1/11/15) 05/07194 LAST WORKOVER 01/12/16 CJS/JM] ADR3RFS(01/09116) 02104/02 RWTP CORRECTIONS 06/21/16 MRDVJMC SEr FIX PLUG/ADP6iFS(06/1 all 6) 02/23/15 PJC SEr XX PLUG (PRE TREE GO) 05/01/17 RCB/JSEr XX PLUG (04/30/17) 06/01/15 PJC TBG CORRECTIONS 07/25/17 RJWJMJ ADDED 30" COhD & 20" CSG INFO 08/13115 DWJMD TREE CJ0(08101/15) 01/21/19 JNJJM)ADDED REF &BF ELEV FRUDHOE BAY IMF WE -L: 04-05A PEFW No:'1931860 AR No: 50-029-20107-01 34, T11 N, R1 5E, 742' FNL & 420' FEL BP Bcpkuation (Alaska) TREE= Third Cement Plug: TBG: Surface to 600' MD OOA: Surface to 600' MD 13-38• CSG, 729. N-80 _, D - 12.347• 5-12' TBG, 179, 13CR-80 NSCC, .0232 bpf, D = 4.892' NOTES: LNR/COLLAR LEM @ 10120'•' DS O4-05 P&A Status PHT SPOT @ 3300'-3800"'• CHROME TBG & Drilling (original) Cement: 9-5/8" Casing: est. 10,124' MD - 8170' MD & 2402' MD — 3017' MD 4-12• TBG, 12.60, 13CR-80 .0152 bpf, D = 3.958- 4-112' TBG, 12.69, 13CR-80 FOX, 10058' .0152 bpf, D = 3.958' PEF FORATDN SUMI AR.Y REF LOG: BNS 0583194 ANGLE AT TOP R3*. 23' @ 9760 Note' Infer to Roductto0 OB for historical pert data SIZE SFFI INTERVAL OpnlSgz SHOT SOZ 3-318' 6 9760 - 9770 0 01109116 w2vitimmific SLT HIX PLUG/ADFEws (06116/16) 2-78' 6 9842 -9852 O 06118116 PJC 3-318' 1 9960-9964 S 1011494 '11126194 3.38' 4 9976-9980 S 088994 11 3-318' 1 10022-10025 S 1011494 Ili 2-7/8• 6 10110-10150 C 1111619 2-78' 4/8 10150 - 10176 C 0&0994 7' LNR, 290, 13CR-80 .0371 bpf. D = 6.184' Second Cement Plug: TBG: 1000' MD to 1800' MD OA: Surface to 1800' MD GAS LFT M4NORELS 2 5295 1 5050 41 MoC' SO RK 20 11811 3 6668 6054 42 MMG OkOI RX 0 10131) First Cement Plug: TBG: 2200' MD to 9604' MD IA: Surface to 9538' MD 9604• H4-12•OTSX NP, D=3.811 9604• 4-12• XX PLUG (04/3017) 14-1/2' OTS X NP, D= 3.81' 1 1006T ELMD TT LOGO 05/17/94 DATE REV BY OOMENTS DATE REV BY COMMMS 1877 ORGINIL COMPLETION 11/18115 G-TW/JK KILLED FX FLt1G (11111115) OSM7194 LAST Y1RORIMER 01112116 CJS(JAD ADPEWS(01f09/16) 0284102 RNTP CORRECTIONS w2vitimmific SLT HIX PLUG/ADFEws (06116/16) 0223/15 PJC SET XX PLt1G (PRE TREE CIO) 0581117 RCB/JSET XX PLt1G (04!30/17) OWI/15 PJC TBG CORRISM10INS 0725117 RJKAU ADDED 30' CORD & 2D' CSG INFO 08/13115 DUJMD 7REEaO(08101115) PR D DE BAY LINT WELL: 04-05A PEFW No: 1931860 API W: 50-02920107-01 So 8cploration (Alaska) !G?S. ave 0• bb) z z ioz5 v � t h 7 � h i .a V -7179 el �so�•+p au -i 1� orb rJa.yo l e- c9.v,,.a� TO to '37 /T/ -In Zs 9r7 Zari 7,'Z`/rj ioZs r �r TcC zyz� 2171/ 3 -%a /2, 347 _Z L sy xY'k cr 3417 ' 9sg)Z- l3�'rZb� Zlzy k9-s�g i gaq I v �btijl5 It 177 O ,y6C�i kx p) 41016, 943 S 11-29`7_ 10137' 12-1-71 1.0137' 12-2-71 10137' Uurvc-y: 10137' 24-3/40 N35W, 1�. HI w/sonic logftto 101341. LolggingRI (23- 27-11-15) 0002 - NORTH SLOPE 10137'TD Ran sonic, SNP PBD _ Running gyro SOr029_20107 (9-5/8" (7 F ppl; I; s �' 7-'L-3. Co ey - D7W @ 10124 ) sx classy ?„ f P1a!:0 @ n hole for csg, Ran9-5/8'r -5 /Nr is 57. 11-28- 0 w/0.3q HR -7 U 0 0< f DV @ 3017, @-5/8 csg shoe II' close Opened DV @ 30171. C plug w/1500 si 392' Cemented 1@ 10ta e ' float d DV OY,, CIP 4:08 Circ out & cemented 2ndt held. CIP @ 2:0p to/800 from 2nd stage, p 11_28_ AN sx Fermafrost aped 375 bbl Black M, Opened DV @ 23 21 w/25p sx Permafrost 30b. Flan rc Out, 8-3/8 "Ibitl Dr.a Dedp$ CIP @ 835 AD4lllu28_Cemented13rd stage cement 7'. Tested to 2500 DV F-23-52 yl, LD DC ge w/100 mud 1.7 bactericide psi 2c R1 to baffle sled to 2500 psi p' jars & blunper POH. 10002 K, Drilled DV @ 101-2, �5) - A'ORTH SLOPE h1' started running gyro survey. out Treated 7 -11 - TD oon An 1 Ran3gyro surveyPBD from 9997, to pull 950-029-201075/8 F`19-5/8° @ 10124') Bowen cutter to 20 • Ran CBL 9990- , 11.11{ ,juin, csg c,/1500 O 9000 _ Vis 56. a7nulus, RU Psi' pressure 9e 5/8 es in.l hr3 3100-220o, Psi' RD Schl. 5 cut LDDP to pull csg- 4ualized @ 200 psi w/9-/cuttar' Pressu,''ed (2-3-27-11-15) 23-2 - 5/8 3-3/8 7 11-15) _ NORTH _ t2210r lU lOOOti'PLDe- DDPFr LD 56 its 93-20107 (9 @ 10124') /dieselPressure t ( csg to 1500 5/8 oil. Had psi OIi, W/OEDPTop Of 9-5/8" @ good clean diesel @surface, stub (�3-27- LDDP,2500' circ out mud T 11-15) _ NORTH SLOPE 10-10 .15) 100021PBD - W/DP @ -API 50-02 to surf 9-20107 (9-5/8" @ 101241) REPORT. `Ce LDDi'. AID BOPE, _Inst displaced e/). bbl -1 Installed xHas tree, diesel, Clean RR 8:00 PAI 12- oi.l bac?; 1-71. FINAL r The Abo,v e is Correct: SIGNATt111H ` f..'•DISi'FiICT DT17 1RVISURuAr Nu.s.n. "I.S1'011Y r(11M•S UAI,1. DAILY L[I, Eli �1 )N5FfUr1VI:I,Y AS -"`--'-- T'IIt;Y AHI? PIiBFAHl9) FUq F'4r'f WPIL. ) r 0.000�000 �5"": I It OF 00 E •ALASKA OIL AND GASTCONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS JUL, . 19 2015 1. Operations Performed Abandon 0 Plug Perforations EZI Fracture Stimulate 0 Pull Tubing 0 O/ 4, g :. 0 Suspend 0 Perforate a Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other: H-C1 p 1 / 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 193-186 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory El AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20107-01-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 04-05A 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 10294 feet Plugs measured 9935/10049 feet true vertical 8942 feet Junk measured feet Effective Depth: measured 9935 feet Packer measured 9535 feet true vertical 8611 feet Packer true vertical 8261.57 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 942 20"94#H-40 23-964 23-964 1530 520 Surface 2678 13-3/8"72#N-80 20-2698 20-2698 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9760-9770 feet feet 9842-9852 feet 9960-9964 feet 9976-9980 feet 10022-10025 feet 10110-10140 feet 10140-10150 feet 10150-10160 feet 10160-10171 feet 10171-10176 feet True vertical depth: 8454-8463 feet feet 8527-8536 feet 8634-8637 feet 8648-8652 feet 8690-8693 feet 8771 -8799 feet 8799-8808 feet 8808-8817 feet 8817-8827 feet 8827-8832 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCOW) N yE� `11131.1 2, !i, 13. Representative Daily Average Production or Injection Data I Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 625 52838 10730 1998 994 Subsequent to operation: Shut-In 150 0 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations a Exploratory ❑ Development I1 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 ❑ 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 If&I l A/ -' Phone +1 907 564 4424 Date 7/18/16 Form 10-404 Revised 5/2015 //� / RBDMS i' ' JUL 2 2 2016 Submit Original Only • • Q O 0 0 0 0 0 0 0 0 0 0 0 o o to N N- co o M M CO CO N N OT- CO O - CO O O M CO O Cn N Cn O N U) o M Tr Tr o CO N- I o CO r- 0 y O O O O O O O o O O O O O O �. M M up o N I- Cf) M CO M Tr Tr M Cf) C) - - CO In CO d) Tr N N Tr m .1 co CO CO I- CO CO 100 CO N- N- 00 o CO N- N 00 O) o UD C) — CO ti CA O) O N- CO O CA M N CO N O CO N CO O M M O N O) N- N O M N N N Tr CC) CO I- V- 00 00 M O0 I , 1 1 1 1 1 i i m m i H Cf) I"- N o CA CO M N- 00 M O o Tr C) O N- 00 O N O CO - CO N N T- N Cfl O M M O '— N- N O N N CC) CO N- N- C0 M C a CO CO I� Tr o N- CO - CA ID O) d' O CA Tr CA M M O CC)CV N y- o c- O COV N CO �t C CD 7 I.- I Co O O N c) CDCD .0t r O O M O 00 Tr cn M CCo l O V 1' CO c- Coo N CV T- N CO O N- T- CD O O N O CO N N NI' Cn N- N- CO O� M MD = c0 ul O O a CD co0 ) o dog) 0 O I O Co Tf 1- z0000z0Z " m" M `r c) U U = d = N fn Cn 09 4t (n g M *k M00 N 4t N. *k 4* 4t o r- CO T- 4# Cfl I� N- O M I� 00 NO) aoTfvv aoTr _ rnrQDT- T- UNM -C;0 _CCoo : CCC — - CVNN (V O) CA CA I O) 0) 4 o T. J= Tr CO N eq in M M 00 M N ,_ 0 CAD U W NN c- - - N MCO W W W W W W W F- F- F- HF- HH < < < < < < Q 0,0 0000000 WWWWWWW mD < 222222 000 Uo ,_ ococoCococoCoCocCezzz Z Et W W W W W W W W W QO m m O ZZZZzzz JJ _ E. H • • Packers and SSV's Attachment PBU 04-05A SW Name Type MD TVD Depscription 04-05A PACKER 8052.29 7128.67 7" Baker Type H Liner Top Packer 04-05A TBG PACKER 9534.97 8261.57 4-1/2" Baker SABL-3 Packer 04-05A PACKER 10040.24 8706.89 4-1/2" Baker F-1 Packer . • • < o w 0 c / < / , 7 E . Lu CC - a k w o o 0 0_ a & C -I D . I- E 5 x I z < LU I') / / w 0 0 E u e -1 _1 $ o m e 2 a o .-- - a 00 _ 5 F- ƒ & I- CO � LU < ƒ 2 w L0 w < § » C % 2 ƒ 2 d 000 0 co co 72 2 0 Z /0• o ƒ O \ / b § \ o � § „ q � \ aw2 x , ƒ 2 ® OQ / # Ua '' Nz = w 2I 72 � I w � TD9 / / ƒ �/ / Lu / R m - u- v o m = _1 m w w 01- 4- R 4- a 2 � I- � / T0 co 0I m O co / >- W / % 0 : < / cn1- O � 0- 2a " % < < � I / w CL : DOE©o2 / w 0 \ >. k / Z / u_ II ƒ / & / 66 � co ix / _ ky � 0 / / / � CeLU , » na9U � o w 0 2U- ••- j / D / k k % 0 a_ R _1 k c m = _I I a 2 / 22gd -� 2k � w2q w / w �� � \ wwcc & « = = L m / 2 / > / DI- D / � R a) : c : A $ : _ ca < : 5 Lu < Co CO CO G G 0) ® _2 _- CO 5OD \ + < TRE = 6-3/8"aW FLSIII -S NOTES: LNR/COLLAR LEAK 10120'""' IVVELLF AD MCEVOY Q —0 5A TIGHT SPOT @ 3300'-3800'***CHROME TBG& ACTUATOR BAXERC LNR*** B . = 64' I BF FEV EV= ? / KOP= 3396' "CONDUCTOR, — ? Max Angie= 47"©8987 _ 2094' —{5-112"CAM BAL-O SSSV NP,D=4.56" Datum MD= 10199' —#' - Datum TVD: 8800'SS 13-318"CSG,72#,N}-80_,D=12.347" H 2711' 3092' H5-112"X 4-112"XO,D=3.958" 5-1/2"TBG,17#,13CR-80 NSCC, H 3092' 1-- GAS LFT MANDRELS 7 ST MD ND CEV TYPE VLV LATCH FORT DATE .0232 bpf,D=4.892" 1 3323 3320 9 MMG DOME RK 16 11/01/13 Minimum ID = 3.725'@ 10053' I .I . 2 5295 5050 41 G SO FE 20 11/01/13 4-1/2" OTIS XN NIPPLE �y 3 WAG WAG DMY (SIC 0 10/31/13 4 7220 6467 40 MMG DMY RK 0 11/18/94 5 7727 6863 37 3 t DMY RK 0 07/23/08 TOP OF 7"LNR —{ 8048' 6 8019 7101 34 MAG DMY FE 0 10/31/13 9-5/8"CSG,47#,N-801S-95,D=8.681' H 8254' L MLLOUT WMVDOW(04-05A)8254' ' 9517' —4-1/2"OTIS X MPP,D=3.81" E X 9538' H7"X 4-1/2"BKR SABL-3 PKR ' 9504 —14-1/2"OTIS X NP,D=3.81' 4-1/2'TBG,12.6#,13CR-80 , H 9617' / \ 9616' H4-1/2"WLEG,13=3.958" .0152 bpf,D=3.958" 9935' —NTERWELL 363-700 HEX PLUG, 4-1/2"FN(06/18/16) I TOP OF 4-1/2"TBG —1 10043' 1---x S 10043' —{7"X 4-1/2"BKR F-1 ISOLATION PKR,D=4.00" ,B' 10049' —14-112'OTIS X NP,D=3.81' 10049' H4-1/2"XX PLUG(11/27/09) ' , 10053' H4-112"OTIS XN NW',D=3.725" 4-1/2'TBG,12.6#,13CR-80 FOX, H 10058' , ._—I 10058' H4-1/2"WLEG,D=2.997 .0152 bpf,D=3.958" 10057' —{ELMO TT LOGGED 05/17/94 PB2FORATION SUMMARY REF LOG:BHCS 05/03/94 ` A NGLE AT TOP PERF:23'@ 9760' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SO7 3-3/8" 6 9760-9770 0 01/09/16 2-7/8" 6 9842-9852 0 06/18/16 PBTD —{ 10253' 3-3/8" 1 9960-9964 S 10/14/94 11/26/94 i��t� 3-3/8" 4 9976-9980 S 08/09/94 x11/26/94 ist iss' 3-3/8" 1 10022-10025 S 10/14/94 11/26/94 inti e, 2-7/8" 6 10110-10150 C 11/18/97 7" �a�••�• LNR 29#,13CR 80 H 10294' i�!' 2-7/8" 4/8 10150-10176 C 08/09/94 .0371 bpf,ID=6.184" DATE REV BY COMENTS DATE REV BY COMMENTS PRUDHOE BAY UVT r 1977 ORIGINAL COMPLETION 11/18/15 GTW/JMC PULLED PX PLUG(11/11/15) WELL: 04-05A 05/07/94 LAST WORKOVBR 01/12/16 CJS/J1/11)ADPERFS(01/09/16) PBRMT No:x1931860 02/04/02 RN'TP COONS 06/21/16 MRLYJMD SET HEX PLUG/ADPBRFS(06/18/16) AR No: 50-029-20107-01 02/23/15 PJC SET XX PLUG(PRE TRIM C/O) SEC 34,T11 N,R15E,742 RC&420'Fa 06/01/15 PJC TBG CORRECTIONS 08/13/15 OLVJMD TREE C/O(08/01/15) BP Exploration(Alaska) STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMISIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ 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: 193-186 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20107-01-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 04-05A 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: 1i gEcE VEU Total Depth: measured 10294 feet Plugs !� Pmeasured 10049 feet true vertical 8942 feet Junk measured feet ,EB t 2 2.01`6 Effective Depth: measured 10049 feet Packer measured See Attachment feet true vertical 8715 feet Packer true vertical See Attachment feet Aorrt Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 942 20"94#H-40 23-964 23-964 1530 520 Surface 2678 13-3/8"72#N-80 20-2698 20-2698 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9760-9770 feet 9760-9770 feet 9960-9964 feet 9976-9980 feet 10022-10025 feet 10140-10150 10110-10140 feet 10140-10150 feet 10150-10160 feet 10160-10171 feet True vertical depth: 8454-8463 feet 8454-8463 feet 8634-8637 feet 8648-8652 feet 8690-8693 feet 8799-8808 8771-8799 feet 8799-8808 feet 8808-8817 feet 8817-8827 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): t Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 286 10893 1700 229 Subsequent to operation: 600 52741 9886 1617 1077 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 1 1ee./6c---- Phone +1 907 564 4424 Date 2/1/16 Form 10-404 Revised 5/2015 VI-1 Z` �/1 RBDMS u- FEB 0 4 2016 Submit Original Only LVL/` • • Packers and SSV's Attachment PBU 04-05A SW Name Type MD TVD Depscription 04-05A PACKER 8052.29 7128.67 7" Baker Type H Liner Top Packer 04-05A TBG PACKER 9534.97 8261.57 4-1/2" Baker SABL-3 Packer 04-05A TBG PACKER 10040.24 8706.89 4-1/2" Baker F-1 Packer • • 0. O O O 0 0 O 0 O O O O O O CC1 — N 0N- 230M Cl) CO OO O '8O — Co O CON O C() M Tr Tr Cn CO N- N- UI CO Is V 1y 0 0 0 0 0 0 0 0 0 0 0 0 0 i Cl) Cr) U) 5f) N ti lC) Cr) CD Cl) q Cl) CO O CA CO CC) Co ' 0) r- N N- Nr CIO CO CO N- CO CIO N- 00 00 N- N- OO O CO N- N OO O CO U) O T- O N O CA ct CA 0 N- OD O CA M N T- CO N 5CON000 01 01 CDNOIsNO01 N N N Tr O CO N- N- co 00 M OD 1 1 1 1 1 1 1 m m i i m i Cn N- N CIO CA 00 M N- Co Cl) O C70 Tr C7) O Ns CO O N O CO — C70 N N N O O M M O T- N O N N Tr O CO N- N CO C°) Awlc G) ,rODCON- TropN- CO OE CAV OCATrOMChT- OONOT— COT- O N N N cr C[ N- Ns OD O O N C01 OO) . C.) 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KOP= 3396', —"contouToR. —I ? ) I I 2094' —15-1/2'CAM BAL-O Ss-SV N13,El=4.56- Max Angle= ar it 8a87' ____#, Daturn M::,= 10199' ID- Datum TVD, 8800'SS = 13-3/6'CSG,72#,N-80 ,I3=12.347' H 2711' 3092 —15-1/2-X 4-1/2"XO,D 3.958' 5-1/2-TBG,17#,13CR-80 NSOC, —{ 30921— GAS LFT MAPDRELS / ST AC TVD CEV TY PE VLV LATCH FORT DATE .0232 bpi,I3=4.892" 1 3323 3320 9 MIAG DOLE RI< 16 11/01/13 Minimum ID = 3.725'@ 10053' L_ 2 5295 5050 41 WAG SO RK 20 11/01/13 3 6668 6054 42 PANG DMY RK 0 10/31/13 4-1/2" OTIS XN NIPPLE . 4 7220 6467 40 MG MY RK 0 11/18/94 5 7727 6863 37 14.0 CAW FE 0 07/23/08 TOP OF r LNR H 8048' 6 8019 7101 34 'MG DMI' FE 0 10/31/13 9-5/8'CSG,47#,N-80/5-95,0=8.681' H 8264' L. MLLOUT WINDOW(04-05A)8254'- ' I I 9617' .--14-1/2"OTIS X NP,13=3.81' E X 9638' Hr x 4-1/2-BKR SA BL-3 PKR I I 960C H4-1/2'ans x PIP,V=3.81" 4-1/2-TBG,12.84,13CR-80 . H 9617' / \ 9616. --I4-1/2"INLEG,0=3.958' .0152 bpf,ID=3.958' 0 II II I TOP OF 4-1/2'TBG H 10043' ] X X 11(K)439 Hr X 4-1/2-BKR F-1 ISOLATION R(R,1:' 4.00' II 10049' H4-1/2-OTS X NP,D=3.81' 10049' H4-1/2"XX PLUG(11/27/09) I I 10063' H4-112"OTIS XN MP,I)=3.725' 4-1/2'TBG, 12.6#,13CR-80 FOX, H 10058' , . 10068' H4-1/2"MEG,13=2.992' .0152 bet,0=3.958' 10067' —113_14t)TT LOGGED 05/17/94 PERFORATION SIM4ARY REF LOG:BHCS 05/03/94 41414k ANGLE AT TOP FE12F:23° E 9760' Note:Ftefer to Production CB for historical perf data SIZE SPF INTERVAL Opn/Sqz SI-OT SOZ 3-3/8" 6 • 9760-9770 0 01/09/16 Pl3TD H 10253' 3-3/8' 1 9960-9964 S 10/14/94'11/26/94 Ai*. AIWA.. 3-3/8" 4 9976-9980 S 08/09/94'11/26/94 ,s111001' Ailli*iir 3-3/8" 1 10022-10025 S 10/14/94"11/26194 ,OO tom oilliss" 2-7/8' 6 10110-10150 0 "11/18/97 T LAIR,29#,13CF1-80 10294' 2-7/8' 4/8 10150- 10176 0 08/09/94 .0371 bpf,0=6.184" DATE REV BY COMMENTS DATE REV BY C01.0•ENTS PRUDHOE BAY UNT r 1977 ORIGINAL COMPLETION 11/18/15 GIVV/JM FULLED PX RUG(11/11/15) WELL: 04-05A 05/07/94 'LAST WORKOVER 01/12/16 CJS/3114)ADFERFS(01/09/16) PERMIT Nb:'1931860 02/04/02 RNTP CORRECTIONS AR No: 50-029-20107-01 02/23/15 PJC SET XX PLUG(PRE TREE C/O) ' SEC 34,T11N,Ft15E,742'FM_&420'F8 06/01/15 PJC TBG CORRECTIONS 08/13/15 DLYJMD 111:E CIO(08/01/15) BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday,January 23, 2016 9:16 PM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OIL; AK, OPS FS2 Field OIL;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Pettus,Whitney; Sayers,Jessica; Dickerman, Eric;AK, D&C Valve Shop Coordinator Subject: OPERABLE: Producer 04-05A (PID# 1931860) Natural Flow Well Post Adperf All, Producer 04-05A(PTD# 1931860)was placed on production on January 21, 2016 post adperf and continued to flow unassisted after gas lift was removed. The well has been reclassified as Operable and may remain online as needed. Per BP internal standards,the well may utilize gas lift for kick off but may not rely on continuous artificial lift(A/L)for production due to the small production casing anomaly logged in the well. If the flow characteristics of the well are altered enough such that the well requires gas lift in order to flow continuously,the Operability status of the well is subject to reclassification. BP Base Management and Operations shall monitor for changes in flow characteristics to ensure that the well remains capable of flowing unassisted to surface. As soon as operationally feasible, the well shall be shut in to assist with the change out of the inner annulus (IA) casing valve. Plan Forward: 1. Operations: Shut in well 2. Downhole Diagnostics: Bleed IA to 0 psi 3. Operations: Drop A/L casing spool 4. Valve Shop: Replace IA casing valve 5. Operations: Place well on production, remove A/L once well has kicked off Please call with any questions and concerns. Thank you, SEED MAY 2 6 2096 Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator@BP.com 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, January 12, 2016 11:24 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OIL; AK, OPS FS2 Field OTL;AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; AK, RIES GPB East Wells Opt Engr;AK, OPS EOC Specialists; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Pettus, Whitney; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer Subject: UNDER EVALUATION: Producer 04-05A (PTD# 1931860) Ready to Place of Production All, Producer 04-05A (PTD# 1931860) added perforations on January 09, 2016 to increase overall production gas. The well logged a small production casing anomaly @ 3007' MD but subsequently passed both a MIT-T and CMIT-TxIA on October 19, 2015. Per BP internal standards,the well could not remain on production utilizing gas lift due to the aforementioned anomaly. The well is reclassified as Under Evaluation to determine if flow characters of the well were altered enough such that the well no longer requires lift gas for continued operations. Plan Forward: 1. Operations: Place well on production 2. Operations: Remove gas lift once well is thermally stable and kicked off 3. Downhole Diagnostics: Monitor pressures 4. