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198-174
1a. Well Status: GINJ Oil 1b. Well Class: 5 Exploratory Service Hilcorp North Slope, LLC 14. Permit to Drill Number/Sundry 198-174 10/13/1998 10/26/98 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 2496' FSL, 1133' FWL, Sec. 32, T11N, R15E, UM 3054' FSL, 2616' FWL, Sec. 32, T11N, R15E, UM 3140' FSL, 3090' FWL, Sec. 32, T11N, R15E, UM Surface: x- y- Zone -698212 5948689 ASP4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 04/27/2021 15. 50-029-21960-01-00 16. PBU 05-18A Well Name and Number: Surface / Surface 35 17. TPI:y- Zone -699678 ASP4x-5949286 Total Depth: x-y-Zone -700149 ASP45949384 9595' / 9064' 2192 / 2192 DNR Approval Number:19. n/a 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: MWD/ GR, CCL/ GR/ CNL CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 7-5/8" 5-1/2" 2- 3/ 8" 91.5# 45.5# 29.7# 17# 4.43# L-80 L-80 L-80 L-80 surface surface surface surface 8870' 8888' 9595' surface surface surface 8369' 8553' 8536' 9064' 2- 3/4" 6- 3/ 4" 9- 7/ 8 284 sx PF 300 sx Class' G' 100 sx Class' G', 117 sx Thixotrophic, 100 sx Lates 20 Bbls 15.8 ppg LARC 25. GRADE PACKER SET (MD/TVD) 26. 4-1/2" 12.6# L-80 x 3- 1/ 2" 9. 3# L- 80 8825' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: n/a n/a Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: Surface Open to production or injection?Yes No 524. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 9400' - 9414' 8913' - 8924' 9423' - 9443' 8931' - 8947' 9465' - 9485' 8964' - 8979' 9490' - 9510' 8983' - 8998' H-40 114'30"20" 10-3/4"surface 3518 13- 1/ 2" 1000 sx CS Ill, 152 sx CS II, 350 sx Class' G'surface 114' 8538' / 8217' Austin McLeod Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 114' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028326 321-041 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF Surface (attached) KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 66 Water Depth, if Offshore:13. n/a 0 API Number: 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 perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 8888'/ 8553' approximate 1900' 5 Submit within 30 days of Completion, Suspension, or Abandonment Top off 8" of OA with new cement per AOGCC rep By Samantha Carlisle at 3:56 pm, May 19, 2021 xGDSR-5/24/21 Abandonment Date 4/27/2021 HEW SFD 5/21/2021 RBDMS HEW 6/7/2021 MGR28JUN2021 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title:Operations Manager Authorized Signature with Date:Contact Phone:(907)564-4672 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the 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 or well test results. 8758' 8799' 8860' 9444' 9520' 8428' 8467' 8526' 8948' 9006' Sag River Shublik Sadlerochit- Zone 4 Zone 1B Base of Sadlerochit- Kavik Kavik 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 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. Well Tested? Yes 9520 9006 Top of Productive Interval 8860'8526' 5NoPermafrost - Top TVDMDNAME 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 31. Daily Operations Summary, Wellbore Schematic, Well photosList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.19 13:11:06 -08'00' Bo York c FULL ABANDONMENT - ALL STRINGS CEMENTED TO SURFACE & CUT 3'1" BELOW TUNDRA, MARKER PLATE INSTALLED (04/25/21) ACTIVITYDATE SUMMARY 4/2/2021 ***P&A In Progress*** Pad Elevation = 35.3'. Tundra Elevation = 30.8'. Begin excavation, find casing ~2' below pad grade. Continue excavation to 4' below pad grade, notice hydraulic leak on excavator lower arm piston. Haul excavator to the Fleet Shop. Excavator will be in the shop until at least 4/5/21. LDFN. 4/18/2021 *** P&A*** Excaveted down and found suspended well casing at ~2' below pad elevation. Continue to excavate down to 11.5' below pad elevation. Pad elevation = 35.3'. Tundra elevation = 28.8'. Cut cemented casing strings 9' 7" below pad elevation = to 3' 1" below tundra elevation. Slight bubling was noticed on the OA, no LELs were detected by gas meter. AOGCC REP. Austin McLeod asked to dig out contaminated cement out of OA and top off with cement. Crew was able to get down 8" until finding hard bottomt then topped it off with new cement. Job In Progress 4/19/2021 **P&A**. OA top job is cured and hard from day before. AOGCC Rep Bob Noble witnessed cement top and marker plate but did not want to weld marker beacause of the vertical split down the conductor. Pictures taked to document cement top and split in the conductor. Wait for a plan foward. Job In Progress. 