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BPAlla}ska-Well Integrity Coordinator Irot COI WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, December 14, 2015 2:59 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC IL; AK, OPS PCC Ops Lead; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; AK, IR.ES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'Regg, James B (DOA)'; Pettus, Whitney; Sayers, Jessica; Dickerman, 1 • ` P&4 -o5--A i9lgc,o Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> E� iz `� 14 I , 14, 2 1 2:59 PM � Sent: Monday, December0 5 I To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS PCC EOC IL; AK, OPS PCC Ops Lead;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA); Pettus,Whitney; Sayers,Jessica; Dickerman, Eric Subject: NOT Operable: Producer 04-05A (PTD# 1931860)Well Unable to Flow Unassisted All, Producer 04-05A(PTD# 1931860)was unable to flow on its own once removed from gas lift service. The well has since been shut in and freeze protected. Per BP internal standards, the well cannot remain on gas lift due to the production casing leak @ 3007'. The well is reclassified as Not Operable and is to remain shut in until integrity can be restored or flow characteristics are altered such that the well no longer requires gas lift for operation. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED SEP 0 7 2016 (Alternate. h�evitt Parks) BP Alaska-Well Integrity Coordinator GA A . :, o! WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@JBP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, November 19, 2015 7:36 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'Regg, James B (DOA) (iim.regq©alaska.gov)' Subject: Operable: Producer 04-05A (PTD: 1931860) MIT-T and CMIT-TxIA Passed All, Producer 04-05A (PTD#1931860) passed a MIT-T and a CMIT T x IA on October 19, 2015. The passing tests confirm two competent barriers in the wellbore. The well is reclassified as Operable.The well can be brought on line with gas lift but after the well is online the gas lift will be shut in due to the possible leak in the production casing. If the well does not flow on its own well needs to be shut in and re-evaluated. 1 • • • Well status is Operable • Annuli are fluid packed • A SSSV is not required Thank you, Kevin Parks tt BP Alaska-Well Inte rity Coordinator rIt GllWens Oroanizator Office: 907.659.5102 WIC Email:AKDCWelllntegritvCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, February 26, 2015 7:27 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: Not Operable: Producer 04-05A (PTD: 1931860) Failed CMIT-TxIA All, Producer 04-05A(PTD# 1931860)failed a CMIT-TxIA on February 25, 2015 indicating a lack of competent barriers in the wellbore. The well has been secured with a plug set on February 22, 2015 and a passing MIT-T was performed on February 25, 2015. The well has been reclassified as Not Operable until down hole barriers can be restored. Please call with any questions. Thank you, Laurie Climer (Alternate. k<,‘III Park%) BP Alaska-Well Integrity Coordinator Grooal' v iI Oc r4awat nI WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinatorPBP.com 2 • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, November 19, 2015 7:36 AM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL;AK, OPS PCC EOC TL;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; Cismoski, Doug A;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA) Subject: Operable: Producer 04-05A (PTD: 1931860) MIT-T and CMIT-TxIA Passed All, Producer 04-05A (PTD#1931860) passed a MIT-T and a CMIT T x IA on October 19, 2015. The passing tests confirm two competent barriers in the wellbore. The well is reclassified as Operable. The well can be brought on line with gas lift but after the well is online the gas lift will be shut in due to the possible leak in the production casing. If the well does not flow on its own well needs to be shut in and re-evaluated. • Well status is Operable • Annuli are fluid packed • A SSSV is not required Thank you, Kevin Parks SCANNED MAY 1 1 2016 (Alternate. Whitney Petri+s% BP Alaska -Well Integrity Coordinator Global Wells GW IOrganizaiior Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com Froma-AK, D&C Well Integrity Coordinator Sent: Thursday, February 26, 2015 7:27 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: Not Operable: Producer 04-05A (PTD: 1 31860) Failed CMIT-TxIA All, Producer 04-05A(PTD# 1931860) failed a CMIT-TxIA on February 25, 201 icating a lack of competent barriers in the wellbore. The well has been secured with a plug set on February 22, 2015 and a passing MIT-T was performed on February 25, 2015. 1 • , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recK a.alaska.govi AOGCC.Inspectors(S alaska.aovi phoebe.brooks a alaska.gov chris.wallace(a�alaska.00v ` _r OPERATOR: BP Exploration(Alaska),Inc. r \`/�v{n FIELD/UNIT/PAD: Prudhoe/GPB/V DATE: 10/19/15 OPERATOR REP: Kevin Parksc.9.-......--.....-----4 AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-05A Type lnj. N TVD Tubing 369 2,515 2,438 2,404 Interval 0 P.T.D. 1931860 Type test P Test psi Casing 412 424 426 426 P/F P Notes: BP Internal MIT-T OA 2 2 2 2 Well 04-05A Type In]. N TVD Tubing 452 2,500 2,463 2,443 Interval 0 P.T.D. 1931860 Type test P Test psi Casing 452 2,500 2,463 2,443 P/F P Notes: BP Internal CMIT-TxIA test#1 OA 2 2 2 2 Well 04-05A Type In]. N ND Tubing 2,343 2,500 2,487 2,477 Interval O P.T.D. 1931860 Type test P Test psi Casing 2,343 2,500 2,487 2,477 P/F P Notes: BP Internal CMIT-TxIA test#2 OA 2 2 2 2 Well Type In]. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In]. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey O=Other(describe in notes) W=Water D=Differential Temperature Test SCA Form 10-426(Revised 11/2012) MIT PBU 04-05 MIT-T CMIT-TxIA 10-19-15 Non witnessed xis • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday, September 11, 2015 3:16 PM To: 'AK, D&C Well Integrity Coordinator'; Regg, James B (DOA) Subject: RE: Permission to Operate: Producer 04-05A (PTD #1931860) Well with Logged Production Casing Leak Whitney, The plan including the MITIA as outlined below for the return to service is approved. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer 2016 Alaska Oil and Gas Conservation Commission SCO K 0 2 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegritvCoordinator@bp.com] Sent: Friday, September 11, 2015 2:38 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA); AK, D&C Well Integrity Coordinator Subject: Permission to Operate: Producer 04-05A (PTD #1931860) Well with Logged Production Casing Leak Jim, As per our conversation, BP would like permission to operate Producer 04-05A(PTD#1931860) if a passing MIT-IA can be obtained. This well is a gas lifted producer that is incapable of unassisted flow to surface. A MIT-T passed to 2500 psi on February 25, 2015 but a CMIT-TxIA failed to 2500 psi. The CMIT-TxIA failed based on BP internal criteria. Subsequently, a leak detect log run on May 10, 2015 identified a production casing leak at 3007' MD (3006'TVD). Upon review of the conversation orders, no restrictions were found that would affect the operability of the well if a passing MIT-IA could be obtained. All pressures could be maintained below MOASP despite the small production casing leak. Please advise on the plan forward. A wellbore schematic,TIO plot, and MIT form from the February 2015 MITs have been included for reference. Please call with any questions or concerns. Thank you, • • Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 ! 0 Producer 04-05A(PTD#1931860) TIO Plot September 11, 2015 i v\e&-tic WELL LOG TRANSMITTAL 2-C.0 t`7 cS11. DATA LOGGED T it6/2015 PROACTIVE DIACINOSTIC SERVICES, INC. M K BENDER To: AOGCC RECEIVED Makana Bender 333 W. 7th Ave JUL 0 7 2(!I5 Suite 100 Anchorage,Alaska 99501 40GC,� a (907) 793-1225 40GCO RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage,AK 99508 SCANNED NED1 . gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1] LeakPoint'T"Survey 10-May-15 04-05A BL/ CD 50-029-20107-01 2) Signed : ✓4 ��/ Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGEAMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archrves\MasterTemplateFiles\Templates\Distnbution\TransmntalSheets\BP_Transmit docx '-. 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. ~C;j' '~ '-)~ ¢2 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 COMMENTS: scanned bY: Bevefly~Vincent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si NOT OPERABLE: 04-OSA (PTD #1931860) Sustained Casing Pressure on~he OA Page 1 af~~~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, February 16, 2010 6:59 PM ~~~ Z~IZ~~° To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Chivvis, Robert; Quy, Tiffany; NSU, ADW Well Integrity Engineer; Winslow, Jack L (ASRC); Holt, Ryan P (ASRC) Subject: NOT OPERABLE: 04-05A (PTD #1931860) Sustained Casing Pressure on the OA All, Well 04-05A (PTD #1931860) has been safed out with kill weight fluid and reclassified as Not Operable. Once the common line inspections and repairs are completed, diagnostics of the wellhead seal integrity will continue. Until then, please ensure the well remains shut-in. Thank you, Anna Dude, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 ~, ~~ °1~E Pager: (907) 659-5100 x1154 ~~~m.~'~~~~~ ~~~ '/" From: NSU, ADW Well Integrity Engineer Sent: Monday, January 25, 2010 3:54 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Winslow, Jack L (ASRC); Chiwis, Robert; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 04-05A (PTD #1931860) Sustained Casing Pressure on the OA All, Well 04-05A (PTD #1931860) has been confirmed to have sustained OA casing pressure. The wellhead pressures were tubing/IA/OA equal to 386/1020/1020 on 1/20/10. The well has been reclassified as Under Evaluation. This well has a history of returning Arctic Pack from the OA when bled. Arctic pack was bled from the OA on 1/16/10 after days of cold weather and logistical issues to move tanks out to the well site. The plan forward includes evaluating the wellhead seals for integrity. A TIO plot and wellbore schematic have been included for reference. Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator 2/17/2010 UNDF,R EVALUATION: 04-OS~TD #1931860) Sustained Casing Prue on the OA Page 1 of 3 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, January 26, 2010 3:44 PM To: 'NSU, ADW Well Integrity Engineer' Cc: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: RE: UNDER EVALUATION: 04-05A (PTD #1931860) Sustained Casing Pressure on the OA Attachments: PBU_04-05A_OA_stable_2008-1214.txt I guess I need some schooling to better understand why BP defines sustained casing pressure different than CO 492. Why wouldn't the repressurization and bleeds every 10-14 days as shown on TIO plot be an indication of sustained casing pressure? If you're basing SCP on exceeding 1000 psi, that is just a function of your bleed frequency - it is sufficiently clear that the OA pressures would exceed 1000 psi in November-December OA pressure builds if not for operator bleeding pressure when it reached 1000psi +/-. What else would this OA repressurization be when evaluating the pressure against the SCP defiinition in CO 492? Also, the well has a history of IAxOA communication (see attached); why doesn't that factor? Even if you assume that the above is outside the SCP rules (which I don't), the excursion above 1000psi together with the IA-OA equalized pressures, and all the other historical factors should have triggered notice to the Commission sometime during the week of 1/10. Wording in CO 492 appears to be getting the gumby treatment with this "understanding". What issues are you referring to that need discussion? Jim Regg AOGCC ~`,~,~,~'~I-1~' .JAi 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, January 26, 2010 2:23 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: RE: UNDER EVALUATION: 04-05A (PTD #1931860) Sustained Casing Pressure on the OA Hi Jim, The OA pressure on 04-05A did not exceed 1000 psi until 1/10/10. Due to the propensity of this well to return arctic pack during bleed operations which in turns plugs hoses, an arctic pack bleed using hardline and a tank was ordered at this time. It is our understanding of Conservation Order 492 that up to three working days are allowed to confirm that the pressure is indeed sustained. It was expected that the pressure would not be sustained based on the past history of this well and therefore notification was not made at that time. Due to inclement weather, the arctic pack bleed operation was delayed. Once the OA pressure was determined to be sustained, notification was made. Perhaps you will be available early February for a meeting to discuss this and other issues. Thank you, 1 /26/2010 UNDER EVALUATION: 04-OS~TD #1931860) Sustained Casing Pres,~yre on the OA Page 2 of 3 Anna ~u6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: {907} 659-5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, January 26, 2010 10:04 AM To: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: 04-05A (PTD #1931860) Sustained Casing Pressure on the OA It appears notification of pressures exceeding the CO 492 thresholds (2000psi IA; 1000psi OA) is late. My interpretation of this plot is that 1000psi was reached (and possibly exceeded) several weeks earlier (on or about 12/26?); also appears pressures were allowed to build to 1000psi before bleeding, which I guess is acceptable but doesn't give you much room with increasing OA pressure if operator is prevented from getting to the well for a couple days due to weather, etc. OA pressure beginning 1/9 are also curious to me -why were pressures allowed to exceed 1000psi for almost a week without notice to the Commission or bleeding pressure? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, January 25, 2010 3:54 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Winslow, Jack L (ASRC); Chiwis, Robert; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 04-05A (PTD #1931860) Sustained Casing Pressure on the OA All, Well 04-05A (PTD #1931860) has been confirmed to have sustained OA casing pressure. The wellhead pressures were tubing/IA/OA equal to 386/1020/1020 on 1/20/10. The well has been reclassified as Under Evaluation. This well has a history of returning Arctic Pack from the OA when bled. Arctic pack was bled from the OA on 1/16/10 after days of cold weather and logistical issues to move tanks out to the well site. The plan forward includes evaluating the wellhead seals for integrity. A TIO plot and wellbore schematic have been included for reference. «04-05A TIO plot.doc» «04-05A.pdf» Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 1 /26/2010 UNDER EVALUATION: 04-OS~TD #1931860) Sustained Casing Pres~e on the OA Page 3 of 3 Pager: {90?) 659-5100 x1154 1 /26/2010 PBU 04-05A PTD #1931860 1 /25/2010 TIO Pressures ~,uo0 a,ooo 2,000 1,000 e~~s ~~ 10}31 }09 11 }O r }05 11 }14}09 11 }21 }09 11 !28}09 12}05}09 12}12}09 12}19}00 12}26}00 01 }02}1 O 01 }09}10 01 }16}10 01 }23}10 ~~ ' "uk.~l ~ a~ Q ~~ C1Vl 0 ~' cC~I~ t 1 L~ Z~ Dr t I ~~ `ZJ~o 7 J~2~~ i~ ~~ is ~- Tbg -F IA -~ OA ooA OOOA On • TREE= McEVOY GEN 1 WELLHEAD = ACTUATOR = MCEVOY AXELSON KB. ELEV = 60' BF. ELEV = ? KOP = 3396' Max Angle = 47 @ 8987' Datum MD = 10199' Datum TV D = 8800' SS ~ 04-05 13-3/8" CSG, 72#, N-80, ID = 12.347"~ 2711' 5-1l2" TBG, 17#, 13-CR-80, A232 bpf, ID = 4.892" -r 30 ~ TOP OF 7" LNR i-I SU4S. 9-5/8" CSG, 47#, N-80/S-95, ID = 8.681" $254' ~7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 4-112" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 9617' Minimum ID = 3.725' @ 10053' 4-1 /2" OTIS XN NIPPLE TOP OF 4-112" TBG 10043' -{- 2094' I-i 5-1/2" CAM BAL-O SSSV NIP, ID = 4.56" 3092" - j 5-112" X 4-1 /2" XO GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3323 3320 10 MMG RK 2 5295 5050 41 MMG RK 3 6668 6054 42 MMG RK 4 7220 6467 40 MMG RK 5 7727 6864 36 MMG RK 6 8019 7101 34 MMG RK MILLOUT WINDOW~~ 9-518" @ 8254' 9517' ~ 4-1/2" OTIS X NIP, ID = 3.81' 9538' 7" X 4-1/2" BAKER SABL-3 PKR 9604' -~ 4-1/2" OTIS X NIP, {D = 3.81" 9$~ 4-1/2" TBG TAIL WIEG 1(}043' --I7" X4-1/2" BAKER F-1 ISOLATION PKR 10049' 4-1/2" XX PLUG (11/27/09) 10049' 4-112" OTIS X NIP, ID = 3.81" 10053' 4-112" OTIS XN NIP, tD = 3.725" 4-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 1005$' --~ 10056 4-112" TBG TAIL WLEG 10057' ELMD TT LOGGED 05/17/94 PERFORATK7N SUMMARY REF LOG: BHC5 05!03/94 ANGLEATTOPPERF:25 @9960' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 1 9960 - 9964 S 11(26194 3-3/8" 4 9976 - 9980 S 11 /26/94 3-3/8" 1 10022-10025 S 11/26/94 2-7/8" 6 10110 - 10150 O 11/18/97 2-7/8" 418 10150 - 10176 S 11126/94 PBTD 7" LNR, 29#, 13-CR-80, .0371 bpf, ID = 6.184" ~--` 10294' DATE REV BY COMMENTS DATE REV BY COMMENTS 1977 ORIGINAL COMPt_EI'ION 12(07/06 RLM/TLH DIAGRAM CORRECTION {GLV) 05/07/94 LAST WORKOVER 03/08/07 RDW/PAG WAVER SFTY NOTE DELETED 02/04/02 RN/TP CORRECTIONS 12/09109 CJN(SV SETXX PLUG (11/27!09} 11/16/03 TJP/PAG WAVER SAFETY NOTE 12/21/05 COMlPAG WAVER SAFETY NOTE 05/30/06 DTM WELLHEAD CORRECTION PRUDHOE BAY UNCI" WELL: 04-05A PERMIT No: 1931860 API No: 50-029-20107-01 SEC 34, T11 N, R15E 3426.15 FEL 3544.49 FNL BP Exploration (Alaska) OPERABLE: 04-OSA (PTD #1931860) OA pressure stable • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, December 14, 2008 9:05 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); Chivvis, Robert; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 04-05A (PTD #1931860) OA pressure stable All, J" After inner casing packoff work was completed on well 04-05 (PTD #1931860), the OA pressure has remained constant. Therefore, the well has been reclassified as Operable. Please contact Well Integrity if IAxOA communication is again observed. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday, November 20, 2008 8:57 PM "S w L,_~ To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Chivvis, Robert; Quy, Tiffany Subject: UNDER EVALUATION: 04-05A (PTD #1931860) for Sustained OA casing pressure Hi all, Well 04-05A (PTD #1931860) has been found to have sustained casing pressure on the OA. The wellhead pressures were tubing/IA/OA equal to 418/1990/1350 psi on 11/16/08. The arctic pack was recently flushed from near surface in the OA and the high OA pressure was initially thought to be due to gas breaking through the arctic pack. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the OA pressure to continue to build pressure. The plan forward for the well is as follows: 1. DHD: OA repressurization test -FAILED 2. Wellhead Tech: Eval for PPPOT-IC 3. DHD: Bleed OA pressure, monitor build-up rate 4/16/2009 OPERABLE: 04-OSA (PTD #~ 1860) OA pressure stable ~ Page 2 of 2 A TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Anna ~Du6e, 2'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 4/ 16/2009 UNDER EVALUATION: 04-OSA (PTD #1931860) for Sustained OA casing pressure Page 1 of 1 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~,~~ li" /~,%2~ Sent: Thursday, November 20, 2008 8:57 PM I l To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East {FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Chivvis, Robert; Quy, Tiffany Subject: UNDER EVALUATION: 04-05A (PTD #1931860) for Sustained OA casing pressure Attachments: 04-05A 30-day TIO plot.BMP; 04-05A.pdf Hi all, Well 04-05A (PTD #1931860) has been found to have sustained casing pressure on the OA. The wellhead pressures were tubing/IA/OA equal to 418/1990/1350 psi on 11/16/08. The arctic pack was recently flushed from near surface in the OA and the high OA pressure was initially thought to be due to gas breaking through the arctic pack. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the OA pressure to continue to build pressure. The plan forward for the well is as follows: 1. DHD: OA repressurization test -FAILED ~ 2. Wellhead Tech: Eval for PPPOT-IC ~ , ~,~~~ ~~ 3. DHD: Bleed OA pressure, monitor build-up rate A TIO plot and wellbore schematic have been included for reference. «04-05A 30-day TIO p1ot.BMP» «04-05A.pdf» Please call with any questions. Thank you, Well Integrity Coordinator GPS Wells Graup Phone: {907) 659-5102 Pager: {907) 659-5100 x1154 11 /24/2008 • ~j T .~ ~ ~ ~n O M i a-- ~ .~ ~ ~` ^~ y ~ ~ • - 1 a a a a a a ~ (''i 0 a cv w 0 0 0 T ~~ a a T r a a a a T O a 0 r a 1 a a ~_ a a a acv a i a a a a o a N r TREE = Mc EV OY GEN 1 WELLHEAD= MCEVOY ~~ ACTUATOR= AXEL50N KB. ELEV = BF. ELEV - KOP = Max Angle = 60' _ _? _ 339fi' 47 @ 8987 Datum MD - 10199' Datum TV D = 8800' SS SAFETY NOTES: HZS OVER 300PPM, LNR/COLLAR LEAK f„~,.®~ .~ AND 1 I E 7T LNRT @ 3300'-3800'. ***CHROMETBG I 13-3/8" CSG, 72#, N-80, ID = 12.347"~--~ 2711' ~ 5-1l2" TBG, 17#, 13-CR-80, A232 bpf, ID = 4.892" 3092' TOP OF 7" LNR ! $04$' 9-5f8" CSG, 47#, N-801S-95, ID = 8.681" $254' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I-I 9411' 4-112" TBG, 12.6#, 13-CR-80, .0152 bpf. ID = 3.958" ~ 961T Minimum ID = 3.725' @ 10053' 4-112" OTIS XN NIPPLE TOP OF 4-1/2" TBG -f 10043' 4-112" TBG. 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~-i 10058` PERFORATION SUMMARY REF LOG' BHCS 05/03194 ANGLE AT TOP PERF: 25 @ 9960' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-378" 1 9960 - 9964 S 11126194 3-3(8" 4 9976 - 9980 S 11 /26/94 3-318" 1 10022 - 10025 S 11126/94 2-7,8" 6 10110 - 10150 O 11f18197 2-718" 418 10150 - 10176 S 11/26!94 2094' ~-] 5-112" CAM BAL-O SSSV NiP, ID = 4.56" 3092' -~5-1r2° x 4-1/2^ xo I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3323 3320 10 MMG DOME RK 16 07/23/08 2 5295 5050 41 MMG DMY RK 0 07(23/08 3 6668 6054 42 MMG DOME RK 16 07/23/08 4 7220 6467 40 MMG DMY RK 0 5 7727 6864 36 MMG DMY RK 0 07123!08 6 8019 7101 34 MMG SO RK 24 07!23/08 MILLOUT WINDOW: 9-518" @ 8254' 9517' 4-1/2" OTIS X NIP. ID = 3.81" 953$' 7" X 4-1/2" BAKER SASL-3 PKR 9604' 4-1/2" OTIS X NIP. ID = 3.81" 96~ 4-1/2" TBG TAIL WLEG 1®043' -~7" X 4-1,'2" BAKER F-1 ISOLATION PKR 10049' -r 4-1l2" OTIS X NIP. 4D = 3.81° 10053' 4-112" OTlS XN NIP, ID = 3.725"' 10056' 4-112" TBG TAIL WLEG 10(}57' --~ELMD TT LOGGED 05/17/94 PBTD i-i 10253' 7" LNR, 29#, 13-CR-80, .0371 bpf, ID = 6.184" ~-~ 10294' DATE REV BY COMMENTS DATE REV BY COMMENTS 1977 ORIGINAL COMPLETION 12,'07;06 RLNUTLH DIAGRAM CORRECTION (GLV} 05/07/94 LAST WORKOVER 03!08107 RDWlPAG WANERSFTY NOTE DELETED 02/04!02 RNlTP CORRECTK?NS 08!05108 KSB/PJC GLV C/O (07/23/08) 11(16(03 TJP(PAG WANER SAFETY NOTE 12(21(05 COM/PAG WAN ER SAFETY NOTE 05/30!06 DTM WELLHEAD CORRECTION PRUDHOE BAY UNIT WELL: 04-05A PERMIT No: 1931860 API No: 50-029-20107-01 SEC 34, T11 N, R15E 3426.15 FEL 3544.49 FNL BP Exploration (Alaska) 04-05A (PTD #1931860) Internal Waiver Cancellation - Normal Well . . All, An internal waiver was issued for IAxOA communication on well 04-05A (PTO #1931860) on 12/10/05. The rate of communication has been reviewed and is manageable by bleeds. In addition, the tubing and production casing integrity has been proven by pressure tests to 3000 psi. The well may be put on production under normal operating pressure limits of 2000 psi on the IA and 1000 psi on the OA. The well is reclassified as a Normal well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 sCANNED MAR 09 2007 1 of 1 3/9/2007 1 :30 PM Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well . MPI-09 MPI-09 :À.ÚQ - {\:..) 3 .__ . ~~I~Q~T-=-- 0):<-1 [ NK-08A Ü NK-08A 18-34 . G\ ç ... i 6¥ 04·05A i t¡3 */ '3 b~ 18.05Al ~ ). -2. . G 07-36 ; q 7 - f ~ '[ 14-36 IF J .- I (3 C-13A / q 7 - ì '-i J U-12 185--1 j J.... R-21 i \93 -.. J 1... ~ R-12 í9.3 -. 0 ).)'" E-16 lsa - c, J J·23 I 8 7 ~ 0 J I . '5-7 F-31 / 8 ~ - , H-35 I G ç -- j i.f q Job# 10563225 10980572 10772241 10560316 10703956 10564525 10703939 10563112 10866557 10564527 11075900 10674388 10687647 10564529 10663003 10703943 10563217 10563216 Log Description INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PSP GLS PPROF WIDEFT PSP LDL PRODUCTION PROFILE LEAK DETECTION LOG LEAK DETECTION LOG INJECTION PROFILE MEM PROD & INJECTION PROFILE LDL PRODUCTION PROFILE PSP PPROF W/GHOSTIDEFT PRODUCTION PROFILE SBHP SURVEY SBHP SURVEY PPROF W/GHOST 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: ) ( ó.:<J-v CCv¡ j h, .- v\.,(,'-(' ) , SCANNEC SEP Date 10/05/03 06/09/05 04/04/04 10/22/03 11/27/03 09/27/03 10/24/03 10/13/03 07/14/04 09/29/03 07105105 10/27/07 09/20/03 10/01/03 03/10104 10/28/03 09/28103 09/27/03 [t 8: 20 [1ti \cr~- t~~ 07/20/05 NO. 3438 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 t 1 1 1 Color CD "-.-' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN Beth FÎ I I (1' ¡/ Î. Received by: l)~)" L.) Ú~,·, or. C:t.o~.DOc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ StJrnulate__ Plugging _ Pedorale _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 64' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 stratagrapic _ Anchora~le, AK 99510-0360 Service_ Prudhoe Ba}, Unit 4. Location of well at surface: 8. Well number: 742' SNL, 420' WEL, Sec 34, T11N, R15E, UM. 4-05A At top of productive interval: 9. Permit number/approval number: 1536' NSL, 3343' WEL, Sec 27, T11N, R15E, UM. 93-186 At effective depth: 10. APl number: 50-029-20107-01 At total depth: 11. Field/Pool: 1733' NSL, 3429' WEL, Sec 27, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10294 feet Plugs (measured) Tagged PBTD @ 10150' MD (11/16/97). true vertical 8943 feet Effective Depth: measured 10150 feet Junk (measured) true vertical 8809 feet Casing Length Size Cemented Measured depth True vertical depth Structural 113' 30" 237 Sx Fondu Neat 113' 113' Conductor 971' 20" 935 Sx PF II & 971' 971' 190 Sx Fondu Surface 2647' 13-3/8" 1100 Sx PF II 2711' 2711' Production 8190' 9-5/8" 800 Sx Class C & 8254' 7298' 300 Sx PF II Liner 2246' 7" 400 Sx Class G 10294' 8943' Perforation Depth measured 10110- 10176' true vertical 8771 - 8832' lubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR-80, NSCC Tbg @ 3092' MD; 4-1/2", 12.6#, 13 CR-80, Fox Tbg @ 9617' MD; 4-1/2", 12.6#, 13 CR-80, NSCT Tbg @ 10043- 10058' MD. !Packers and SSSV (typeand measured depth) Baker F-1 Isolation Packer @ 10043' MD; Baker SABL-3 Packer @ 9538' MD; 4-1/2", Camco Bal-O SSSV @ 2094' MD. Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Averaqe Production or I niection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 625 892 5086 247 Subsequent to operation 728 2370 6846 264 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. Si,ned ~~ ~ ...-~'~~~OE. E.J~.O~I Title: En~ineerin~Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 4-05A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 11/16/97: RIH &tagged PBTD at 10150' MD. 11/18/97: MIRU & PT equipment. Added perforations: Reperforated: RIH w/perforating gun & shot 40' of perforations as follows: 10110- 10122' MD (Z2) 10125 - 10140' MD (Z2) 10122- 10125' MD (Z2) 10140- 10150' MD (Z2) Ref. Log: BHCS 5/3/94. Ref. Log: BHCS 5/3/94. Used 2-7/8" carriers & shot the perforations at 6 spf at 60 degree phasing at balanced pressure POOH w/perf guns. Rigged down. Returned the well to production & obtained a valid welltest. AOGCC Individual Well -~eoleglcai Materials Inventory T DATA_PLUS Page D at e RUN .;_ 10,/1.3/95 DATE_RECVD 93-i86 93 - 186 93-186 93~.i86 9 $-~ 186 93 ~ ! 36 e3~186 93~i86 93~186 93-186 93~!86 2 ~CA/GR ~7~P/{~Am~GR ~/~NL/GR ~LL/GR/SP ~C/GR/CL 'T' 8250-1029') L 95~~' i'~2q2u L 8255-10290 L ~'~50-~ ~,~ ~ z0220 L 9550-I0242 L 9950-Ii090 L 9700-10!48 L 9820~i0122 L 99~2~I0080 L 9796~i0i73 VD T, 9550~10242 ~'~ (BLUELiNE L 9940-10254 w~NZ~,,±) L ~a~n-10214 OH-AC/GR 1 1 ! 1 1 1 1 1 i i 1 05/27/94 05/27/94 05/27/94 05/27/94 05/27/94 05/27/94 08/29/94 10/24/94 05/27/94 09/13/94 05/27/94 06/20/94 05/27,/94 Are dry ditch samples requ~-~ "? _ ~____~And received? mi eot ves Y~ Was the well cored? yes ~nalysis & descripti - -~_l.,~ ,.. yes Are well ~_r ~\y~ ~.:.ts requ±red? -~-.s Well is ~n cum~ ,±ance COHHE NT S ilo STATE OF ALASKA ALASKA ;AND GAS CONSERVATION CC rVIISSION REPORT SUNDRY WELL OP - ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 742' SNL, 420' WEL, Sec. 34, T11N, R15E, UM At top of productive interval 1536' NSL, 3343' WEL, Sec. 27, T11N, R15E, UM At effective depth At total depth 1733' NSL, 3429' WEL, Sec. 27, T11 N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-5A 9. Permit number/approval number 93-186 10. APl number 50 - 029-20107-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 113' Conductor 971' Sudace 2647' Production 8190' Liner 2246' 10294 feet Plugs(measured) 8943 feet 10253 feet 8905 feet Junk(measured) Size Cemented 30" 237 sx Fondu Neat 20" 935 sx PF II & 190 sx Fondu 13-3/8" 1100 sx PF II 9-5/8" 800 sx CI C & 350 sx PF II 7" 400 sx CIG Measured depth True vertical depth 113' 113' 971' 971' 2711' 2711' 8254' 7298' 10294' 8943' Perforation depth: measured 10140-10176' true vertical 8799-8833' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13CR-80, NSCC Tbg @ 3092' MD; 4-1/2", 12.6~, 13CR-80, Fox Tbg @ 9617' MD; 4-1/2", 12.6#, 13CR-80, NSCT Tbg @ 10043'-10058' MD Packers and SSSV (type and measured depth) Baker F-1 Isolation Packer @ 10043' MD; Baker SABL-3 Packer @ 9538' MD; 4-1/2", Camco Bal-O SSSV @ 2094' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached 14. FEB -7 1995 Treatment description including volumes used and final pressure Ailt,~ka 0ii & Gas Cons. Commission Representative Daily Average Production or Injection Data Anch0ra? OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2094 20040 7256 395 Subsequent to operation 1347 1475 6104 - 255 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: OilX~ Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Form 10-404 Rev 06/15/88 AJB cc: KZ, JWP Title Engineering Supervisor ORIGINAL SUBMIT IN DUPLICATE 4-05A DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF I 0/1 4/g4' Added Perforations: 9960- 9964' MD (Z2) 10022 - 10025' MD (Z2) Ref. Log: BHCS 5/3/94. 11/19/94 - I 1/20/94: RIH & set a 4.5" PXN Plug in the XN Nipple at 10053' MD, to isolate the lower open perforations located below the isolation packer at: 10140 - 10176' MD (Zl) Ref. Log: BHCS 5/3/94. Made runs w/dump bailer & dumped 600 lbs of sand on top of the PXN Plug, in preparation for cement squeeze. POOH w/dump bailer. Rigged down. I 1/26/94: A CTU Cement Squeeze was performed for Gas Shutoff as follows: MIRU CTU & PT equipment to 4000 psi. Loaded the wellbore w/Hot Seawater & RIH w/CT to tag sand at 10029' MD. Pumped cement to squeeze the open perforation intervals located above the sand/plug (above), at: 9960 - 9964' MD (Z2) 9976 - 9980' MD (Z2) 10022 - 10025' MD (Z2) Ref. Log: BHCS 5/3/94. Pumped 50 bbls of Latex Acid Resistive Cement & placed 1 bbl of cement behind pipe at 3500 psi max squeeze pressure, held for 1 hour. Contaminated cement w/biozan & jetted contaminated cement down to 10051' MD. POOH w/CT. Rigged down. 12/11/94 12/18/94' Made bailer runs & bailed sand & cement from wellbore to the top of the PXN Plug (above). 