4/25/2021 ***P&A In Progress*** Weld 10-3/4" plate on to surface casing. Weld marker plate on to 20" conductor. Verified by AOGCC rep Jeff Jones. WOW to pull shoring box and backfill excavation. Hilcorp North Slope, LLC Well: PBU 05-18A PTD #198-174 API #50-029-21960-01-00 4/27/2021 ***P&A Complete*** Pull shoring box, backfill excavation & delineate location. Demobe all equipment and travel to V-119. Daily Report of Well Operations PBU 05-18A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 4/19/2021 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Inspector PBU 05-18A Hilcorp North Slope LLC PTD 1981740; Sundry 321-04'f 4/19/2021: 1 traveled to Hilcorp's PBU 05-18A to do a follow up inspection on a surface abandonment. On arrival I met with Hilcorp rep Jaycen Sala. I went over possible issues the AOGCC had with the well abandonment. Yesterday's inspection (see Austin McLeod report) noted that cement in the production casing by intermediate casing annulus was of poor quality and while digging in it noticed some bubbling. Hilcorp said they could only dig down 8 inches and topped it off with cement — see photo provided by Hilcorp. ✓ I confirmed the information on the marker plate was correct. I looked at the split conductor that was noted during yesterday's inspection. There was about 2 feet of pipe exposed and there was no sign of the split closing. I looked at the pipe that they had cut off. It was split the full length (about 8 feet). The annuli spaces on the top end of the removed pipe section had hard cement; the bottom end showed good hard cement except in the surface casing by conductor annulus. It was soft enough that I could dig in it with my fingernails. It also had a hydrocarbon smell it. I informed Hilcorp's Jaycen Sala not to weld the plate on and wait for direction from the AOGCC. Attachments: Photos (9) 2021-0419—Surface—Abandon—PBU-05-18A bn.docx Page 1 of 6 Surface Abandonment — PBU 05-18A (PTD 1981740) Photos by AOGCC Inspector B. Noble except as noted 4/19/2021 Photo courtesy of Hilcorp V, W' Marker Plate 2021-0419_Surface_Abandon_PBU_05-18A_bn.docx Page 2 of 6 r . Confinning competence of cement to surface 2021-0419_Surface_Abandon_PBU_05-18A_bn.docx Page 3 of 6 Poor quality cement in surface Split conductor casing by conductor annulus 2021-0419_Surface_Abandon_PBU_05-18A_bn.docx Page 4 of 6 s 2021-0419_Surface_Abandon_PBU_05-18A_bn.docx Page 5 of 6 8 -foot well section removed; view of bottom 8 -foot well section removed; view of top Split conductor on 8 -foot length of removed well section 2021-0419_Surface_Abandon_PBU_05-18A_bn.docx Page 6 of 6 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:198-174 6.API Number:50-029-21960-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028326 Property Designation (Lease Number):10. 8. PBU 05-18A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon 5 Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG 5 Abandoned Oil WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9595 Effective Depth MD: L-80 11. 2/15/2021 Commission Representative: 15. Suspended Contact Name: Oliver Sternicki Contact Email: Oliver.Sternicki@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: none Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9064 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8538, 8217 none Date: Liner 295 5-1/2"8593 - 8888 8269 - 8553 7740 6280 Well Status after proposed work: 16. Verbal Approval: Change Approved Program surface - 3518 surface - 3517 14. Estimated Date for Commencing Operations: BOP Sketch surface - 114 Structural 6890 Proposal Summary 13. Well Class after proposed work: 3-1/2" Otis WD Packer 9400 - 9510 8913 - 8998 4-1/2" 12.6# x 3-1/2" 9.3#surface-8825 Production surface surface surface none surface - 114 470 10-3/4" 7-5/8" Contact Phone:(907) 564-4891 Date: 1/19/2021 4790 78 149020"Conductor 2480 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3481 5210 Intermediate 8834 surface - 8870 surface - 8536 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic n/a Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:04 am, Jan 20, 2021 321-041 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.20 07:37:31 -09'00' Bo York X MGR20JAN21 DLB 01/20/2021 AOGCC to witness. Photo document as described. 