12/26/94- RIH & POOH w/PXN Plug, to resume production from the lower perforation interval (listed above). Returned well to production w/gaslift & obtained a valid production test. Note: Oil rate decreased by 747 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1428 BOPD, resulting in a net oil benefit of 681 BOPD. RE EIVE, D FEB -7 lt~95 Alaska Oil & Gas C0n~. Commission Anchora~.:~ STATE OF ALASKA · ALASKA . AND GAS CONSERVATION CC AlSSlON REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 742' SNL, 420' WEL, Sec. 34, T11 N, R15E, UM At top of productive interval 1536' NSL, 3343' WEL, Sec. 27, T11N, R15E, UM At effective depth 5. Type of Well Development Exploratory Stratigraphic Service ~ At total depth ;~i;~S~(2~ *':' 1733' NSL, 3429' WEL, Sec. 27, T11N, R15E, UM Anohor~ 2: 6. Datum of elevation(DF or KB) 64 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-5A 9. Permit number/approval number 93-186 10. APl number 50 - 029-20107-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10294 feet Plugs(measured) PBTD Tagged @ 10172' MD (8/9/94) true vertical 8943 feet Effective depth: measured 10172 feet true vertical 8829 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 113' 30" 237 sx Fondu Neat 113 113 Conductor 971' 20" 935 sx PF II & 190 sx Fondu 971' 971' Sudace 2647' 13-3/8" 1100 sx PF II 2711' 2711' Production 8190' 9-5/8" 800 sx Cl C & 350 sx PF II 8254' 7298' Liner 2246' 7" 400 sx Cl G 10294' 8943' Perforation depth: measured 9976-9980'; 10140-10176' true vertical 8646-8649" 8799-8833' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR-80, NSCC Tbg @ 3092' MD; 4-1/2", 12.6#, 13 CR-80, Fox Tbg @ 9617' MD; 4-1/2", 12.6#, 13 CR-80, NSCT Tbg @ 10043'-10058' MD Packers and SSSV (type and measured depth) Baker F-1 Isolation Packer @ 10043' MD; Baker SABL-3 Packer @ 9538' MD; 4-1/2", Camco BaI-O SSSV @ 2094' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2313 2402 5638 2391' 6677 8286 Tubing Pressure 268 308 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I here_by 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 1220/14 cc: KZ, JWP SUBMIT IN DUPLICATE? 4-05A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 8/9/94: MIRU & PT equipment. perforations as follows: RIH w/perforating gun & tagged PBTD at 10172' MD, then shot 35' of Added perforations: 9976 - 9980' MD (Z2) Ref. Log: BHCS 5/3/94. Reperforated: 10140 - 10171' MD (Z1) Ref. Log: BHCS 5/3/94. Used 3-3/8" carriers & shot perforations at 180 degree phasing, at underbalanced pressures. Shot 9976 - 9980' MD at 1 spf. Shot 10140 - 10151' MD & 10156 - 10176' MD at 4 spf, & shot 10151 - 10156' MD at 8 spf (interval overlapped by two guns). POOH w/perf guns. Rigged down. Returned the well to production & obtained a valid welltest. GeoQuest 600 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 8923 Oompany: Alaska 011 & Gas Cons Oomm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 9/12/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar q_ ~> - ( ~D.S. 1-6 PROD PROFILE (8-20-94) 1 1 jF6- c~-5' D.S. 2-13 PERF REOORD (8-21-94) 1 1 ?S"-?~ D.S. 3-1 PROD PROFILE (8-19-94) 1 1 ~ D.S. 4-4,, PROD PROFILE (8-25-94) 1 1 ~ ~' [~'C. D.S. 4-5A IPROD PROFILE (8-19-94) 1 1 ? ~'-z.3___._~ D.S. 4-29 INJEO PROFILE (8-19-94) 1 1 ~e-?.,C D.S. 6-10 .. PROD PROFILE (8-20-94) 1 1 2(~ -~__~_~ D.S. 6-15 PERF RECORD (8-20-94) 1 1 D.S. 9-26 LEAK DETECTION (8-23-94) 1 1 _ D.S. 11-24A DUAL BURST TDT-P (8-19-94) I 1 _,~'~-__~o D.S. 11-33 DUAL BURST TDT-P (8-25-94) 1 1 ~, - ~' ~" ! ~, ~ D.S. 12-3 PERF REOORD (8-22-94) 1 1 K ' ~.. E J ~ ~ D.s. 14-15 PERF REOORD (8-20-94) 1 1 ~/..___~ ~. c,_ D.S. 14-20 PROD PROFILE (8-24-94) 1 1 S !P ~ ~' 'i Commission Please sign and retum on/e copy of this transmittal to SherrJe at the above address. Thank you. DATE: Anchorage GeoQuest 600 W. International Airport Road Anchorage, AK 99518-1199 Al'tN: Sherrie NO. 8889 Company: Alaska OII & Gas Cons Comm , Atth: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 8126/94 Field: Prudhoe Bay Well Log De~::ription BL RR Sepia RF Sepia Mylar ?~/~:]'~ D.S. 1-09A DUAL BURST TDT (8-7-94) 1 1. ~~ D.S. 4-05A PERF RECORD (8-9-94) 1 1 ~,-~,_m~ D.S. 7-' 17 DUAL BURST TDT (8-5-94) 1 1 '/~ D.S. 9-5A DUAL BURST TDT (8-7-94) 1 1 ~ I-7...___._~ D.S. 13-11 pRoD PROFILE (8-5-94) 1 1 ~'3--C~ D.S. 13-28 LEAK DETECTION (8-5-94) 1 1 ;> ~'--'~C~C=, D.S. 14-7 BRIDGE PLUG RECORD (8-8-94) 1 1 ~ l,, il c~ D.S. 14-26 PROD PROFIE (8-6-94) 1 1 ?:~-l,/~-'D.S. 14-35 TUBING PUNCHER & POGLM RECORD (8-6-94) 1 1 ~1-/'/' D.S. 16-3 PERF RECORD(8-9-94) 1 1 ~ DS. 16-31 LEAK DETECTION (8-9-94) 1 1 Please~ ~ign and retum cee copy of this transmittal to Shertie at the above addre;ss. Thank you. STATE OF ALASKA ALASK/~'---~ L AND GAS CONSERVATION Cr :~'MISSION REPORT SUNDRY WELL OP:RATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 742' SNL, 420' WEL, sec. 34, T11N, R15E, UM At top of productive interval 1536' NSL, 3343' WEL, Sec. 27, T11N, R15E, UM At effective depth At total depth 1733' NSL, 3429' WEL, Sec. 27, T11 N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service R F_ C F.. IV F-. D Gas Cons. Commission Anch0rage 6. Datum of elevation(DF or KB) 64 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-05A 9. Permit number/approval number 93-186 10. APl number 50 - 029-20107-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10294 feet Plugs(measured) true vertical 8943 feet Effective depth: measured 10253 feet 0RIGII~AL true vertical 8905 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 113' 30" 237 sx Fondu Neat 113' 113' Conductor 971' 20" 935 sx PF II & 190 sx Fondu 971' 971' Surface 2647' 13-3/8" 1100 sx PF II 2711' 2711' Production 8190' 9-5/8" 800 sx CI C & 350 sx PF II 8254' 7298' Liner 2246' 7" 400 sx CIG 10294' 8943' Perforation depth: measured 10160-10176' true vertical 8818-8833' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR-80, NSCC Tbg @ 3092' MD; 4-1/2", 12.6#, 13 CR-80, Fox Tbg @ 9617' MD; 4-1/2", 12.6#, 13 CR-80, NSCT Tbg @ 10043'-10058' MD Packers and SSSV (type and measured depth) Baker F-1 Isolation Packer @ 10043' MD. Baker SABL-3 Packer @ 9538' MD; 4-1/2", Camco BaI-O SSSV @ 2094' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 3295 3407 5129 Tubing Pressure -- 248 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 1149/10 KRF cc: JED, JWP Title Engineering Supervisor SUBMIT IN DUPLICATE 4-05A DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF ZONE I 5/16/94' RIH & tagged PBTD at 10255' MD. 5/17/94' Shot Initial Perforations: 10160 - 10176' MD (Z1A) Ref. Log: BHCS 5/3/94. 5/20/94 · MIRU & PT to 9050 psi. Pumped a Hydraulic Fracture Treatment using 20/40 mesh proppant, through the perforations (listed above). a) 300 bbls 20# Pre Pad Gel @ 25 bpm, followed by b) Shutdown. Pumped: pumping Data Frac: Resumed c) 100 bbls 40# Crosslinked Gel @ 20 bpm, followed by d) 70 bbls 40# Crosslinked Gel @ 5 bpm, followed by e) 73 bbls 40# Crosslinked Gel @ 20 bpm, followed by f) 186 bbls 20# Flush @ 20 bpm, followed by g) Shutdown. ISIP @ 1491. pumping Fracture Treatment: Resumed h) 95 bbls 45# Crosslinked Pad @ 20 bpm, followed by i) 345 bbls Slurry w/proppant stages @ 2 - 8 ppg, followed by j) 186 bbls 20# Flush, followed by k) Shutdown. Rigged down. Placed a total of 60,700 lbs of proppant into the formation. 5/22/94 · RIH w/CT & jetted a proppant fill cleanout to 10263' MD. Returned the well to production through the proppant fill w/gaslift & obtained a valid welltest. RECEIVED JUL. 2 5 1994 A~sska Uil & Gas 0OHS. 6ommission Anchoraue STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2, Name of Operator 7. Permit Number CO,nc. ORIGINAl 3. Address ...... '"-- 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20107-01 4. Location of well at surlace 9. Unit or Lease Name 742 SNL, 420 WEL, SEC. 34, T11N, R15E : '". .... - '[~" i I,OC.A~ Prudhoe Bay Unit At Top Producing Interval ! ~,,,.Z~,T~,,~_~¢ ~ ~11~1~ . 10. Well Number 1536 NSL, 3343' WEL, SEC 27, T11N R15E '~¢-"i"'~r~. ~ - At Total Depth i --~.~, ~ '-: ..... -7-~.' ........ ;:- - Prudhoe Bay Field/Prudhoe Bay Pool 1733' NSL, 3429' WEL, SEC. 27, T11N, R15E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 53.26' ! ADL 28325 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 4/29/94 5/2/94 5/17/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 10294' MD/8943' TVD 10253' MD/8905' TVD YES [] NO []I 2094' feet MD J 1900' (Approx.) 22. Type Electric or Other Logs Run Cal/A C/DLL/CNL/GR/MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP DO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 157.5# B Surface 113' 39" 237 sx Fondu Neat 20" 94¢t H-40 Surface 971' 26" 935 sx PF 11/190 sx Fondu 13-3/8" 72# N-80 Surface 2711' 17-1/2" 1100 sx PF II 9-5/8" 53.5#/47# S-95/N-80 Surface 8254' 12-1/4" 800 sx Class "c"/35o sx PF II 7" 29# L-80/13CR 8048' 10294' 8-1/2" 400 sx Class "G" 24. Perforations open to Production (MD+TVB of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET {MD) Gun Diameter 3-3/8" 4 spf 5-1/2" x 4-1/2" 9617' 9538' & 10043' MD TVD 10160'-10176' 8818'-8833' 13CR80 4-1/2"tail ~oo43'-~oo5a' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) 5/27/94 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF ¢¢ATER-BBL CHOKESIZE IGAS-OIL RATIO I i'EST PERIOD Flow Tubing Casing Pressure 3ALCULATED OlL-BBL GAS-MCF ¢/ATER-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. RECEIVED JUil 2_ ? ;-;i¢;3ka. (~i! & Gas Cons. 60mrnissi0n ,Anch0ra_je Form 10-407 Submit in duplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE zg. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Top Sadlerochit 9758' 8453' Zone 2 9902' 8582' Base Sadlerochit 10177' 8834' RECEIVED ,,-'.'. ...... ~a$ ~ ' uons. fJornmission Anch0ra,_t~ 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge "~/?J/l~xl'''{~.)~'.,~' Drillina Enainoer_ Suoervisor Signed . . Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 4-5A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/23/94 10:30 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 04/24/94 ( 1) TD:10002 PB: 0 04/25/94 ( 2) TD:10002 PB: 9580 04/26/94 ( 3) TD:10002 PB: 9580 04/27/94 ( 4) TD:10002 PB: 9580 RU BOPE MW: 8.5 Seawater MOVED RIG TO DS 4-5A. SPOTTED RIG OVER WELL, JACKED UP RIG AND LYERED MATTING BOARDS 3 LAYERS DEEP TO PROVIDE WORKING SPACE F/ BOPE ON MCEVOY GEN I WELLHEAD. SPOTTED PIT COMPLEX AND LEVELED W/ RIG. TOOK ON SEAWATER AND BEGAN RIGGING UP TO KILL WELL. ACCEPTED RIG @1030 HRS ON 04/23/94. RU TO KILL WELL. RU LUBRICATOR, PULLED BPV. NO PRESSURE ON WELL. CIRCULATED OUT 400 BBLS METHANOL WATER. MONITOR WELL DEAD. SET TWC. ND TREE. BUILT BOP STACK, NU SINGLE GATE, DOUBLE GATE, HYDRILL. RU CONTROL LINES, CHOKE AND KILL LINES. LD TUBING MW: 8.5 Seawater CONTINUE TO RU BOPE. ATTEMPTED BOP TEST. LEAKING PAST HANGER/TWC. RU LUBRICATOR AND PULLED TWC. MU SPEAR. ENGAGED TUBING W/ SPEAR. CLOSED BAG AND TESTED AGAINST WELL. B.O.L.D.S. PULLED HANGER TO FLOOR W/ 185K# PUW. LD HANGER AND CBU. LD COMPLETIONS. RECOVERED 74 JTS 7" 26# L-80 LTC, SSSV, 2 GLMS, 75 JTS 5 1/2" 17# L-80 BTC. TEST BOPE MW: 8.5 Seawater FINISHED LD TUBING. LD COMPLETION. RECOVERED 74 JTS 7" 26# L-80 LTC, SSSV, 10 GLM'S, 143 JTS 5 1/2" 17# L-80 BTC, SEALS AS .57 SS HANDS. RD TOOLS AND CLEARED FLOOR. RU TEST EQUIPMENT, INSTALLED TEST PLUG. CHANGED RAMS TO 4 1/2" ATTEMPTED TO TEST BOPE. TEST FAILURES ON BOTH SETS PIPE RAMSS, BLINDS, TOP PIPE RAM DOOOR HINGE SEALS, BLIND RAM DOOR HINGE SEALS, AND TEST PLUG. PU DP, RIH W/ BRIDGE PLUG MW: 8.5 Seawater CONTINIED TO ATTEMPT BOPE TEST. DSR ON LOCATION, INSPECTED STACK, STACK IN SPEC. INSPECTED RAM ELEMENTS, FOUND DRY CRACKING. REDRESSED BOTTOM RAMS, INSTALLED AND TESTED. RAMS HELD, STILL SMAL LEAK ELSEWHERE. REDRESSED BLINDS, INSTALLED AND TESTED. CHANGE OUT TOP RAMS, INSTALLED AND TESTED. FLUSHED HYDRAULIC SYSTEM TO INSURE INTEGRITY. PULLED TEST PLUG, SEAL NOT AVAILABLE TO REDRESS, BUT SEALS IN GOOD CONDITION. INSTALLED TEST PLUG AND RILDS. TESTED STACK RAMS. GOOD TEST. RETESTED BOP STACK COMPONENTS, FUNCTION TESTED ACCUMULATOR SYSTEM. STACK AND WELLHEAD NOW ACCEPTABLE TO CONTINUE WORK. MU BAKER HYDRAULIC SET BRIDGE PLUG. PU DP AND RIH. WELL : DS 4-5A OPERATION: RIG : NABORS 2ES PAGE: 2 04/28/94 ( 5) TD:10002 PB: 9580 04/29/94 (6) TD: 8254 PB: 8254 04/30/94 ( 7) TD: 8552' ( 0) 05/01/94 (8) TD: 9371' ( 819) MILLING 53.5# 9 5/8" CSG MW: 8.5 Seawater PU DP AND RIH W/ BRIDGE PLUG. SET BRIDGE PLUG @ 8500' TESTED CASING. NO LOSS. DISPLACED WELL TO 10.0 PPG MILLING FLUID. SPOTTED 18 PPG PILL ON BOTTOM. POH. LD 32 JTS DP. SLIPPED DRLG LINE. POH. LD RUNNING TOOL. MU BHA #1. RIH W/ BHA #1. POSITIONED MILL @ 8254' MD. MADE CUT-OUT IN 1 HR, MILLED F/ 8254-8269'. METAL RETURNS EXCELLENT. NO PROBLEMS ASSOCIATED W/ 53.5# CASING. CHANGING RAMS MW: 8.5 Seawater MILLED F/ 8269-8304' CIRCULATED HOLE CLEAN. POH. LD BHA #1. RIH W/ MULESHOE. WASH THRU SECTION TO 8404', NO FILL. SBK AND RU TO CEMENT. CBU. VERY SMALL AMOUNT METAL OVER SHAKER. HOLE CLEAN. PUMPED 5 BBLS WATER, PT TO LINES TO 3000 PSI, PUMPED 15 BBLS WATER, 30 BBLS CEMENT. POH 12 STANDS. CLOSED RAMS AND SQUEEZED CEMENT. PUMPED DRY JOB, POH. LD 32 JTS DP. FLUSHED OUT STACK. PWR INSTALLED TEST PLUG. CHANGED OUT RAMS. NEW ELEMENTS INSTALLED ON RAMS. DRILLING MW: 9.9 VIS: 52 TESTED BOPE. MU BHA #2. RIH, FLOW CHECKED SPERRY MWD SYSTEM. RIM. PU KELLY AND WASHED DOWN LOOKING F/ C~MENT TOC @ 8075' DRILLED VERY HARD CEMENT F/ 8075-~'~'~)~\---- ORIENTED AND BEGAN KICK OFF. TIME DRILLED/ SLID F/ 8259-8304' SAFELY PAST CASING STUMP. DRILLED F/ 8304-8552'. CBU DRILLED F/ 8552-9370' CBU. MW:10.0 VIS: 52 05/02/94 ( 9) TD: 9981' ( 610) 05/03/94 (10) TD:10294' ( 313) DRILLING MW:10.0 VIS: 52 FINISHED CBU. DROPPED SURVEY AND PUMPED DRY JOB. POH F/ BHA AND NEW BIT. HOLE IN EXCELLENT CONDITION. LD MOTOR, LC, STAB, MU BHA #3. RIH W/ HWDP AND FLOW CHECKED MWD. RIH. PRECAUTIONARY REAMED 80' TO BOTTOM. DRILLED F/ 9371-9981'. BIT IN ZONE 2. LOGGING MW:10.0 VIS: 54 DRILLED F/ 9981-10294'. PUMPED LO-HI VIS SWEEP AND CIRCULATED HOLE CLEAN. SHORT TRIPPED 5 STANDS, RIH, NO DRAG, SHORT TRIPPED TO 9 5/8" CASING 22 STANDS, NORMAL HOLE DRAG. SLIPPED DRILLING LINE. RIH, NO PROBLEMS. CBU. POH F/ LOGS. L/D BHA #3. CLEARED FLOOR. RU AWS W/ CAL/AC/DLL/CN/GR. LOGGING. .Anchomj~ WELL : DS 4-5A OPERATION: RIG : NABORS 2ES PAGE: 3 05/04/94 (11) TD:10294' ( 0) 05/05/94 (12) TD:10294' ( 0) 05/06/94 (13) TD:10294 PB: 0 05/07/94 (14) TD:10294 PB: 0 RIH W/ 7" LINER MW:10.0 VIS: 60 CONTINUED LOGGING. BHCS FAILED, OTHER LOGS OK. POH. LD LOGGING STRIN, PU NEW BHCS AND RIH. RE-LOGGED INTERVAL. POH. RD AWS. MU BHA #4. RIH, NO EXCESS DRAG, WASHED 115' TO BOTTOM, NO FILL. PUMPED LO-VIS SWEEP AND CIRCULATED HOLE CLEAN. PUMP DRY JOB, DROPPED RABBIT. POH. OH IN EXCELLENT CONDITION. LD 45 JTS DP, BHA #4. CLEARED FLOOR. RU NCS. RAN 22 JTS 13CR, 33 JTS L-80 7" 29# LINER, BAKER HMC HANGER, TYPE H PACKER, TIE-BACK EXTENSION. NO PROBLEM W/ 13CR MU. RIH 1 STAND. CIRCULATED LINER VOLUME. RD NCS AND CLEARED FLOOR. RIH W/ LINER ON 4 1/2" DP. RIH MW:10.0 VIS: 80 RIH W/ LINER ON 4 1/2" DP TO 9 5/8" SHOE. CIRCULATE LINER VOLUME. RIH W/ LINER ON 4 1/2" DP. MAKE UP CMT. HEAD. BREAK CIRCULATION. TAG BTM @ 10294'. BATCH MIX CMT. PUMP KCL PREFLUSH. TEST LINES. POH 15 STANDS. CIRCULATE DP VOLUME. BREAK DOWN CMT HEAD. CLEAR FLOOR. PUMP PILL. POH. LAY DOWN RUNNING TOOL. MU 8/12 CLEANOUT ASSY. CUT ANS SLIP LINE. RIH TO 7919' KELLY UP, CIRCULATE DOWN TO TOP OF LINER. NO SIGN OF CMT. POH. LAY DOWN BHA #5. PICK UP 6" CLEAN OUT ASSY AND RIH. PICK UP TAIL ASSY PrW: 8.5 Seawater RIH W/ 6" CLEANOUT ASSEMBLY. KELLY UP, CIRCULATE TO 10200'. TAG CEMENT. CIRCULATE. TEST CSG AND LINER LAP. CLEAN OUT CEMENT F/ 10200-10253'. TAG LDG COLLAR @10253' CIRCULATE, PUMP 50 BBL KCL SPACER, DISPLACE WELL TO INHIBITED SW. TEST CSG AND LINER LAP. LAY DOWN DRILL PIPE & BHA #6. CLEAR FLOOR. RU ATLAS WIRELINE. CHECK AND CLEAN BASKET. LAY DOWN SAME. MAKE UP PACKER RUNNING TOOL, MAKE UP ON PACKER @10044'. POH & RD ATLAS WIRELINE. PULL WB, SET TEST PLUG, CHANGE BTM RAMS TO 5 1/2" AND TEST. PICK UP TAIL ASSY. INSTALL 2-WAY CHECK MW: 8.5 Seawater RUN COMPLETION STRING. 145 JTS 4 1/2" 12.6#, 13 CR, 78 JTS 5 1/2" 17# 13 CR TBG. MAKE UP HGR AND LDG JT. HOOK UP & TEST CONTROL LINES. LAND TBG. RILDS. PRESSURE TBG TO 3000 PSI TO SET PKR. PRESSURE TBG. BLEED TBG PRESSURE. TEST ANNULUS. BLEED OFF TBG PRESSURE. RP VALVE SHEARED. RIG DOWN LINES. LAY DOWN LDG JT. INSTALL 2 WAY CHECK. WELL : DS 4-5A OPERATION: RIG : NABORS 2ES PAGE: 4 05/08/94 (15) TD:10294 PB:10253 RELEASE RIG MW: 8.5 Seawater PRE-NIPPLE DOWN SAFETY MEETING. REMOVE RAMS FROM BODIES. CLEAN OUT BODIES AND GREASE SAME. NIPPLE DOWN CHOKE AND KILL LINES. INSTALL BLIND FLANGES ON BOP SIDE OUT LET FLANGES. NIPPLE DOWN BELL NIPPLE AND ANNULAR PREVENTOR. SEPERATE BOP BODIES. NIPPLE UP TBG HEAD ADAPTER AND TEST. MAKE UP CL AND TEST. NIPPLE UP TREE AND TEST. RIG UP LUBRICATOR AND PULL 2-WAY CHECK VALVE AND SET BPV. FREEZE PROTECT WELL. RIG DOWN LINE, SECURE WELL. RELEASE RIG @2359 HOURS ON 05/07/94. SIGNATURE: (drilling superintendent) DATE: , SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA / PAGE PRUDHOE BAY DRILLING PBU/4-05A 500292010701 OR NORTH SLOPE COMPUTATION DATE: 5/ 5/94 DATE OF SURVEY: 050295 MWD SURVEY JOB NUMBER: AK-MW-40040 KELLY BUSHING ELEV. = 53.26 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8250 7295.00 7241.74 32 2 8519 7517.50 7464.24 36 42 8610 7588.81 7535.55 40 5 8705 7661.05 7607.79 40 54 8800 7731.88 7678.62 42 42 N 56.51 W .00 1465.82N 2438.29W 2334.53 N 39.39 W 3.97 1567.61N 2549.13W 2472.74 N 35.69 W 4.51 1612.45N 2583.50W 2527.71 N 32.90 W 2.08 1663.41N 2618.24W 2588.42 N 28.70 W 3.50 1717.79N 2650.61W 2651.28 8894 7799.15 7745.89 45 54 8987 7863.34 7810.08 46 47 9082 7929.03 7875.77 45 42 9170 7991.09 7937.83 44 35 9263 8057.76 8004.50 43 47 N 27.80 W 3.47 1775.62N 2681.67W 2716.76 N 27.90 W .97 1835.12N 2713.10W 2783.90 N 27.60 W 1.18 1895.84N 2745.05W 2852.39 N 25.70 W 1.98 1951.59N 2773.04W 2914.70 N 26.-00 W .89 2009.94N 2801.31W 2979.51 9354 8123.77 8070.51 43 12 9448 8194.05 8140.79 40 0 9542 8268.21 8214.95 35 47 9630 8341.36 8288.10 31 42 9725 8423.67 8370.41 28 12 N 24.40 W 1.38 2066.61N 2827.98W 3042.13 N 23.90 W 3.42 2123.54N 2853.52W 3104.53 N 23.70 W 4.47 2176.36N 2876.82W 3162.26 N 24.10 W 4.67 2221.05N 2896.62W 3211.14 N 24.80 W 3.70 2264.23N 2916.23W 3258.56 9820 8508.26 8455.00 25 53 9915 8593.96 8540.71 25 12 10010 8680.24 8626.98 24 17 10106 8768.13 8714.87 23 6 10201 8856.02 8802.76 21 30 N 25.80 W 2.47 2303.28N 2934.67W 3301.74 N 24.80 W .87 2340.32N 2952.19W 3342.71 N 23.70 W 1.06 2376.58N 2968.53W 3382.48 N 24.30 W 1.27 2411.83N 2984.22W 3421.06 N 22.30 W 1.86 2444.92N 2998.49W 3457.10 10264 8914.99 8861.73 19 42 N 18.80 W 3.46 10294 8943.23 8889.97 19 42 N 18.80 W .00 2465.66N 3006.29W 3479.21 2475.23N 3009.55W 3489.28 THE CALCULATION PROCEDURES ARE BASED ON THE,USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3896.69 FEET AT NORTH 50 DEG. 33 MIN. WEST AT MD = 10294 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 335.87 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/4-05A 500292010701 NORTH SLOPE COMPUTATION DATE: 5/ 5/94 DATE OF SURVEY: 050295 JOB NUMBER: AK-MW-40040 KELLY BUSHING ELEV. = 53.26 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 8250 7295.00 9250 8048.38 10250 8901.80 10294 8943.23 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7241.74 1465.82 N 2438.29 W 955.00 7995.12 2001.85 N 2797.37 W 1201.62 246.62 8848.54 2461.19 N 3004.77 W 1348.20 146.57 8889.97 2475.23 N 3009.55 W 1350.77 2.58 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/4-05A 500292010701 NORTH SLOPE COMPUTATION DATE: 5/ 5/94 DATE OF SURVEY: 050295 JOB NUMBER: AK-MW-40040 KELLY BUSHING ELEV. = 53.26 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGUI2%R COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 8250 7295.00 7241.74 1465.82 N 2438.29 W 955.00 8319 7353.26 7300.00 1487.62 N 2468.34 W 965.83 8439 7453.26 7400.00 1532.94 N 2518.25 W 986.47 8564 7553.26 7500.00 1589.17 N 2566.21 W 1010.86 10.83 20.64 24.39 8694 7653.26 7600.00 1657.75 N 2614.57 W 1041.44 8829 7753.26 7700.00 1735.43 N 2660.21 W 1076.07 8972 7853.26 7800.00 1825.63 N 2708.08 W 1119.02 9116 7953.26 7900.00 1917.83 N 2756.51 W '1163.41 9256 8053.26 8000.00 2006.06 N 2799.42 W 1203.50 30.58 34.63 42.94 44.39 40.10 9393 8153.26 8100.00 2091.23 N 2839.10 W 1240.74 9523 8253.26 8200.00 2166.30 N 2872.40 W 1270.18 9643 8353.26 8300.00 2227.66 N 2899.58 W 1290.67 9758 8453.26 8400.00 2278.63 N 2922.88 W 1305.32 9870 8553.26 8500.00 2322.94 N 2944.15 W 1316.75 37.23 29.45 20.48 14.65 11.43 9980 8653.26 8600.00 2365.43 N 2963.63 W 1327.14 10089 8753.26 8700.00 2406.05 N 2981.61 W 1336.57 10198 8853.26 8800.00 2443.92 N 2998.08 W 1344.77 10294 8943.23 8889.97 2475.23 N 3009.55 W 1350.77 10.39 9.43 8.20 6.00 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska, Inc. Date: Subject' From/Location' Telephone: To/Location: P.O. Box 100360.- .... nchorage, AK May 24, 1994 Transmittal #: 94043 ARCO Static Pressure Surveys John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 99510,~ ~lk, Well i Log Date i Tool Type . Number! (M-D-Y) ! 2-6 [ 03-03-94 i Static Pressure 3-32A i 05-13-94 4-5A i 05-18-94 6-16 i 05'13'94i Run, Sca~e 16-24 ,i i Static Pressure ,. ., 1 5" Contractor Sch Sch Static Pressure 1 5" Sch Static Pressure 1 5" Sch Static Pressure 1 5" Sch 1 5" 1 5" 1 5" 1 5" 1 5" : 1 5" 1 5" 11-24A 4 03-06-94 ! Static Pressure ;Z. toq ! 16-15, 04-01-94 ! Static Pressure Sch 2. ¢-2% i 16-20 .~i 03-23-94 ! Static Pressure Sch 03-24-94 6-25 ,i 03-24-94 t Static Pressure 17-09/,." 03-24-94 i Static Pressure 7-05 ~ 03-23-94 ! Static Pressure Sch Sch I Sch I Sch Number of Records: 11 John E. DeGrey Distribution- Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil D & M Please acknov~ledge receipt by signing and returning a copy of transmittal. ARCO Alaska, Inc. Is a Subsidiary of Aflan~cRIchfletdCompa~y ARCO Alaska, Inc. Date' May 24, 1994 P.O. Box 100360, borage, AK Transmittal #: 94040 99510,~ ~, Subject: ARCO Cased Hole Finals From/Location: Telephone: To/Location: John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well Number OWDW- SW Log Date (M-D-Y) 4-29-94 1-9A 5-14-94 1-20 5-7-94 Tool Type ' v//, PITS ",," ,/Perf Rec ¢'l Perf Rec Run, ScaJe 2-4 5-11-94 v/ Prod Prof 1, 5" 2-4 5-11-94 ,,,/' CNL : 1, 5" 2-5 5-7-94 5-7-94 5-8-94 2-5 Prod Prof 2-18 2-20 2-20 4-30-94 vx CNL ¢'" Prod Prof ,.//Prod Prof CNL 5-13-94 J,,/ v'~. Bridge Plug ,,/. Bridge Plucj vUSIT (Cern & Corr) ,,," Perf Rec 4-4-94 5-3-94 5-9-94 ~ USIT 3-19 Contractor SCH SCH SCH SCH SCH SCH SCH 1 5" : 1 5" : I 5" ; I 5" 1 5" :' 15" i 1 5" 1 5" 3-29 3-32A 3-32A 4-5A 4-5A 5-6 5-35 6-10 6-11 6-22A SCH SCH SCH SCH SCH SCH 5-12-94 SCH 5-17-944 v" Perf Rec SCH 5-17-94 ~ SCH ,/ Prod Prof ,/ TDT-P v/ Leak Detect 1, 5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1 5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1, 5" SCH 1, 1" 2" 5" SCH 4-30-94 5-3-94 4-5-94 7-3 7-3 7-23 7-23 9-13 9-26 4-6-94 9-42 5-15-94 9-47 5-16-94 11-36 5-18-94 ~. 12-8B 5-14-94 '¢,-Packer Set Rec 5-14-94 ,/' Perf Rec 5-8-94 Prod Prof 5-7-04 Perf Rec 5-10-94 Set Rec 5-15-94 Rec 5-16-94 Perf Rec Leak Detect Packer Set Rec 1, 5" SCH USIT i 1, 5" SCH 5-4-94 ,/' Prod Prof ,.. 13-8 ! 13-31 i 13-35 14-7 14-15 14-41 ' '16-26 1, 1" 5" SCH 1, 5" SCH 1 5" SCH SCH 1 1 5" I 5" 1 5" 1 5" 1 5" I 5" ii (~ tt 5-2-94 v 5-2-94 5-10-94 5-13-94 ~Tubin~ Patch Rec 5-17-94 ? CNL 5-8-94 t/Dual Burst TDT-P 5-6-94 1~" Perf Rec 17-19 5-12-94 k/" Perf Rec ! 18-1 5-1~v,/ Perf Rec o1 At~an~cl:Uchflel~ SCH SCH SCH SCH SCH SCH ARCO Alaska, Inc. Date: Subject' From/Location- Telephone' To/Location: P.O. Box 100360, A May 24, 1994 Transmittal #: ARCO open hole Magnetic tape(s) John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94041 orage, AK 9951O ~5 iql Well Number 01-09A 03-32A 4-5A . 34APH 11-04A ! 11-35 ! 11-36 12-13A 15-09A · -34 8-23A Log Date i Tape Type (M-D-Y)I 03-17-94 i ..,DLL/CN/GR/AC/ ]" GR 05-01-94 i AC/GE & DEL/CE/ Iv" GE 05-03-94 i AC/GE & DEL/CE/ !v" 4CAL/GR 03-06-94 ] D~UACICNIGR 03-01-94 i,/DLL/ZDUCN/GR 5-19-94 ! '/ ZDL/CN 05-08-94 ~DIFL/ZDL/CN/GR 03-31-94i D~LL/AC/CN/G R ,, Run, Footage 11786- 12637 9200-9654 8250- 10292 9120- 11658 8410-9341 8670-9471 9300-9969 8607- 1O38O 03-30-93i ¢' MWD/GR i 1 9971- ~ ! 8767 Contractor Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Sch ! 05-16-94 Sch i ,/D~.L/ZDL/CN/G Ri 10560- ] ! 11282 03-06-93 ] ,/ MWD/GR i1' 9635'7999 Sch Number of Records: 11 John E. DeGrey Distribution: Bob Ocanas Phillips BPX Exxon Please acknowledge receipt by signing and returning a copy of transmittal. By: ,... ..... Date: Q. '.,- , f' ~-],-~ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Ir1¢. is a Subsidiary of At/anticRlchfleldCompeny ARCO Alaska, Inc. Date: Subject' From/Location: Telephone: To/Location- P.O. Box 100360, /~--"-chorage, AK May 23, 1994 Transmittal #: ARCO Open Hole Finals John E. DeGre¥/ATO-1529 (907) 263-4310 94038 Distribution 99510~ ~. Well i Log Datei Tool Type Number i (M-D-Y) 1-10 ' 05-10-94 i~/~ CoilarLog 3-19 i04-24-94!v/, Coilarbocj 3-24 i 05-10-94t,,[,,- CollarLog 3-~ ~ 05-01-94 iV'Dual Laterolocj \i 3-32A i 05-01-94 iv/. BHCA/GR ~ 05-01-94 iv" CNL/GR 3-32A ~ : 3-32A,! 05-01-941v/' SSTVD 4-5A [ 5-5-94 4-5A ! 5-3-94 i 4-5A i 5-3-94 4-5A i 5-3-94 4-5A i 5-3-94 4-5A i 5-3-94 11-29 i 04-27-94 11-29 i04-27-94 11-36 ~05-08-94 11-30 5-8-94 11-36 I5-8-94 11-36 i05-08-94 15-32 I03-25-94 ; I04-25-94 Run, Scale 1,5" 1,5" ! 5II 1, 2"&5" 15-32 15-32 04-25-94 15-32 03-35-94 15-32 15-33 15-33 17-19 * Includes diskette Number of Records: 27 1, 2"&5" 1, 2"&5" ! 1 "&2"&5" iV' PFC/GR/Coilor 1, 5" iv" SSTVD 1, 1"&2" i v' Borehole Prof ARCO Alasl(a, Inc. Is a ,Sui:~ldlar~ of A~tlcRlchfleldCompany ,/~ CNL/GR ,,/Dual Lateroiocj ¢' BHCA/GR j~IWD:TVD/GRC, .v' EWR,FXE v, MWD:MD/GRC, EWR,FXE 1, 2"&5" 1, 2"&5" 1, 2"&5" 1, 2°'&5'' 1, 2"&5" 1, 2"&5" /Borehole Prof 1, 2" v" SSTVD i,/ DIFL/GR/SP 1¢ 2"&5" 1, 2"&5" ' 1, 2"&5" v.MWD:~D/DGR, 2"&5" CNP,DSFD. !1'13' I./MWD:MD/DGR, i 1-13, 2"&5" · ' EWR~FXE v,MWD:TVD/DGR, 1-13, 2"&5" EWR,FXE 05-04-94 05 -04-94 03-29-94 ~ 04-01-94 ,/ 1-13, 2"&5" CNP, DSFD Section Section ': 1-13, 2"&5" MWD:MD/DGR 1-20, 2"&5" Collar Log i 1, 5" Contractor Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Sperry Sperry Atlas Atlas Atlas Atlas Sperry Sperry Sperry Sperry Sperry Sperry Sperry , Atlas Alaska oi/4.Gas Con.~ .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI~,,~ Sus~nd O~rafion Shutdown Re-enter sus~nded well 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Alter casing __ Repair well __ Plugging __ Change approved program x Pull tubing __ 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 742' SNL, 420' WEL, SEC. 34, T11N, R15E At top of productive interval 1765'NSL, 3400' WEL, SEC. 27, T11N, R15E At effective depth N/A At total depth 1865' NSL, 3420' WEL, SEC. 27, T11N, R15E 12. Present well condition summary Total depth: measured true vertical Effective depth' measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) feet feet feet feet Packers and SSSV (type and measured depth) Description summary of proposal X 13. Attachments 14. Estimated date for commencing operation 2/15/94 Time extension Oil X Gas Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Drilling Engineer Supervisor · FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Location clearance__ Mechanical Integrity Test__ Subsequent form required 10- Original S~gned ~y Approved by order of the Commission J'Ja_vid t~/. JehnstoI1 , Form 10-403 Rev 06/15/88 16. If proposal was verbally approved Name of approver 5. Type of Well: Development x Exploratory __ Stratigraphic__ Service Stimulate Other True vertical depth BOP sketch Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) kbe = 68.3 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 4 -5A 9. Permit number 93-186 10. APl number 50~ 029-20107-01 11. Field/Pool Prudhoe Bay Field/Oil Pool Date approved Size Cemented Measured depth RECEIVED JAN ---? 1994 0il & Gas Cons. Commission Anchorage Detailed operations program__ 15. Status of well classification as: Suspended~ J Approval No.~/.,_~ ~ Approved Copy, Returned Commissioner Date SUBMIT IN TRIPLICATE Vadance Perforate ~.S4-5A SUNDRY CHANG~ Directional plan #3 has changed from the approved sundry. The target depth and location are unchanged, but the kickoff point has been moved up hole to acheive a lower well bore angle through the target interval. The kickoff point is now 760' MD (674' vertical) higher. RECEIVED JAN "7 t994 0il & Gas Cons. Corrlmissior: Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION December 3, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 27t~7542 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re .' Prudhoe Bay Unit DS 4-05A ARCO Alaska, Inc. Permit No: 93-186 Sur. Loc. 742'SNL, 420'WEL, Sec. 34, TllN, R15E, UM Btmhole Loc. 1865'NSL, 3420'WEL, Sec. 27, TllN, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to redrill the above referenced well. The permi~ to redrill 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Si Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill[[]llb. Type of welI. ExploratoryF'] Stratigraphic Testl-I Development Oil[] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 68.3 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pooi P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28325 4. Location of well at surface 7. Unit or property Name ,11. Type Bond(se,, 2o ^^c 25.o25 742' SNL, 420' WEL, SEC. 34, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1765' NSL, 3400' WEL, SEC. 27, T11N, R15E 4-05A U-630610 At total depth 9. Approximate spud date Amount 1865'NSL, 3420' WEL, SEC. 27, T11N, R15E 1/10/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa,dTVD) property line ADL 28324-3420' feet No close approach feet 2560 10360' MD/8852' TVD feet 16. To be completed for deviated wells :17. Anticipated pressure (see 2o ^AC 25.o35 (e)(2)) Kickoff depth 90~o feet Maximum hole angle~6.25 o Maximum surface 3330 psig At total depth (TVD) ~800'/4390 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# 13CR80 NSCT 1650' 8860' 7834' 10510' 8935' 300 sx Class "G" FC t"~ .E'i ....~ 1~. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary i!','-i'?' '4 f'~ 'i.. '. Total depth: measured 10137 feet Plugs (measured) true vertical 8990 feet Effective depth: measured 10002 feet Junk (measured) '- ......... true vertical 8870 feet Casing Length Size Cemented Measured depth True Vertical depth Structural 113' 30" 237sx Fondu neat 113' 113' Conductor 971' 20" 9~5¢x~'F/~,~Fo~u 971' 971' Surface 2711' 13-3/8" 1100 sx PF fl 2711' 2711' Intermediate Pro d u c ti o n 10124' 9 -5/8" ~o ¢x .~'/2~ ~x PF , 10124' 8979' Liner Perforation depth: measured 9911'-9927', 9933'-9937', 9939'-9946', 9955'-9972' true vertical 8789'-8803', 8808'-8812', 8814'-8820', 8828'-8844' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drillin~l fluid pro~]ram [] Time vs depth plot [] Refraction analysis l-I Seabed report[-] 20 AAC 25.050 requirementsl-] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~/,~/,,.~~ T itle Drilling Engineer Supervisor ////-'~'~ '~ Date Commission Use Only L Number IAPI number Approval date See cover letter Permi~,,.~_//~/, 150-02_?-..~--0/0~-~::~ ~' /C~---',_~----~'-~ for other requrements Conditions of approval Samples required [] Yes '1~ No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BOPE 1-12M; E]3M; 1~5M; FllOM; F'115M; by order of Other:Approved by fim~irl0riginalw Signed~,, ~,,,,,+,-,,.,BY Commissioner tne commlssio n Date/ Form 10-401 Rev. Submit in triplicate I Well Name: IDS 4-05 A Redrill Plan Summary Type of Redrill (producer or, injector)' I Producer lSurface Location: Target Location: Bottom Hole Location: 4537 FSL 420 FEL S34 T11N R15E UM 1765 FSL 3400 FEL S27 T11N R15E UM 1987 FSL 3444 FEL S27 T11N R15E UM I AFE Number: ! I l,Rig: I Doyon #16 I I Estimated Start Date: I Jan 1994 I I'~perating days to complete: I 16 I uD: I10510 I [TVD: 188' 'ss I !KBE: 168-30 ! Well Design (conventional, slimhole, etc.)' } conventional ] Objective: [ TO RETURN THE ROMEO INTERVALS TO LOW GOR PRODUCTION Mud Program: A 9.5 - 10.00 ppg Biozan/KC1 water based mud will be used. ISpecial design considerations Inone Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.0 18 30 15 30 6 0 8 tO tO tO tO tO tO tO tO tO TD' 10.0 18 30 15 30 6 0 8 Directional: I KOP: 19010 MD Maximum Hole Angle: ] 56.25 DEGREES Close Approach Well: I NONE Casing/Tubin,,; Program: Hole Size Wt/Ft Hole Siz{~ Csg/ " Wt/Ft' Grade Conn Length' Top Bt'm Tbg O.D. MD/TVD MD/TVD 8.5" 7" 29# 13cr80 NSCT 1650 8860/7834 10510/8935 4.5" 12.6g 13cr80 NSCT 640 8860-7834 9500/8364 5.5" 17# 13cr80 NSCT 8860 SURFACE 8860/7834 Cement Calculations: I Liner Size' 17" ! Basis:[ Total Cement Volume: SHOE JT PLUS 20% EXTR.& iDVER OH CALIPER @ 300 SKS CLASS 'G' PLUS 7" x 9-5/8" LINER LAP + 100' ON TOP OF LINER INSIDE OF 9-5/8 W/O DRILL PIPE. , Liner Size: [N/A I Basis:[ Total Cement Volume: N/A , Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and mud fluid system schematics on file with AOGCC. ~"- ....... PRUDHOE BAY DRTLL~G"--~'ROUp'-- '----: BKB SECTN INCLN 7969 2i79 25.12 Anadrj ] ] Schlumberger DSO4-O5A (P2) , VE~RTICAL ,..SE.C.,T. ION VIEW Marker Identil 5cation HD Al IIE-IN/KOP 9010 B) E~O 6.00/i00 CUI~VE 9662 8464 C) IAFIGE1 1023~ B784 D) fO ~0510 8935 2572 56.25 3051 56.25 3277 56.25 SBction at: 3,18.56 TVD Sca]e.' I inch = 300 fee[ Dep Sca]e.' t' inch = 300 feet Drawn ' :11/23/93 -~:~-I .......... I - " ......... ! , - ~~ ~,,: .... ~ ~ ........... .q ........................... , ............ ===================== 'z~[ ~? ~c~tD - ~ ~[~ .... F ................. ¢ q~ ......... ~ ' . -~,~¢EwqE:- ~ .......... ~ .............. ............. 1 ............. .... ~ .. { ~ 1400 J550 1700 1850 2000 2150 2300 2450 2600 2750 2900 3050 3200 3350 3500 3650 3600 3950 4J~ Sect ion Departure I.~na¢r't]i k193 o4o5~2 81.5,3 ti:.~3 I~R ~) PRUDHOE BAY , , DSO4-OBA (P2) PLAN VZEN CLOSURE ..... : 4078 feet at Azimuth 3i2.04 DECLINATION.: 30.1JO E SCALE ....... : ! inch = 300 feel DRAWN ....... : ll/23/93 30CC 2850 , DRILLING GROUP , Marker ~d~ntif~catton ND N/S A) TIE-iN/KOP ~010 t672 B) END 6.00/200 CURVE 9662 2040 C) TARGET ~0238 2509 D) TO 10510 2731 E/W 272~ 2889 2984 3028 ,. ~7oo---t ;: !1- :1 ,:'1 ?;~o, ! i ~ I ,, . .=, , · , . .... ~,500' ' ! '" i ' ",. t2~0 ............... x.; ._ I'-. I , :. 1200 I '.~ , .... , . . ., 1050 ' ' @900 3750 3600 3450 ~300 3t50 3000 2850 2700 2550 2400 22.50 2100 1950 1 SOO <- W~ST . · --, .. ;-. .... . - .- . . . TOTRL P. DS 4-05A AFE INFORMATION Objective: The objective of this sidetrack is to return the Romeo intervals to Iow gor production. The Upper Romeo is jetting gas through leaking perforations and the Lower Romeo is producing through the liner hole. OH logs will indentify the Lower Romeo target and any remaining potential in the Upper Romeo. Upside potential is possible targets in the Victor and Tango. Scope: 1. P & A original wellbore as per State regulations 2. Cut and pull existing 7"x 5.5" tubing string. 3. P/U 5" DP and RIH w/dual 9-5/8" csg scrappers and wireline gauge ring, RIH set Baker WD-1 Whipstock packer. 4. RIH set whipstock - mill window. 5. Directionaly drill 8-1/2" production hole to TD. 6. Obtain open hole logs. 7. Run 7" 13CR80 liner and new 5.5" x 4.5" completion string w/GLM's. 8. Perforate with wireline after rig moves off the well. Timing: Doyon #16 will be making a pad to pad move from DS 14 to DS 4-5A in the early part of January 1994. DS 4-05A PRE-RIGWORK/WHIPSTOCK / DRILLING SUMMARY PROCEDURES: 1. Pre-rig work: Kill well. Lay cement plug across perforations. Cut 7"x 5-1/2" tubing @ 9235' md. (+/- 20' above packer assembly. 2. MIRU workover rig. 3. Pull BPV. Circulate out freeze protection fluid. 4. Set BPV. ND tree. 5. NU BOP's. Install tree test plug. Test BOP's to 5000 psi. BPV. 6. Pull and lay down 7" x 5-1/2" 17# L80 tubing. November Pull tree test plug and 24, 6a. Replace tbg head and 9-5/8 packoff. . , . 10. 11. i2. P/U 5" 19.5# class "G" drillpipe w/ 9-5/8" 47# casing scraper w/3 junk baskets. RIH to whipstock setting depth of @ 9000'm~l. Reverse circulate csg. x dp annulus with a minimum of 2 annular volumes. Report any wellbore debris observed across shaker screens. If seems neccessary, make 8.5" GRJB run on e-line prior to step #8. (in the past we had problems getting 8.5" OD to go past FO's, so it may be a good idea to RIH with a smaller ID. Packer OD is 8-1/8" ) RIH on E-line with a 9-5/8" Baker model "DW-I" packer- postion / set this packer @ 9010' md - POOH. RIH w/Gyrodata Gyro orientation survey. Obtain survey to determine packer alignment key position relative to borehole high side. POOH. Perform "timing" operations on Baker "W-2" Anchor latch/whipstock assembly to ensure proper orientation to BHL. Bakerlock and tack weld whipstock and anchor connection. RIH w/starting mill/whipstock/anchor assembly. Locate into DW-1 9-5/8" 47# packer. Slack off +/- 6,000 lbs to engage anchor latch into DW-1 packer. P/U +/- 35,000 lbs above string wt. to shear carriage bolt from starting mill. Displace well to KCL milling/drilling fluid. Mill 1.5' to 3.0' with 9-5/8" starting mill. POOH. P/U window/watermelon milling assembly - RIH and mill +/- 10-15' md of open hole - Circulate and condition open hole prior to POOH. 13. 14. 15. P/U 8-1/2" bit w/ 6-1/4" Directional/MWD collars and drill off of the whipstock using toolface/inclination as the principal directional guides. Align with target quadrant. Slide w/6-1/4" GLDD PDM until all stabilizers are past the whipstock assembly. Do not rotate stabilizers across the whipstock assembly. Drill with a 8-1/2 ,, directional assembly to total depth of 150' MD below the BOTTOM OF THE SADLEROOHIT. (Est bottom of sadlerochit is @ 8788' TVDss) Multi-Shot survey w/Sperry-Sun on final trip out of the hole for AOGCC survey requirements will not be needed because this is a Twin. RU Atlas wireline and log with the triple combo (GR/Res./BHCS/CNL/4-Arm Caliper). Upon completion of logging make wiper trip prior to running 7" liner. (Note' Use four arm caliper to calculate your cement volumes) November 24, ,, ~, .~, .., 1993 16. 17. 18. 19. 20. 21. 22. 23. 24. Run 7" 29# 13(~R80 NSCC standard liner assembly to TD with liner top packer and +/- 150' lap. XO to 7" 29# L80 liner +/- 300' md above Sadlerochit top @ 9350'md. Liner top packer and hanger assembly are t¢ be plain 4140 grade carbon steel. The placement of marker joint will be determined after the OH logs are completed. Cement liner calculating cement volume by using information obtained from 4-Arm caliper run while logging. L/D extra 5" DP - that will not be required for clean out run. Use 25% excess over caliper volume for open hole. Clean out liner to PBTD and test to 3500 psi. Change over to clean inhibited seawater. RIH with 5-1/2" 17# x 4-1/2" 12.6# I~(~RLS0 NSCT completion string w/7" packer positioned +/- 200' md above top of Sadlerochit. GLM spaceout MD will be sent under the separate cover as soon as they are obtained from production eng.'Sad/erochit top is estimated @ 8400 tvd.. Reference DS 4- 05A completion cli¢[grc, m in Well PIc[n attachments ie. geosciq~n~e prognosis form for more exact fCrmati¢n M/U tubing hanger- test SSSV lines to 5000 psi for 10 mins. Odent SSSV balance line towards reserve pit. Land tubing hanger and RILDS. Test tubing hanger packoff to 5000 psi. Back out & L/D the landing joint. Set blanking plug. N/D BOPE. N/U tubing head adaptor and 6" tree. Test control lines to 5000 psi. Test 6" tree and adaptor to 5000 psi. Pull the test plug with a lubricator. Pressure up on the 5-1/2" 17# x 4-1/2" 12.6# 13CR80 tubing to 4000 psi to set the production straddle packer. Maintain tubing pressure at 4000 psi for 30 minutes after setting packer and record as the tubing test. Bleed off 5-1/2" x 4-1/2" tubing pressure to +/- 1500 psi. Pressure test tubing x 9-5/8" annulus to 3500 psi for 30 minutes. Record the test on a Barton chart. Bleed off the annular pressure prior to bleeding off the tubing pressure. Bleed off the tubing preSsure. Pressure up to 2900 psi on the annulus to shear out the RP valve in the top GLM position. Displace the tubing w/enough diesel to freeze protect the annulus to 2000'. Allow the diesel to U-tube to the tubing. If possible have the well freeze protected by gas by the PE's in the WOA or DSM in the EOA. November 24, 1993 .... STATE OF ALASKA Al_f. .-~ OIL AND GAS CONSERVATION COMMIS$, APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend__ Operation Shutdown ~ Re-enter suspended well~ Alter casing ~ Repair well~ Plugging x Time extension ~ Stimulate ~ Change approved program ~ Pull tubing Variance__ Perforate ~ Other x __ Plugback for redrlll 2. Name of Operator ARCO Alaska,/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 742'SNL, 1914' WEL, SEC. 34, T11N, R15E At top of productive interval 1439' NSL, 1914' EWL, SEC. 27, T11N, R15E At effective depth 1582'NSL, 1782'EWL, SEC. 27, TllN, R15E At total depth 1625' NSL, 1740' EWL, SEC. 27, T11N, R15E 6. Datum elevation (DF or KB) feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 4-5 9. Permit number 71-25 10. APl number 50- 029-20107 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 113' Conductor 971' Surface 2711' Intermediate Production 10124' Liner Perforation depth: 10137 feet Plugs (measured) 8990 feet 10002 feet Junk (measured) 8870 feet Size Cemented Measured depth 30" 237 sx Fondu neat 113' 20" 935 SX PF Ii/190 SX Fondu 971' 13-3/8" 1100 SX PF II 2711' 9-5/8" 800 sx "G"/350 sx PF II 10124' measured 9911'-9927', 9933'-9937; 9939'-9946', 9955'-9972' True vertical depth 113' 971' 2711' 8979' RECEIVEr true vertical 878g'-8803', 8808'-8812', 8814'-8820', 8828'-8844' , ~ fl; · , ~ ~.',i & 6as Con.~. C:~,.. ........ Tubing (size, grade, and measured depth) Packers and SSSV (ty~ and measur~ depth) AVA "PPB"Packer~ 9250'MD; Camco SSSV~ 2200'MD 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 12/10/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended __ Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signed Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity X. BOP Test Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ~/~ 7' Original Signed By Approved by order of the Commissic~avid W. ,iohnstnn Form 10-403 Rev 06/15/88 IApproval No. Approved Copy Returned on~missioner · Date ( SUBMIT ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 1 ) Fee ~ ~//~ (3) Admin (4) Casg (5) BOPE [ c}' thru [10 & 13] [14 thru 22'] [23 thru Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. T 3. Is well located proper distance from property line ................... 4' Is well located proper distance from other wells ..................... 5. Is sufficient undo. dicated acreage available in this pool ............. 6. Is well to be deviated & is we]lbore plat included ................... ~ .. 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease nLrnber appropriate .......................................... 13. Does well have a unique name & nLrnber ................................ 14. Is conductor string provided ......................................... 15. Wil to 6. Is 7. Wil 8. 9. Wil 0. Is 1. Is 2. Is 3. Is 4. 5. 6. 7. 8. Lease & Well NO 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. I enough cement used to circulate on conductor & surface ............ I 1 cement tie in surface & intermediate or production strings ...... I ] cement cover all known productive horizons ..................... I 1 all casing give adequate safety in collapse, tension, and burst. 2 well to be kicked off from an existing wellbore .............. 2 old wel ]bore abandonment procedure included on 1~]~ 2 adequate wellbore separation proposed ................ 2 a diverter system required ........................................ 2 Is drilling fluid program schematic & list of equipment adequate ..... 2 Are necessary diagrams & descriptions of diverter & BOPE attached .... 2 Does BOPE have sufficient pressure rating -- test to ~-E~C) psig ..... 2 Does choke manifold comply w/API RP-53 (May 84) ..... - ............... 2 Is presence of H2S gas probable ...................................... REMARKS geology' engineering: RP ~ .B_E~ JDPL, TAB ~ ~1~-I.1~$ rev 6/93 ~,,,jo/6.011 FOR EXPLORATORY $ STP, ATIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... 32. Name and phone nLrnber of contact to supply weekly progress data ...... 33. Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA SHORE Add i t i ona 1 remarks' MERIDIAN' UM 2~ SM WELL TYPE' Exp~(,[~ Redril] ~ Inj Rev -rz ~-'~0 ~o-.I 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. dAi"l~.o 4 1997 * ~S~ COMPUTING CENTER . ****************************** . ....... SCHL~BERGER . ............................ ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : D.S. 4 - 0SA FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292010701 REFERENCE NO : 97003 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE · 97/01/23 ORIGIN : FLIC REEL NAME : 97003 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-05A, API# 50-029-20107-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/01/23 ORIGIN : FLIC TAPE NAME : 97003 CONTINUATION # : 1 PREVIOUS TAPE CO~4~4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-05A, API# 50-029-20107-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 4-05A API ~ER: 500292010701 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 23 - JAN- 97 JOB ~BER: 97003 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: K. NEUPERT SURFACE LOCATION SECTION: 34 TOWNSHIP: 1 IN RANGE: 15E FNL: 742 FSL: FEL: 420 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 60.40 DERRICK FLOOR: 59. O0 GROUND LEVEL: 29.50 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 7.000 10294.0 29.00 5.500 3092.0 17.00 4.500 9617.0 12.60 4.500 10058.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NI]M~ER : PASS NUMBER: DATE LOGGED: 5-MAR-94 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 10145.0 10144.5 10128.0 10126.5 10106.5 10105.0 10101.5 10076.0 10063.5 10061.5 10056.5 10047.0 10045.0 10044.0 10032.5 10030.5 10014.0 10011.0 9999.0 9998.0 9995.5 9991.5 9990.0 9979.5 9941.5 9916.5 9900.5 9877 5 9844 5 9838 5 9832 0 9827 0 9797 0 9790.5 9783.0 9781.5 9771.0 9762.5 9760.5 9747.5 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH NPHI .............. 88888.5 88888.0 10145.0 10127.5 10105.5 10076.5 10057.0 10046.0 10042.0 10031.5 10012.0 9998.5 9990.5 9980.5 9942.0 9917.0 9901.5 9877.5 9845.5 9832.5 9797.0 9783.0 9763.0 9761.0 9748.0 100.5 10145.0 10127.5 10106.0 10102.0 10063.5 10060.5 10057.0 10046.5 10032.5 10014.5 9999.0 9994.0 9990.5 9838.5 9828. 0 9789.5 9781. 0 9772. 0 101. 0 REMARKS: The depth adjustments shown above reflect cased hole GR PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 to open hole GR and cased hole NPHI to open hole GR. All other CNTG curves were carried with the NPHI shifts. $ $ PAGE: **** FILE H~ER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE 1VIIM~ER : 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ND?4BER : 1 DEPTH INCREMENT: O . 5000 FILE SU~94ARY LDWG TOOL CODE START DEPTH STOP DEPTH CNTG 10162.0 9740.0 GRCH 10150.0 9740.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NIIMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... CNTG GRCH .............. REMARKS: This file contains CNTG Pass #1. shifts were applied to this data. $ LIS FORMAT DATA No pass to pass LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: ** 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 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 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 553982 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 553982 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 553982 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 553982 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 553982 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 553982 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 553982 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 553982 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 553982 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 553982 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 553982 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 553982 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 553982 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 553982 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 553982 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 553982 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 553982 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10268.500 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NP~T. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: GR. BCS 128. 050 DEPT. 10200.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 GR.BCS 143.560 DEPT. 10000.000 NPHI.CNTG 19.952 ENPH. CNTG NRAT. CNTG 2.413 CRAT. CNTG 2.479 ENRA.CNTG FCNT. CNTG 839.750 CNTC. CNTG 2220.000 CFTC. CNTG CFEC. CNTG 782.813 GRCH. CNTG 49.773 TENS.CNTG GR.BCS 93.690 DEPT. 9800.000 NPHI.CNTG 21.240 ENPH. CNTG NRAT. CNTG 2.604 CP~T. CNTG 2.563 ENRA.CNTG FCNT. CNTG 931.500 CNTC. CNTG 2440.250 CFTC. CNTG CFEC. CNTG 773.125 GRCH. CNTG 48.359 TENS. CNTG GR.BCS 90.900 23.285 3.932 884.500 3357.125 23.219 3.925 992.125 3168.188 DEPT. 9700.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 GR.BCS 293.170 CPHI CNTG NCNT. CNTG CNEC. CNTG CCL CNTG CPHI CNTG NCNT. CNTG CNEC. CNTG CCL CNTG CPHI CNTG NCNT. CNTG CNEC. CNTG CCL CNTG CPHI CNTG NCNT. CNTG CNEC. CNTG CCL.CNTG -999.250 -999.250 -999.250 -999.250 21.625 2427.000 3078.125 -0.016 20.886 2431.500 3034.375 0.120 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE ·FLIC VERSION .O01CO1 DATE · 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE · 97/02/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CNTG 10161 . 