10-407 DSR-1/20/21 Yeson Required? Comm 1/21/21 dts 1/21/2021 JLC 1/21/2021 RBDMS HEW 1/27/2020 Plug and Abandon Well: 05-18A PTD: 198174 API: 50-029-21960-01 05-18A Plug and Abandon Well Integrity Engineer: Oliver Sternicki, (907)350-0759 Operations Engineer: David Bjork, (907)440-0331 Expected Start Date: 02/15/2021 History Prudhoe well 05-18 was originally drilled and completed in 1989 and sidetracked in 1998. On 02/23/2010 an LDL confirmed a production casing leak at 6150’. 05-18A (PTD# 198174) was found to have no future utility and was suspended on 05/09/2018 with cement to surface in all strings and the wellhead cut off approximately 2.5 feet below pad level and capped under sundry #317-182. Objective Excavate and cut off all casings 3’ below original tundra, permanently install well name cap, and backfill excavation. Procedure 1. Excavate and cut off all casings 3’ below original tundra level. 2. AOGCC witness of cut-off casings before any top job commences. 3. AOGCC witness cement tops in all annuli. Top off with cement as needed. 4. Bead weld marker cap on outermost casing string. Photodocument all steps and AOGCC witness of installed cap. Marker cap to read as follows: Hilcorp North Slope LLC 05-18A API No. 50-029-21960-01 PTD No. 198174 2 STATE OF ALASKA ❑ Stratigraphic ❑ ALASKA OIL AND OAS CONSERVATION COMMISSION Gas ❑ WDSPL ❑ WAG ❑ REPORT OF SUNDRY WELL OPERATIONS SUSP 0 SPLUG ❑ 1. Operations Performed Suntlry Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Plug for Reddll ❑ Perforate New Pool ❑ Alter Casing ❑ Change Approved Program ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 2. Operator Name: BP Exploration (Alaska), Inc 4. RI Trdvis.Montgomery0bp.com Well Class Before Work Contact Phone: 3. Address: P.O. Box 196612 Anchorage, Development m Ex lorato 5. Permit to Drill Number: 198-174 p ry ❑ AK 99519-6612 7. Property Designation (Lease Number): Stretigrephic ❑ Service ❑ 6. API Number: 50-029.21960-01-00 ADL 028328 e_ Well Name and Number: PBU 05-18A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: 11. Present Well Condition Summary: PRUDHOE BAY. PRUDHOE OIL is s Total Depth: measured 9595 feet Plugs measuredSurface JUN true vertical feet 2 9064 tee} 10 Effective De EDepth. P - measured Junk measured None teat Surface feet true vertical Packer A ( measured 8538 feet OGC Surface feet Packer /`1 till true vertical 8217 reef <J Casing: Length: Size: MD: ND: Burst Collapse: Structure, Conductor -78 20" Surface -114 Surface - 114 Surface -3481470 1490 10-3/4" Surface -3518 Surface -3517 Intermediate -88342480 5210 7-5/8" - Surface -8870 Surface 8538 Production 6890 4790 Liner 295 5-1/2" 8593 - 8888 8289-8553 7740 6280 Perforation Depth. Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# x 3-1/2' 9 3# L-80 Surface 8825 Surface - 8492 Packers and SSSV (type, measured and 3-112" Otis MD Packer true vertical depth) 8538 6217 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Prior to well operation: Suspended Subsequent to operation: 14. Attachments tregUmd per2ow4c 25.070.25071, s 252MI 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Lastufka, Joseph N Authorized Title: Authorized Sian: Form 10-404 Reviser, 0412017 "Vol"', Tubing Pressure Development m Service ❑ Stratigraphic ❑ Oil ❑ Gas ❑ WDSPL ❑ WAG ❑ GINJ ❑ SUSP 0 SPLUG ❑ Suntlry Number or N/A if C.O. Exempt: WA Contact Name: Montgomery, Travis J Contact Email: Trdvis.Montgomery0bp.com 1,5/11 Contact Phone: +1 907 584 4197 3BDMSJ-LyAv.-1UN 2 6 2019 Submit Original Only Daily Report of Well Operations 05-18A ACTIVITYDATE SUMMARY T/I/O = N/A. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Adam Earl. Pictures taken. 