0 9739.0 GRCH 10150.0 9739.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 10148.5 10144.5 10140.5 10136.5 10132.5 10128.5 10124.5 10116.5 10108.5 10076.5 10072.5 10068.5 10064.5 10060.5 10056.5 10052.5 10048.5 10044.5 10040.5 10036.5 10032.5 10028.5 10020.5 10016.5 10012.5 10008.5 10000.5 9996.5 9992.5 9988.5 9984.5 9980.5 9976.5 9972.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... CNTG GRCH .............. 88888.5 88888.0 10137.0 10073 0 10068 5 10064 5 10060 0 10056 5 10052 0 10047 0 10043.0 10040.5 10035.0 10031.5 10029.0 10021.0 10017.5 10013.0 9993.0 9988.5 9985.0 9981.0 9977.5 10148.5 10144.5 10140.0 10132 0 10127 5 10124 0 10116 0 10108 5 10076 5 10072 0 10056.0 10053.0 10048.0 10044.0 10041.0 10036.5 10020.5 10017.0 10013.0 10008.5 10000.5 9996.0 9988.0 9983.0 9975.0 9970.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 9968.5 9964.5 9960.5 9956.5 9952.5 9936.5 9932.5 9928.5 9920.5 9916.5 9912.5 9908.5 9904.5 9896.5 9892.5 9888.5 9884.5 9868.5 9864 5 9860 5 9852 5 9848 5 9844 5 9840 5 9832 5 9828 5 9824 5 9820 5 9816 5 9812 5 9808 5 9804 5 9800 5 9796.5 9792.5 9784.5 9780.5 9776.5 9772.5 9768.5 9764.5 100.0 9956.0 9952.5 9908.5 9905.0 9869.0 9864.5 9861.0 9853.0 9849.5 9845.5 9841.0 9833.0 9828.5 9824.5 9821.0 9817.0 9812.5 9808.0 9804.5 9780.5 9775.5 9772.5 100.0 9967.5 9963.0 9959.0 9955.5 9935.5 9932.0 9927.5 9919.5 9916.0 9911.5 9895.5 9892.0 9887.5 9884.0 9852.0 9848.5 9832.5 9829.5 9825.0 9813.0 9808.5 9804.0 9800.5 9796.0 9791.5 9783.5 9780.0 9775.5 9773.0 9768.5 9765.0 100.5 REMARKS: This file contains CNTG Pass #2. The depth shifts shown above relect GRCH pass #2 to GRCH pass #1 and NPHI pass #2 to NPHI pass #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 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 553982 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 553982 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 553982 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 553982 O0 000 O0 0 2 1 1 4 68 0000000000 NR~T CNTG 553982 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 553982 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 553982 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 553982 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 553982 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 553982 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 553982 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 553982 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 553982 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 553982 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 553982 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 553982 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10161.000 NPHI. CNTG 28.842 ENPH. CNTG 28.691 CPHI.CNTG NRAT. CNTG 3.013 CRAT. CNTG 2.985 ENRA.CNTG 4.525 NCNT. CNTG FCNT. CNTG 614.087 CNTC. CNTG 1857.448 CFTC. CNTG 644.402 CNEC. CNTG CFEC. CNTG 616.138 GRCH. CNTG -999.250 TENS.CNTG 3250.000 CCL.CNTG 27. 072 1892. 992 2787. 869 O. 054 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: DEPT. 10000. 000 NPHI. CNTG 22. 026 ENPH. CNTG NRAT. CNTG 2.560 CRA T. CNTG 2.611 ENRA. CNTG FCNT. CNTG 839. 000 CNTC. CNTG 2236. 188 CFTC. CNTG CFEC. CNTG 807. 125 GRCH. CNTG 50. 375 TENS. CNTG DEPT. 9800.000 NPHI.CNTG 23.391 ENPH. CNTG NRAT. CNTG 2.950 CRAT. CNTG 2.686 ENRA.CNTG FCNT. CNTG 986.750 CNTC. CNTG 2540.438 CFTC. CNTG CFEC. CNTG 792.875 GRCH. CNTG 51.938 TENS.CNTG DEPT. 9739.000 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 127.250 TENS.CNTG 22.270 CPHI.CNTG 3.816 NCNT. CNTG 868.813 CNEC. CNTG 3227.219 CCL.CNTG 22.647 CPHI.CNTG 3.859 NCNT. CNTG 998.875 CNEC. CNTG 3147.219 CCL.CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG 22.525 2355.250 3079.656 0.000 22.092 2519.906 3060.020 0.034 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE . 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE · 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE1VO-MBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NO~4BER : 3 DEPTH INCREMENT: 0.5000 FILE SUNmlARY LDWG TOOL CODE START DEPTH CNTG 10161.0 GRCH 10150.0 STOP DEPTH .......... 9739.0 9739.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 10 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10148.5 10144.5 10132.5 10128.5 10124.5 10116.5 10112.5 10100.5 10096.5 10092.5 10088.5 10084.5 1OO8O.5 10076.5 10072.5 10056.5 10052.5 10048.5 10044.5 10040.5 10036.5 10032.5 10028.5 10024.5 10020.5 10016.5 9996.5 9992.5 9984.5 9980.5 9976.5 9972.5 9968.5 9964.5 9960.5 9956.5 9948.5 993 6.5 9932.5 9928.5 9924.5 9920.5 9916.5 9900.5 .......... EQUIVALENT UNSHIFTED DEPTH CNTG GRCH 88889.0 88888.5 10149.0 10144.5 10133.5 10132.5 10128.0 10124.0 10116.5 10113.0 10101.5 10097.0 10093.0 10089.5 10086.0 10082.0 10077.0 10057.0 10052.0 10047.5 10039.5 10036.0 10032.0 10029.5 10025.5 10022.0 10017.5 10097.0 10094.5 10090.0 10086.0 10072.5 10052.5 10050.0 10046.0 10037.0 10033.0 10028.5 10024.5 10021.0 9997.0 9992.0 9984.0 9979 5 9974 5 9971 0 9968 0 9965 5 9960 0 9956.0 9947.5 9935.5 9932.0 9927.5 9923.0 9919.5 9916.0 9900.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 11 9896.5 9892.5 9888.5 9884.5 9876.5 9872.5 9868.5 9860.5 9856.5 9852.5 9848.5 9844.5 9840.5 9836.5 9832.5 9824.5 9820.5 9816.5 9812.5 9804.5 9800.5 9796.5 9792.5 9788.5 9780.5 9776.5 9772.5 9768.5 9760.5 9756.5 100.0 9837.5 9833.0 9817.0 9812.5 9780.5 9777.0 9772.5 9769.0 9896.5 9893.0 9888.0 9884.5 9876.5 9872 0 9868 5 9860 5 9857 0 9852 5 9849 0 9845 0 9840 5 9837 0 9833 5 9825 5 9821 0 9805.0 9800.0 9796.0 9791.5 9788.0 9780.0 9777.0 9773.5 9761.5 9758.0 100.5 101.5 REMARKS: This file contains CNTG Pass #3. The depth shifts shown above relect GRCH pass #3 to GRCH pass #1 and NPHI pass #3 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 12 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 16 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 553982 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 553982 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 553982 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 553982 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 553982 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 553982 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 553982 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 553982 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 553982 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 553982 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 553982 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 553982 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 553982 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 553982 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 553982 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 553982 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10161.500 NPHI.CNTG 27.084 ENPH. CNTG 29.757 CPHI.CNTG NRAT. CNTG 2.987 CRAT. CNTG 2.888 ENRA.CNTG 4.636 NCNT. CNTG FCNT. CNTG 642.694 CNTC. CNTG 1851.767 CFTC. CNTG 669.412 CNEC. CNTG CFEC. CNTG 614.434 GRCH. CNTG -999.250 TENS. CNTG 3230.000 CCL.CNTG DEPT. 10000.000 NPHI.CNTG 21.855 ENPH. CNTG 23.447 CPHI.CNTG ArRAT. CNTG 2.655 CRAT. CNTG 2.601 ENRA.CNTG 3.951 NCNT. CNTG FCNT. CNTG 909.065 CNTC. CNTG 2337.628 CFTC. CNTG 889.952 CNEC. CNTG CFEC. CNTG 789.600 GRCH. CNTG 52.500 TENS. CNTG 3245.000 CCL.CNTG DEPT. 9800.000 NPHI.CNTG 22.517 ENPH. CNTG 24.925 CPHI.CNTG NRAT. CNTG 2.645 CRAT. CNTG 2.638 ENRA.CNTG 4.117 NCNT. CNTG FCNT. CNTG 835.246 CNTC. CNTG 2398.469 CFTC. CNTG 949.396 CNEC. CNTG CFEC. CNTG 759.776 GRCH. CNTG 51.750 TENS. CNTG 3135.000 CCL.CNTG 25.337 1847.520 2848.447 0.068 23.286 2505.338 3119.787 0.024 21.832 2362.273 3128.320 0.049 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 13 DEPT. 9739.500 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 144.000 TENS.CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUM~ER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3 CNTG The arithmetic average of passes 1,2,& 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 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 APIAPI API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553982 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 553982 O0 000 O0 0 4 1 1 4 68 0000000000 1VRAT CNAV 553982 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 553982 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 553982 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 553982 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 553982 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 553982 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 553982 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 553982 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 553982 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 553982 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 553982 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 553982 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 1 O161. 000 NPHI. CNAV 27. 430 NRAT. CNAV 2. 954 CPHI. CNAV CRAT. CNAV 2. 907 ENPH. CNAV 29. 067 ENRA. CNAV 4 . 564 NCNT. CNAV FCNT. CNAV 638. 423 CNTC. CNAV 1870. 187 CFTC. CNAV 665. 643 CNEC. CNAV CFEC. CNAV 615. 800 GRCH. CNTG -999. 250 26.001 1894.105 2810.695 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 DEPT. 10000. 000 NPHI. CNAV 21 . 276 NRAT. CNAV CRA T . CNA V 2.563 ENPH . CNA V 22.998 ENRA . CNA V FCNT. CNAV 862. 519 CNTC. CNAV 2264. 379 CFTC. CNAV CFEC. CNAV 793.100 GRCH. CNTG 49. 773 DEPT. 9800. 000 NPHI. CNAV 22. 381 NRAT. CNAV CRAT. CNAV 2. 629 ENPH. CNAV 23. 595 ENRA. CNAV FCATT. CNAV 917. 740 CNTC. CNAV 2459. 473 CFTC. CNAV CFEC. CNAV 775.181 GRCH. CNTG 48. 359 2. 542 3. 899 881. 000 2.733 3.967 980.034 CPHI.CNAV NCNT. CNAV CNEC. CNAV CPHI.CNAV NCNT. CNAV CNEC.CNAV PAGE: 15 22.476 2428.953 3092.213 21.601 2437.649 3073.931 DEPT. 9740.500 NPHI.CNAV -999.250 lV~RAT. CNAV -999.250 CPHI.CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG 277.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE . FLIC VERSION . O01CO1 DATE : 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION . O01CO1 DATE . 97/01/23 ~REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~VARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG 10161 . 0 9740.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 1 6 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 09-DEC-96 42.2 1110 09-DEC-96 10164.0 10165.0 9740.0 10161 . 0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CCL CCL CAL - YA - 28 TCC TELEMETRY CARTRIDGE TCC- B- 2 81 GR GARfl~A RAY SGC- SA- 5 9 CNTG NEUTRON CNC- GA - 125 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY'. HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 10294.0 CRUDE -5.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO BHCS DATED 5/3/94 EPITHERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 MASTER CALS DONE WITH MAXIS UNIT ON 11/9/96 PUMPED 375 BBLS CRUDE PRIOR TO LOGGING $ LIS FORMAT DATA PAGE: 17 * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 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 553982 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 553982 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 553982 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 553982 O0 000 O0 0 5 1 1 4 68 0000000000 T~ PS1 553982 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 553982 O0 000 O0 0 5 1 1 4 68 0000000000 EIVRA PSi 553982 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 553982 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 553982 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 553982 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN PS1 CPS 553982 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 553982 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 553982 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 553982 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 553982 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 553982 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 553982 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 1 8 NAME SERV UNIT SERVICE API API API API FILE N-U~IB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS PS1 LB 553982 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 553982 O0 000 O0 0 5 1 1 4 68 0000000000 * * DA TA * * DEPT. 10177.500 NPHI.PS1 26.056 ENPH. PS1 36.230 TNPH.PS1 TNRA.PS1 2.832 RTNR.PS1 2.913 ENRA.PS1 5.274 CFEC.PS1 CNEC.PS1 2867.104 RCEF. PS1 540.125 RCEN. PS1 2720.452 RCNT. PS1 RCFT. PS1 643.406 CNTC. PS1 1878.537 CFTC.PSI 678.125 NPOR.PS1 GR.PS1 42.188 TENS.PSi 2465.000 CCL.PS1 0.059 DEPT. 10000.000 NPHI.PS1 19.686 ENPH. PS1 23.228 TNPH.PS1 TNRA.PS1 2.463 RTNR.PS1 2.383 ENRA.PS1 3.926 CFEC.PS1 CNEC. PS1 3081.110 RCEF. PS1 827.435 RCEN. PS1 3017.158 RCNT. PS1 RCFT. PS1 844.860 CNTC. PS1 2223.929 CFTC. PSi 891.246 NPOR.PS1 GR.PS1 52.875 TENS.PSi 3360.000 CCL.PS1 -0.020 DEPT. 9800.000 NPHI.PS1 19.975 ENPH.PS1 24.162 TNPH. PS1 TNRA.PS1 2.482 RTN-R.PS1 2.682 ENRA.PS1 4.032 CFEC. PS1 CNEC. PS1 3041.352 RCEF. PS1 776.043 RCEN. PS1 2856.468 RCNT. PS1 RCFT. PS1 1002.028 CNTC. PS1 2500.129 CFTC. PSi 1063.114 NPOR.PS1 GR.PS1 48.656 TENS.PSi 3200.000 CCL.PS1 0.054 DEPT. 9739.500 NPHI.PS1 40.909 ENPH. PS1 41.989 TNPH.PS1 TNRA.PS1 3.647 RTNR.PS1 3.780 ENRA.PS1 5.793 CFEC. PS1 CNEC.PS1 2537.668 RCEF. PS1 435.071 RCEN. PS1 2419.607 RCNT. PS1 RCFT. PS1 461.307 CNTC. PS1 1657.240 CFTC. PSI 471.145 NPOR.PS1 GR.PS1 194.875 TENS. PSi 3190.000 CCL.PS1 0.078 25.395 543.646 1900.652 25.395 21.387 784.763 2445.592 18.916 19.348 754.306 2532.389 19.316 37.013 438.088 1662.562 37.384 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION ' O01CO1 DATE : 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 19 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE1VUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NU3fBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH CNTG 10161.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 9739.0 09 -DEC- 96 42.2 1110 09-DEC-96 10164.0 10165.0 9740.0 10161.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CCL CCL CAL- YA - 28 TCC TELEMETRY CARTRIDGE TCC-B-281 GR GAt4MA RAY SGC- SA- 5 9 CNTG NEUTRON CNC-GA- 125 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TE~IPERATURE (DEGF) : BOTTOM HOLE TE~IPERATURE (DEGF) : 10294.0 CRUDE -5.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 20 FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUN~ RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO BHCS DATED 5/3/94 MASTER CALS DONE WITH MAXIS UNIT ON 11/9/96 PUMPED 375 BBLS CRUDE PRIOR TO LOGGING $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 21 TYPE REPR CODE VALUE 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 553982 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 553982 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 553982 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 553982 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 553982 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 553982 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 553982 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 553982 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 553982 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 553982 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 553982 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 553982 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 553982 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 553982 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 553982 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 553982 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 553982 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 553982 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 553982 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10193.000 NPHI.PS2 24.912 ENPH.PS2 32.267 TNPH. PS2 TNRA.PS2 2.769 RTNR.PS2 2.848 ENRA.PS2 4.891 CFEC. PS2 CNEC. PS2 2808.777 RCEF. PS2 570.597 RCEN. PS2 2665.108 RCNT. PS2 RCFT. PS2 661.454 CNTC. PS2 1888.212 CFTC. PS2 697.147 NPOR.PS2 GR.PS2 39.875 TENS. PS2 2565.000 CCL.PS2 0.059 DEPT. 10000.000 NPHI.PS2 22.073 ENPH. PS2 22.196 TNPH.PS2 TNRA.PS2 2.613 RTNR.PS2 2.561 ENRA.PS2 3.807 CFEC. PS2 CNEC.PS2 3081.501 RCEF. PS2 805.055 RCEN. PS2 3094.186 RCNT. PS2 RCFT. PS2 830.049 CNTC. PS2 2231.408 CFTC. PS2 863.455 NPOR.PS2 GR.PS2 50.125 TENS. PS2 3225.000 CCL.PS2 -0.015 DEPT. 9800.000 NPHI.PS2 23.405 ENPH. PS2 22.619 TNPH.PS2 TNRA.PS2 2.687 RTNR.PS2 2.959 ENRA.PS2 3.856 CFEC.PS2 CNEC.PS2 3060.348 RCEF. PS2 802.600 RCEN. PS2 2919.775 RCNT. PS2 RCFT. PS2 1004.823 CNTC. PS2 2546.371 CFTC. PS2 1005.928 NPOR.PS2 GR.PS2 51.938 TENS. PS2 3145.000 CCL.PS2 0.024 24.483 574.317 1910.441 24.483 22.669 809.356 2337.590 21.581 21.905 793.616 2521.304 22.583 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 22 DEPT. 9738.000 NPHI.PS2 TNRA.PS2 3.870 RTNR.PS2 CNEC. PS2 2559.854 RCEF. PS2 RCFT. PS2 376.674 ClTTC. PS2 GR.PS2 114.000 TENS.PS2 44.987 ENPH. PS2 3.789 ENRA.PS2 391.224 RCEN. PS2 1626.359 CFTC.PS2 3155.000 CCL.PS2 46.187 6.145 2421.125 432.804 0.073 TNPH. PS2 CFEC. PS2 RCNT. PS2 NPOR.PS2 40.982 416.585 1569.760 43.229 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE ' FLIC VERSION · O01CO1 DATE : 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-UT4BER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in las¢ file PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE S~Y VENDOR TOOL CODE START DEPTH CNTG 10161.