6/2/2019 SV, WV = C. IA, OA = CTG. 13:30 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 05-18A Permit # (PTD): 198174 Operator: BP EXf Surface Location: Sectic Nearest active pad or road: Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Initial Inspection Field/Pool: Prudhoe Bay / Prudhoe Oil API Number: 50-029-21962-01 Date Suspended: 5/9/2018 Range: 15E Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean Pad or location surface: Location cleanup needed: Pits condition: Surrounding area condition: Water/fluids on pad: Discoloration, Sheens on pa Samples taken: None Access road condition: Photographs taken (# and or water: Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Cellar description, condition, fluids: N/A Rat Hole: N/A Wellhouse or protective barriers: Cattle Guard Well identification sign: Yes Tubing Pressure (or casing if no tubing): N/A Annulus pressures: N/A Wellhead Photos taken (# and description): N/A Operator Rep (name and signature) AOGCC Inspector: Adam Earl Inspection Date: 6/2/2019 Time of arrival: 1:15 PM Site access method: Acce Josh AOGCC Notice Date: 6/1/2019 Time of Departure: 1:25 PM Y- - i — r �e _.. s r .. r �,�. N" •. a-�. - � 05-194 d5 -285P81. 18-3DAPB1(+ L3-25 '= 11-25A y- 11.3ZR. C D5 -19B .�� „-314 11-11 C OFr#$A 16-30 C 1$-21A _' 11-25 - 1B-D1 Dc-}8APB1 11-29 OE -2P• 7 05.28A `31 16-01/� r- (i 05-1�lc 4 11-34 02-35APB7 tl6-?3B ^. 0E-156 03-39R. DF_39 32-35R.F82 — 18-T1 QPM M � 28 30 0E-15spe1 `.. 32-39AF•64 C 1$-114 - 0E- I EA�^4£-14AP62 71-05A - C 1i-08 11-07FB: 02-38AP62 DE -144 Ors134 02-384 _05-1_ ., 11-14Pa, �' 02-D2,SP61 C, 18-20 _- 0'__15 0E-14 V aE-i3B ;t- OE-3E•.A r a2-42 ... 0E-14APB1 D5 -3T' L� E 11-24A. D: -31A L. 05-32 ". 45-OZA C 11-24 —U I— 0°-31 C OF.1_A E..&00 0, c -3v• _ a- I4 .,, 05-318 ac_ _ a° -OZ IC. 11-38 C 11-05 1144 1 r a D� 39 05-„ _ 05-13,. �.-_ t 11-384. _ aF ]4 ' DE-a?,e 7 _ 174 aE-,B F y2-�-� a_ -}HAP v05-1,=. ]. L05-24 r ]] -0= "'A' �' 32 - DE -3 �v Y 11-05A. ] Ti -12,4 31 {�-17'� 31 C. 05-33 [ DE -25 " 0E-344 '-��y �5-t Oc-] A:-058.P61;i a'-2aA YF z DE -is - ` 05 0EA C 0E-256 C 05-04 FBI -. 0-39 "- N-�9 -DF Off P�Pi QSi 1-2 PW Q+�{7-i _OE�10-aE-TO6 a0',25C ae-2zA. D,3 �I I.; a5�a.:F 6 a5_LDF�,-eE-mss 09 OD5-4D C 12-43A a53AP67V05- 05-03B 11-22AL1 _ 11_ 052 D�3A ! R 1- xc226 Orr-206 i 05-214— 3€-276I03C�11-034. 11-15 C 05-41 C; 5.41A 05-93 q 0.F -276P81 ly C 05-0$ , ama �. 05-07 ^Ot-194 �' 01-214 1111 1143 C 01-158 0606A 01- XX5 11-03PB1 'II' 01-01C 01-224 J 01-20 01-19 I 5 k.01- 0,27 �', 11-12 (" 19C 5 "` D1 -04B OE -27A i - S '0'1-08A _ 01-17A 01-15 - 01-03A 01-03 r,; Ot-22B' C' 01-045 _' 01-17 - Ot-D4 - C.01-178 0 01-32A 01-044 01-28A TRE == FMC FMC SUSPENDED CMT TO SURFACE 1500' TBGM/OA (12/23/17) 12.6#, L-80, —F ST -1 ITBG PUNCH, 6 SPF (11/06/17) I—L Minimum ID =1.25" 9388' WFD ER PATCH K9 3 -PC, 9.3#, L-80, I- j 882T D = 2.992' 8871' PERFORATION SUIv%MRY RIP LOG: SWS MCNL ON 11/05/98 ACTUATOR= TO a f3 KB. EV = 68' BF. aEV = SDWrACE KOP= 4900' Max Anglo = 57' @ 9030' Datum MD= 9342'o0' DetumTVO= 88SS CMT TO SURFACE 1500' TBGM/OA (12/23/17) 12.6#, L-80, —F ST -1 ITBG PUNCH, 6 SPF (11/06/17) I—L Minimum ID =1.25" 9388' WFD ER PATCH K9 3 -PC, 9.3#, L-80, I- j 882T D = 2.992' 8871' PERFORATION SUIv%MRY RIP LOG: SWS MCNL ON 11/05/98 ANGLEATTOP PERF: 38' @ 9400' Note: Refer to production DB for historical part data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16' 6 9400-9414 C 04/16/02 1-11/16' 4 9423-9443 C 03/26/01 1-11/18' 4 9465-9485 S 11/08/17 1-11/16' 4 9490-9510 S 11/08/17 1 5-12' LNR 17#. L-80..0232 bpf. ID=4.892- I SAFETY NOTES: WELLHEAD CUT OFF 2.5- BELOW PAD 05-1 8 A INSTALLED, BACKFUDE. CEMENT TO SLLED 05109118MARKER CAP 63' 4-1/2' X 3-12' XO, 1495' - 1500' TBG PUNCH, 6 SPF (12/19117) 1606'JETCUTTBG(12/18/17) TOP OF DPZ1 1920' BOTTOM OF DPZ1 6560' TOP OF DPZ3 8504' STRAIGHT SLOT LOC SEAL ASSY 2' OTs WD PEIW am o8r"g) 13-112' BKR H-1 CAST IRON CMT RETAINER (09128)1 7) 1 8816' _f3 -1W OTs XN HP, ID= 2.75' 8827' 3-12'WLED,ID=2.992' ELMD TT NOT LOGGED MLLOUT WPIDOW (05-18A) 8888' BOTTOM OF DPZ3 9068' !:>%.F9-388'--9452- 1.80' WFD 13CR ER PATO1(0621 /09), ID =1.25' .0039 bpf, D =1.995' DATE REV BY COMAENTS DATE REV BY COMMENTS 11/89 ORI(&WILCCMPLERON 01/16/19 MWJMD CORREE-noNS TO SUSPENDED 10/29/98 SiOETRA 110123119 MWJMD APPROVED SUSPENDED WELL 11/13/17 AB/JMD CMT IA&TBG (11/08/17) 0620/19 JNUJMD ADDED BF aEV 1221/17 NXNIJMD JEF CUT TBG &TBG=ICSG PUNCH 1227/17 DMS/.MD CMT TO SURFACE TBG/M/OA 05/09/18 AB/JMD SUSPENDED 12-318' PACK -OFF BUSHNG ID=1.0' I PRUDFK)E BAY UHT WB -L: 05-/8A PEa.BT No: 9981740 API No: 50-029-21960-01 SED 32, T11 N, RISE 2188.96' FEL, 2137.99' FNL 13P Exploration (Alaska) Suspended Well Inspection Report InspectNo: susAGE190618095545 Date Inspected: 6/2/2019 Inspector: Adam Earl Well Name: PRUDHOE BAY UNIT 05 -IBA Permit Number: 1981740 Suspension Approval: Sundry # 317-182 Suspension Date: 5/9/2018 Location Verified? ❑1 If Verified, How? Other (specify in comments) Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 6/1/2019 - Operator: BP Exploration(Alaska)Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? O Photos Taken?