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9739.0 09 -DEC- 96 42.2 1110 09-DEC-96 10164.0 10165.0 9740.0 10161.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 23 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CCL CCL CAL- YA - 28 TCC TELEMETRY CARTRIDGE TCC- B- 2 81 GR GA~g~A RAY SGC-SA-59 CNTG NEUTRON CNC- GA - 125 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10294.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) .. GAS~OIL RATIO: CHOKE (DEG) : CRUDE -5.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THE~) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO BHCS DATED 5/3/94 MASTER CALS DONE WITH MAXIS UNIT ON 11/9/96 PUMPED 375 BBLS CRUDE PRIOR TO LOGGING $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 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 553982 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 553982 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 553982 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 553982 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 553982 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 553982 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 553982 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 553982 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 553982 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 553982 O0 000 O0 0 7 1 1 4 68 0000000000 RCEN PS3 CPS 553982 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 553982 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 553982 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 553982 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 553982 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 553982 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 553982 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 553982 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 553982 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 25 DEPT. 10174.500 NPHI.PS3 TNR~.PS3 2.959 RTNR.PS3 CNEC. PS3 2764.343 RCEF. PS3 RCFT. PS3 629.603 CNTC. PS3 GR.PS3 38.531 TENS.PS3 DEPT. 10000.000 NPHI.PS3 TNRA.PS3 2.577 RTNR.PS3 CNEC. PS3 3107.264 RCEF. PS3 RCFT. PS3 885.547 CNTC. PS3 GR.PS3 51.750 TENS.PS3 DEPT. 9800.000 NPHI.PS3 TNRA.PS3 2.570 RTNR.PS3 CNEC. PS3 3121.141 RCEF. PS3 RCFT. PS3 982.378 CNTC. PS3 GR.PS3 51.750 TENS.PS3 DEPT. 9738.000 NPHI.PS3 TNRA.PS3 4.040 RTNR.PS3 CNEC. PS3 2542.688 RCEF. PS3 RCFT. PS3 365.700 CNTC. PS3 GR.PS3 114.750 TENS.PS3 28.379 ENPH. PS3 3.044 ENRA.PS3 573.642 RCEN. PS3 1922.267 CFTC. PS3 2480.000 CCL.PS3 21.452 ENPH. PS3 2.630 ENRA.PS3 795.291 RCEN. PS3 2359.083 CFTC. PS3 3305.000 CCL.PS3 21.354 ENPH. PS3 2.918 ENRA.PS3 704.919 RCEN. PS3 2460.163 CFTC. PS3 3090.000 CCL.PS3 31.242 TNPH. PS3 4.788 CFEC. PS3 2622.947 RCNT. PS3 663.578 NPOR.PS3 0.068 24.193 TNPH. PS3 4.036 CFEC.PS3 3008.349 RCNT. PS3 912.745 NPOR.PS3 0.122 24.602 TNPH.PS3 4.081 CFEC.PS3 2894.823 RCNT. PS3 995.191 NPOR.PS3 0.054 27.289 577.382 1944.896 27.289 22.674 769.976 2539.069 20.760 21.055 764.730 2404.302 22.125 48.077 ENPH. PS3 42.960 TNPH. PS3 48.437 4.395 ENRA.PS3 5.876 CFEC.PS3 432.734 437.651 RCEN. PS3 2405.371 RCNT. PS3 1669.585 1628.625 CFTC. PS3 389.040 NPOR.PS3 47.746 3100.000 CCL.PS3 0.107 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/01/23 ORIGIN : FLIC TAPE NAME : 97003 CONTINUATION # : 1 PREVIOUS TAPE : CO~ff4ENT · ARCO ALASKA INC. , PRUDHOE BAY, D.S. 4-05A, API# 50-029-20107-01 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1997 11:39 PAGE: 26 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/01/23 ORIGIN : FLIC REEL NAME : 97003 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4~05A, API# 50-029-20107-01 Tape Subfile 2 is type: LIS , TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: OWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6195.00 J. DAHL SEE REMARKS D.S. 4 - 05A 500292010701 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 09-MAY-94 RUN 2 RUN 3 34 liN 15E 742 420 60.38 58.98 29.49 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 8254.0 PRODUCTION STRING 8.500 10294.0 REMARKS: DLL/CN/4CAL/GR & AC/GR. LOGS WITNESSED BY: J. VERSTEEG & G. BECK. CIRCULATION STOPPED AT 21:30, 02-MAY-94. ACOUSTIC DATA RECORDED ON A SEPARATE RUN. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING ACTIVE, NO CASING OR SALINITY CORRECTIONS APPLIED. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 9551.0 10269.0 9551.0 10292.0 all runs merged; no case GR 8255.0 DLL 9551.0 2435 9551.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 10210.0 10242.0 10217.0 GR from AC tool string. (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH DT GRI LL3 NPHI 8256.0 8255.0 9556.5 9555.5 9558.5 9557.5 9557.5 9563.5 9562.5 9562.5 9567.0 9566.5 9566.0 9565.0 9566.0 9578.5 9578.5 9590.0 9590.0 9595.5 9595.0 9602.0 9601.0 9603.5 9603.0 9609.0 9608.0 9612.5 9613.0 9612.0 9612.0 9613.0 9612.5 9628.5 9627.5 9629.0 9629.0 9628.5 9631.5 9630.5 9646.0 9645.5 9648.5 9647.0 9652.0 9652.0 9651.0 9651.0 9651.0 9661.5 9661.0 9667.0 9666.5 9667.0 9673.0 9672.5 9672.5 9674.5 9674.0 9677.5 9676.5 9679.0 9678.5 9679.5 9679.5 9678.5 9678.5 9681.5 9681.0 9683.0 9682.5 9684.0 9684.5 9685.0 9684.5 9690.5 9690.5 9690.5 9690.5 9690.5 9694.5 9694.5 9698.0 9698.0 9700.5 9700.5 9703.5 9704.5 9703.5 9707.0 9707.0 9706.0 9707.0 9707.5 9707.5 9710.5 9710.0 9713.0 9717.0 9718.0 9728.0 9732.5 9741.5 9742.0 9750.0 9754.0 9760.0 9760.5 9763.0 9771.0 9771.5 9772.0 9780.5 9781.0 9782.5 9783.0 9785.0 9789.5 9792.0 9796.5 9797.0 9802.0 9828.0 9834.5 9836.5 9839.0 9841.0 9843.5 9844.0 9845.5 9858.0 9860.5 9866.5 9870.5 9887.0 9903.0 9917.5 9923.0 9924.5 9925.5 9938.5 9964.5 9965.0 9978.0 9985.0 9990.0 9990.5 9992.5 9994.5 9996.0 9997.5 10000.5 10002.5 10004.5 10005.0 10008.5 10009.0 9742.0 9763.0 9772.0 9783.0 9797.5 9834.5 9844.0 9867.0 9965.0 9990.5 9993.0 9996.5 10000.5 10008.5 9712.0 9719.0 9728.0 9732.0 9740.5 9749.0 9754.0 9760.5 9763.0 9771.5 9781.0 9785.0 9790.0 9796.5 9828.5 9837.0 9844.0 9861.0 9871.0 9918.0 9965.5 9990.5 9996.0 10000.5 10005.0 10009.0 9719.0 9728.0 9732.0 9740.5 9750.0 9754.0 9759.5 9761.5 9779.5 9782.0 9785.0 9790.0 9796.5 9802.5 9828.0 9834.0 9838.5 9840.5 9925.0 9965.5 9994.5 10000.5 10008.5 9717.5 9759.0 9769.5 9791.5 9802.0 9839.0 9846.0 9858.5 9886.5 9903.0 9923.5 9926.5 9939.0 9978.0 9984.5 9990.5 9998.0 10000.0 10002.0 10005.0 10009.5 10011.5 10012.0 10014.5 10015.0 10031.5 10033.5 10041.5 10042.0 10046.5 10052.0 10056.5 10063.0 10063.5 10067.5 10070.5 10076.5 10077.0 10096.0 10099.0 10099.5 10105.5 10106.0 10108.5 10116.5 10117.0 10118.5 10127.5 10130.0 10130.5 10134.0 10136.0 10144.5 10147.0 10147.5 10150.0 10153.0 10156.0 10158.5 10159.0 10163.0 10164.0 10164.5 10168.0 10172.0 10175.0 10181.0 10186.5 10187.0 10189.5 10199.5 10200.0 10206.0 10233.0 10233.5 10243.5 $ MERGED DATA SOURCE PBU TOOL CODE GR 10011.5 10014.5 10032.0 10043.5 10071.0 10076.5 10117.0 10128.5 10134.0 10145.0 10150.0 10153.5 10156.0 10160.0 10168.0 10181.5 10199.0 10234.0 10243.5 RUN NO. 1 10012.0 10014.5 10031.5 10034.0 10042.5 10047.0 10057.0 10064.0 10076.5 10099.5 10106.0 10116.0 10127.0 10135.5 10144.0 10149.0 10152.5 10158.5 10164.0 10171.5 10179.5 10186.5 10199.0 10204.5 PASS NO. 6 10011.0 10014.0 10034.0 10043.0 10064.0 10071.0 10077.0 10099.5 10104.5 10118.5 10126.5 10129.5 10134.0 10147.5 10149.5 10158.5 10163.0 10186.5 10232.5 10034.0 10043.0 10052.0 10063.0 10068.0 10076.5 10095.5 10099.0 10108.5 10116.5 10130.5 10135.5 10146.5 10162.0 10167.5 10175.0 10189.0 10200.0 MERGE TOP 9551.0 MERGE BASE 10269.0 BCS 1 6 9551.0 10292.0 GR DLL 2435 $ REMARKS: 8255.0 10210.0 9551.0 10242.0 9551.0 10217.0 MERGED MAIN PASS. "GRI" REFERS TO THE GAMMA RAY FROM THE DLL/CN STRING. MTEM, TEND, & TENS (from AC string) WERE SHIFTED WITH DT. LLD, SP, MTEM, TEND, TENS, C13, & C24 (from DLL/CN tool string) WERE SHIFTED WITH LL3. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ?MATCH2. OUT /??MATCH3 .OUT /??MATCH4 .OUT $ : ARCO ALASKA INC. : D.S. 4 - 05A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Name Tool Code Samples Units GR BCS 68 1 GAPI DT BCS 68 1 US/F MTEM BCS 68 1 DEGF TEND BCS 68 1 LB TENS BCS 68 1 LB GR DLL 68 1 GAPI LL3 DLL 68 1 OHMM LLD DLL 68 1 OHMM SP DLL 68 1 MV MTEM DLL 68 1 DEGF TEND DLL 68 1 LB TENS DLL 68 1 LB C13 DLL 68 1 IN C24 DLL 68 1 IN NPHI 2435 68 1 PU-S FUCT 2435 68 1 CPS NUCT 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 20 789 90 0 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 299 Tape File Start Depth = 10317.000000 Tape File End Depth = 8228.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 75223 datums Tape Subfile: 2 555 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3j is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 3 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8250.0 10222.0 DLL 9551.0 10254.0 2435 9551.0 10228.5 4CAL 8250.0 10302.0 $ 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): 03-MAY-94 FSYS REV. J001 VER. 1.1 2130 02-MAY-94 504 03-MAY-94 10294.0 10292.0 8250.0 10242.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS MIS AC 4 CAL $ CABLEHEAD TENSION TEMPERATURE GAMMARAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG 4-ARM CALIPER TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229MA/1229EA 3967XA 1603MA/1609EB 4203XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 8254.0 8255.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): KCL POLYMER 10.00 54.0 MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: 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): TOOL STANDOFF (IN): REMARKS: DLL/CN/4CAL/GR MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4 - 05A : PRUDHOE BAY : NORTH SLOPE : ALASKA 9.6 5.1 169.0 .126 .059 .110 .000 .286 .000 THERMAL SANDSTONE .00 .000 2.0 75.0 169.0 68.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB TEN DLL 68 1 LB SPD DLL 68 1 F/MN C13 CAL 68 1 IN C24 CAL 68 1 IN CAL CAL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 4 46 103 82 1 4 11 639 82 1 4 73 724 97 6 4 80 933 93 6 4 30 085 93 6 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 68 * DATA RECORD (TYPE# 0) Total Data Records: 595 1014 BYTES * Tape File Start Depth = 10308.000000 Tape File End Depth = 8228.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 149779 datums Tape Subfile: 3 678 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS 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 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 2 PASS NUMBER: 6 DEPTH INCREMENT: .2500 FILE S~Y VENDOR TOOL CODE START DEPTH GR 9550.0 AC 9550.0 $ 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 10286.0 10310.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR PCM AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY PULSE CODE MODULATOR BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): M~3D FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 03-MAY-94 FSYS REV. J001 VER. 1.1 2130 02-MAY-94 834 03-MAY-94 10294.0 10300.0 9550.0 10292.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 3506XA 1603MA/1609EB 8.500 8254.0 8255.0 KCL POLYMER 10.00 54.0 9.6 5.1 172.0 · 126 .058 · 110 .000 .286 .000 75.0 172.0 68.0 .0 68.0 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: AC/GR MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4 - 05A : PRUDHOE BAY : NORTH SLOPE : ALASKA .00 .000 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units 1 GR AC 68 2 AC AC 68 3 ACQ AC 68 4 TEMP AC 68 5 CHT AC 68 6 TTEN AC 68 7 TEN AC 68 8 SPD AC 68 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GAPI 4 1 US/F 4 1 4 1 DEGF 4 1 LB 4 1 LB 4 1 LB 4 1 F/MN 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 61 008 99 5 4 95 558 30 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 110 Tape File Start Depth = 10317.000000 Tape File End Depth = 9549.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 102881 datums Tape Subfile: 4 183 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 2 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9682.0 10227.0 DLL 9682.0 10259.0 2435 9682.0 10234.0 4CAL 9682.0 10290.0 $ 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 CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS MIS AC 4CAL $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG 4-ARM CALIPER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): 03-MAY-94 FSYS REV. J001 VER. 1.1 2130 02-MAY-94 427 03-MAY-94 10294.0 10292.0 9550.0 10242.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229MA/1229EA 3967XA 1603MA/1609EB 4203XA 8.500 8254.0 8255.0 KCL POLYMER 10.00 54.0 9.6 5.1 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY~(OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: 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): TOOL STANDOFF (IN): REMARKS: DLL/CN/4CAL/GR REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4 - 05A : PRUDHOE BAY : NORTH SLOPE : ALASKA 169.0 .126 .059 .110 .000 .286 .000 THERMAL SANDSTONE .00 .000 2.0 75.0 169.0 68.0 .0 68.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 4 2 RS DLL 68 1 OHMM 4 3 RD DLL 68 1 OHMM 4 4 SP DLL 68 1 MV 4 5 TEMP DLL 68 1 DEGF 4 6 CHT DLL 68 1 LB 4 7 TTEN DLL 68 1 LB 4 8 TEN DLL 68 1 LB 4 9 SPD DLL 68 1 F/MN 4 10 C13 CAL 68 1 IN 4 11 C24 CAL 68 1 IN 4 12 CAL CAL 68 1 IN 4 13 CNC 2435 68 1 PU-S 4 14 CNCF 2435 68 1 PU-S 4 15 CN 2435 68 1 PU-L 4 16 LSN 2435 68 1 CPS 4 17 SSN 2435 68 1 CPS 4 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 4 46 103 82 1 4 11 639 82 1 4 73 724 97 6 4 80 933 93 6 4 30 085 93 6 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 181 Tape File Start Depth = 10313.000000 Tape File End Depth = 9681.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 195302 datums Tape Subfile: 5 262 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 2 PASS NUMBER: 5 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9725.0 AC 9748.0 $ 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 10284.0 10307.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR PCM AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY PULSE CODE MODULATOR BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL 03-MAY-94 FSYS REV. J001 VER. 1.1 2130 02-MAY-94 809 03-MAY-94 10294.0 10300.0 9550.0 10292.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 3506XA 1603MA/1609EB 8.500 8254.0 8255.0 KCL POLYMER 10.00 54.0 9.6 5.1 172.0 .126 .058 .110 .000 .286 .000 75.0 172.0 68.0 .0 68.0 .0 TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX:. ~ MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: AC/GR REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4 - 05A : PRUDHOE BAY : NORTH SLOPE : ALASKA .00 .000 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 2 AC AC 68 3 ACQ AC 68 4 TEMP AC 68 5 CHT AC 68 6 TTEN AC 68 7 TEN AC 68 8 SPD AC 68 1 GAPI 4 1 US/F 4 1 4 1 DEGF 4 1 LB 4 1 LB 4 1 LB 4 1 F/MN 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 61 008 99 5 4 95 558 30 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 97 Tape File Start Depth = 10315.000000 Tape File End Depth = 9642.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 127119 datums Tape Subfile: 6 168 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile-7 is. type: LIS 94/ 5/ 9 01 **** REEL TRAILER **** 94/ 5/ 9 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 9 MAY 94 4:46p Elapsed execution time = 24.00 seconds. SYSTEM RETURN CODE = 0