❑ Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: BPV Installed? ❑ OA: VR Plug(s) Installed? ❑ Wellhead Condition NA Condition of Cellar NA Surrounding Surface Condition well is buried, no sheen or trash, area looks clean ' Comments Location Verified by pad map Supervisor Comments Photos(3)attached 5gE �� I14I,� Wednesday, August 14, 2019 Suspended Well —PBU 05-18A PTD 1981740 AOGCC Inspection Rpt # susAGE190618095545 Photos by AOGCC Inspector A. Earl 6/2/2019 2019-0602_Suspend_PBU_05-18A_photos_ae.docx Page 1 of 2 now RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM N WEL COMPLETION OR RECOMPLETION REPORT AND LOG JUS! 0 4 2018 la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0 • lb.Well Class: may' 20AAC 25.105 20AAC 25.110 L 9 Developme • �Gryr G GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Coj,Susp.,p'Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 5/9/2018"-_. 198-174 • 317-182 3. Address: 7. Date Spudded: 15 API Number: P.O.Box 196612 Anchorage,AK 99519-6612 10/13/1998 50-029-21960-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 10/26/98 PBU 05-18A • Surface: 2496'FSL,1133'FWL,Sec.32,T11N,R15E,UM • 9 Ref Elevations KB 66.00 • 17. Field/Pool(s): Top of Productive Interval: 3054'FSL,2616'FWL,Sec.32,T11N,R15E,UM GL 35.00 ` BF Surface PRUDHOE BAY,PRUDHOE OIL Total Depth: 3140'FSL,3090'FWL,Sec.32,T11N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: Surface/Surface ADL 028326 ` 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD). 19. DNR Approval Number: Surface:x- 698212" y- 5948689 ` Zone - ASP 4 • 9595'/9064' • 70-099 TPI: x- 699678 y- 5949286 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 700149 y- 5949384 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No Il 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top VMndow MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 8888'/8553' 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 perforation record. Acronyms may be used.Attach a separate page if necessary MWD/GR,CCL/GR/CNL 23. CASING,LINER AND CEMENTING RECORD CASING wr.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT PULLED FT. TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 Surface 114' Surface 114' 30" 284 sx PF 10-3/4" 45.5# L-80 Surface 3518' Surface 3517' 13-1/2" 1000 sx CS Ill,152 sx CS II,350 sx Class'G' 7-5/8" 29.7# L-so Surface 8870' Surface 8536' 9-7/8" 300 sx Class'G' 5-1/2" 17# L-80 8593' 8888' 8269' 8553' 6-3/4" 100 sx Class'G',117 sx Thixotrophic,100 sx Lates 2-3/8" 4.43# L-80 8697' 9595' 8369' 9064' 2-3/4" 20 Bbls 15.8 ppg LARC 24. Open to production or injection? Yes 0 No Il 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number;Date Perfd): 4-1/2"12.6#L-80 8825' 8538'/8217' x 3-1/2"9.3#L-80 Iii v-F c 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. <-- --[-�.- Was hydraulic fracturing used during completion? Yes 0 No Ci( • VEr !(7. Per 20 AAC 25.283(i)(2)attach electronic and printed wee JUN I .a-2D-1-r information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size_ Gas-Oil Ratio: Test Period �► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): , Press 24 Hour Rate """► Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only IG6/f ZIJYRBDMS-s JUN 0 5Zo18 ,K 4' ., - ..f3-,% 28. CORE DATA • Conventional Cores) Yes 0 No 8 • Sidewall Cores Yes 0 No w 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 ND Permafrost-Top Well Tested? Yes 0 No Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 8860' 8526' separate sheets to this form,if needed,and submit detailed test information per 20'. AAC 25.071. Sag River 8758' 8428' Shublik 8799' 8467' Sadlerochit-Zone 4 8860' 8526' Zone 1B 9444' 8948' Base of Sadlerochit-Kavik 9520' 9006' Formation at total depth: Kavik 9520' 9006' 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 or well 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: Hibbert,Michael Authorized Title: SI ialist /' Contact Email: Michael.Hibbert@BP.com Authorized Signature: A /,� `Q Contact Phone: +1 907 564 4351 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 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 la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and ND 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,summaryof daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only S i WELL NAME: 05-18A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8630' Set Cast Iron Cement Retainer 8468'- 8473' Tubing Punch 6390' 115 Bbls Cement 1606' Cut Tubing 1495'- 1500' Tubing/Casing Punch Surface 145 Bbls Class 'G' • Daily Report of Well Operations 05-18A ACTIVITYDATE SUMMARY T/I/O = MV/600/380. Temp = SI. Bleed OAP to 0 psi (APE request). No AL. OA FL @ surface. Bled OAP from 380 psi to 0 psi in 30 min (1/2 bbl). Monitored for 30 min, OAP unchanged. Final WHPs = MV/600/0. 8/28/2017 SV, WV, SSV= C. MV= LOTO. 12:00 hrs. T/I/O = MV/600/10. Temp = SI. WHPs (post bleed). No AL. OAP increased 10 psi overnight. 8/29/2017 SV, WV, SSV= C. MV= LOTO. IA, OA= OTG. 16:45 T/I/O = MV/600/15. Temp = SI. WHPs (Post bleed). No AL. OAP increased 5 psi since 8/29/17. 8/31/2017 SV, WV, SSV= C. MV= LOTO. IA, OA= OTG. 13:30 hrs. 9/8/2017 Cost placeholder for marker plate Special Projects - Jobe Scope: Pre P&A Cement Chemical Inj. Line Injectivty test/warm chemical injection line w/warm hydraulic fluid. 1 gallon or 406' away and pressure reached 4000 psi. Line plugged. Will request to pull CI valve. 9/15/2017 ****Incomplete**** ***WELL S/I ON ARRIVAL*** (Pre injectivity test) SET 3-1/2"WHIDDON CATCHER SUB ON 3-1/2" WFD WRP AT 8,615' SLM. CURRENTLY POOH W/ BK-DGLV FROM CHEMICAL INJECTION MANDREL. 9/22/2017 ***JOB IN PROGRESS, CONTINUED ON 9/23/17 WSR*** T/I/O = 910/638/37 Job Scope: Cement Chemical Injection line. RU LRS pump and warm tubing after injectivity test. (See LRS AWGRS) Mix and inject 2.0 gallons of 14.0 ppg SqueezeCrete, 15.6 gallons of 80 deg fresh water and 3.2 gallons of 14.0 ppg SqueezeCrete. (Left sample on wellhead) Wait 48 hrs and pressure test cement to 2500 psi. ***Job 9/23/2017 Complete*** T/I/0=1076/620/37 Temp=Sl (LRS Unit 70 -Assist Slickline & Special Projects: Injectivity test, OA Pressure Test) Pumped 2 bbls 60/40 down TBG warming well 55 bbls Pumped 86 bbls of 60*crude for injectivity test: 1 bpm @ 88 psi 3 bpm @ 312 psi 5 bpm @ 755 psi Pumped 94 bbls of 150*crude to heat well bore While DHD pumped cement down checmical injection line. Pressured up OA to 500 psi w/ .20 bbls crude and monitor for 5 min. ( No visible surface leaks). Bled OA to 0 psi. bled back .20 bbls. Tags hung.AFE sign hung on well. SV WV SSV= closed. MV IA OA= open. 9/23/2017 FWHPS=280/630/0 ***CONTINUED FROM 9/22/17 WSR***(Pre injectivity test) PULL BK-DGLV FROM ST#1 (8,457' MD - Chemical injection mandrel). PURGE CHEMICAL INJECTION LINE W/ 15 GALLONS OF HYDRAULIC FLUID. PULL EMPTY 3-1/2" WHIDDON C-SUB FROM 8,615' SLM. BAIL 1/4 CUP OF ASPHALTINES OFF 3-1/2" WFD WRP AT 8,615' SLM. EQUALIZE & PULL 3-1/2"WFD WRP (Elements&slips intact) FROM 8,615' SLM. ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 9/23/2017 NOTE: CHEMICAL INJECTION MANDREL LEFT EMPTY PER PROGRAM. i • Daily Report of Well Operations 05-18A T/I/O = 2460/2370/Vac. Temp = SI Chemical injection line PT passed to 2810 psi. (Pre P&A). No AL. TBG FL @ 6260' (957' below#2, DMY). IA FL @ 5650' (347' below#2, DMY). OA FL = near surface. Used 2 quarts of 15.7 ppg AS-1 cement to pack chemical injection lines. The chemical injection line lost 22 psi over 15 minutes (2833 psi test). Dumped the SSSV and bled the TP to 380 psi in 5 minutes (Production, gas). The TP increased 20 psi in 15 minutes. Bled the IAP from 2370 psi to 2320 psi in 1 hour and 15 minutes (all gas, IA would not bleed lower). During the bleed the IA inflowed 150'. The IAP increased 70 psi in 5 minutes. During the IA bleed the OAP increased from a vac to 40 psi. Bled the OAP to 0 psi in 2 seconds (all gas). SLB SL on location to set TTP. 9/27/2017 **Continued on 9/28/17 WSR** ***WELL S/I UPON ARRIVAL**** (Plug &Abandonment) DRIFTED W/2.84" NO-GO TO TRSV @ 2,166' SLM /2,192' MD PERFORMED FLAPPER CHECKER ON 3-1/2" AVA TRSV @ 2,192' MD (Functioning properly) 9/27/2017 ****CONT. JOB ON 9/28/17**** T/I/O = 2400/2400/0 TEMP = 80* PPPOT-T(Tx I) FAIL PPPOT-T: Rig up test equipment on to test fitting. stung into void 1,400 psi on void, able to bleed void to 50+ psi. Monitored for 10 min, void gained 1000 psi in 10 min. Bled void down to 50+ psi torque all LDS to 450ft/Ib. Monitored for 10 min, void gained 1,000 psi in 10 min. Unable to pressure void, Unable to re-energize seal on FMC well head. Rig down test 9/27/2017 equipment. ****CONT. JOB FROM 9/27/17**** (Plug & abandonment) DRIFTED W/2.80" WRP DRIFT&2.50" LIB TO 6232' SLM, UNABLE TO WORK PAST. DRIFTED W/2.80" CENT&2.50" LIB TO DEPLOYMENT SLEEVE @ 8643' SLM.(impression on fn) ATTEMPT TO SET BAKER 3-1/2" CEMENT RETAINER, TOOLS S/D @ 6240' MD. DRIFTED W/2.80" GAUGE RING TO DEPLOYMENT SLEEVE @ 8643' SLM.(no issues) DRIFTED W/2.80"WRP DRIFT TO 6240' SLM, UNABLE TO WORK PAST. LRS LOADED IA WITH 430 BBLS OF CRUDE &TUBING WITH 120 BBLS OF CRUDE. SET 3 1/2" CAST IRON CEMENT RETAINER AT 8630' SLM 9/28/2017 ***CONT ON 9-29-17 WSR*** **Continued from 9/27/17 WSR** T/I/O = 430/2370/0. Monitor OAP during SLB SL work. Bleed TP & IAP to 600 psi post Cement Retainer set(Pre P&A). No AL. T FL @ 6260' (957' below#2, DMY). IA FL @ 5650' 9/28/2017 (347' below#2, DMY). OA FL near surface. SLB SL in control of well upon departure. 05:00 9/28/2017 LRS T-106 fluid support T/I/O= 2350/2320/0 Assist S-Line Load Well (P&A) Load Tbg w. 5 bbls60/40, 95 bbls crude, Load tbg w/5 bbls 60/40, 430 bbls crude. Load TBG again with 120 bbls of 120*crude. Pumped and additonal 7 bblsof 60*crude to assist SL down TBG. ***Job continued to 9/28/2017 9/29/2017 ***WSR continued from 9/28/2017. Pumped 6 bbls 60/40 meth and 6 bbls crude to FP FlowLine. Tag hung. SlickLine on well upon departure. 9/29/2017 FWHP= 343/716/vac valves= SlickLine T/I/O = 380/670Nac. Temp = SI. WHPs (Post cement retainer). No AL. 9/29/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 0730 hrs. ***CONT FROM 9-28-17 WSR*** RIG DOWN SWCP 4522 9/29/2017 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** T/I/O = 410/610NAC. Temp = SI. WHPs (WIE req). No AL. 10/21/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 04:45 S • Daily Report of Well Operations 05-18A 10/27/2017 Placecard Holder for the purchuse of Foam Balls for Plug &Abandonments T/I/O = 2250/620/Vac. Temp = SI. No AL. IA FL @ surface. 11/2/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 16:50 T/I/O = 2190/1730/VAC. Temp = SI. T & IA FL (eval secure). No AL. Integral installed on flowcross companion =inspection not current. T FL @ 7429' (sta#4 DMY, 66 bbls). IA FL @ 2100' (71 bbls). 11/5/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 19:30 ***WELL S/I ON ARRIVAL*** (SLB ELINE TUBING PUNCH) INITIAL T/I/O = 2100/1700/0 PSI. MIRU. 11/5/2017 ***JOB CONTINUED 6-NOV-2017*** ***JOB CONTINUED FROM 5-NOV-2017***(SLB ELINE TUBING PUNCH) FINISH R/U. LPT/HPT= PASS. LRS R/U AND LOAD IA W/210 BBL'S OF CRUDE, TUBING W/ 100 BBL'S OF CRUDE. RIH W/ MH-22 (1.375" FN)/SWIVEL/WB(X2)/CCL/MPD/5'X 1.56" TUBING PUNCHER, SMALL CHARGES 4 SPF, 0 DEG PHASING/SPD. OAL = 29', OAW= 250 LBS, MAX OD = 1.69". TIE INTO TUBING TALLY 30-OCT-1989. TAG CEMENT RETAINER AT 8644' ELMD. TUBING PUNCH INTERVAL = 8468' -8473'. CCL TO TOP SHOT = 5.7', CCL STOP DEPTH = 8462.3'. POOH, RDMO. FINAL T/I/O = 600/300/0. 11/6/2017 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** T/I/0=2100/1570/vac SI Assist EL as directed (PLUG AND ABANDONMENT) Pumped 2 bbls 60/40 followed by 210 bbls crude down IA to load for EL. Pumped 2 bbls 60/40 followed by 100 bbls crude down TBG to load for EL. EL on well upon departure. CVs OTG 11/6/2017 FWHP=300/600/0 SLB Cementers -Job Scope: Stage 1 of 2. Cement perfs, tbg, and IA up to 5650' MIRU, Displace/load IA and tbg w/soap/musol wash, FW, and 107 bbls Diesel in IA from surface to 2947'. Pump 14 bbls 15.8 cement to perfs floowed by 1-1/4 ball to retainer @ 8630. 300 psi increase in pump pressure when ball on seat @ 76 bbls away (calc volume 75 bbls). Followed w/ 115 bbls cement(planned for 122 bbls but ran out of cement) Dispace cement w/ 2 foam balls and 34 bbls FW and 22 bbls diesel. Circ cement into IA from tbg punch holes @ 8473' . Returns into PC leak @ 6150'. Last 22 bbls returns taken from IA into 40 bbl tank 1:1 returns. Tbg and IA FP'd w/diesel to 2500'. ******Job Complete****** Tbg Fluids: Diesel 0 -2480' ( 0 -2480'TVD); FW 2480' -6390' ( 2480' -6272' TVD); Cement 6390' - 9510 (6272' -9001 TVD) bttm perf IA Fluids: Diesel 0 -2500' (0 -2500' TVD ) FW 2500' - 5620' ( 2500 - 5586' TVD) Cement 5620' - 8473' ( 5586' - 8154' TVD) tbg punch holes 11/8/2017 T/I/0=167/0/0 Assist S-Line MIT-IA Passed to 2006 psi. Max Applied Pressure= 2250 psi, Target pressure= 2000 psi. Pressured IA to 2250 psi w/2.5 bbls crude. Loss of 142 psi 1st 15 min. Loss of 69 psi for a total loss of 211 psi during 30 min test. Bled IA to 0 psi. 11/14/2017 FWHP=270/0/0 Casing valves OTG. S-Line on location upon departure. • Daily Report of Well Operations 05-18A ****WELL S/I UPON ARRIVAL**** (Plug &Abandonment) DRIFTED W/2.25" CENT, 1-3/4" SAMPLE BAILER, TAG TOC @ 3,412' SLM (Sample of cement) RAN 3-1/2" BLB, 2.62" GAUGE RING TO 2,000' SLM, BRUSHED TRSV(Recovered partial wiper ball) LRS PERFORMED PASSING MIT-IA TO 2,000 psi (See LRS log) 11/14/2017 ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** T/I/0=167/0/0 Assist S-Line MIT-IA Passed to 2006 psi. Max Applied Pressure= 2250 psi, Target pressure= 2000 psi. Pressured IA to 2250 psi w/2.5 bbls crude. Loss of 142 psi 1st 15 min. Loss of 69 psi for a total loss of 211 psi during 30 min test. Bled IA to 0 psi. 11/14/2017 FWHP=270/0/0 Casing valves OTG. S-Line on location upon departure. T/I/0=167/0/0 (LRS Unit 72 -Assist Slickline: MIT-IA Post Cement Job) MIT-IA***PASSED***to 2006 psi. Max Applied Pressure= 2250 psi, Target pressure= 2000 psi. Pressured IA to 2250 psi w/2.5 bbls crude. Loss of 142 psi 1st 15 min. Loss of 69 psi for a total loss of 211 psi during 30 min test. Bled IA to 0 psi. Casing valves OTG. S-Line on location upon departure. 11/14/2017 FWHP=270/0/0 T/I/O =VacNacNac. Temp = SI. T& IA FL's (Fullbore request). AL spool disconnected. T & IA FL's near surface. 11/14/2017 SLB in control of well. 05:20. ***WELL S/I ON ARRIVAL*** (Plug and abandon) TAG TOP OF CEMENT @ 3,458' SLM W/2.25" CENT, 1-3/4" S-BAILER (Sample of contaminated cement) DHD PERFORMED PASSING MIT-T TO 2,000psi TAG TOP OF CEMENT @ 3,462' SLM W/2.25" CENT, 4'x 1-3/4" DRIVE DOWN BAILER (Sample of contaminated cement) DHD PERFORMED PASSING MIT-IA TO 2,000psi JOB INCOMPLETE, WILL RETURN AFTER WEATHER IMPROVES TO PULL AVA- 12/7/2017 BRAIN. T/I/O = 304/290/VAC. Temp = SI. AOGCC MIT-T & MIT-IA both PASSED (assist SL). T & IA FL @ surface. Pumped 1.7 bbls of diesel down T to increase TP from 304 psi to 2500 psi in 20 min. TP lost 148 psi in 1st 15 min, TP lost 49 in 2nd 15 min fora 30 min total of 197 psi. Pumped 2.0 bbls down IA to increase IAP from 43 psi to 2500 psi in 10 min. IAP lost 163 psi in 1st 15 min, IAP lost 77 psi in 2nd 15 min fora 30 min total of 240 psi in 30 min. Bled TP to 10 psi, 2.2 bbls. Bled IAP to 40 psi, 1.9 bbls. Tags hung. Final WHPs = 30/40NAC. 12/7/2017 SL in control of well upon departure. 20:30 ***WELL S/I ON ARRIVAL***(Plug &Abandonment) TAG TOC AT 3,484' MD W/2.25" CENT, 1-3/4" DD BAILER (Sample of dry cement/AOGCC witnessed). MADE TWO ATTEMPTS TO PULL AVA BRAIN AT 2,170' SLM (Cracked skirt on pulling tool both times). AVA BRAIN CEMENTED IN PLACE AFTER CHEMICAL INJ. LINE WAS CEMENTED (Lines linked together). 12/9/2017 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** T/I/O = 150/130Nac. Temp = SI. T, IA& OA FL's (E-line Request). No AL. T FL near surface, IA FL @ surface, OA FL near surface. 12/14/2017 SV= C. WV, SSV, MV= 0. IA, OA= OTG. 20:15. • • Daily Report of Well Operations 05-18A ***JOB STARTED ON 18-DECEMBER-2017*** (SLB ELINE JET CUT/ PERF) INITIAL T/I/O = 100/20/20 RU.PT. RIH W/ HEAD(FN 1 3/8") 2.875" JET CUTTER (MAX OD). CCL TO MID CUTTER = 10.6'. CCL STOP DEPTH = 1595.4'. CUT TUBING AT 1606'. GOOD INDICATION OF SHOT, TBG LOST 100 PSI. 12/18/2017 JOB CONTINUED 19-DECEMBER-2017 T/I/0 = SSV/120/160. Temp = S/I. WHP Post ELine shooting holes through TBG and IA to OA. MIRU small volume cementing equipment. mix 5 gallons of SLB untra-fine SqueezeCrete cement 14.0 ppg Inject 1 gallon down balance line (rear) and 1.5 gallons down control line (front). Sample of cement was placed on wellhead. DHD to return in 48 hours to pressure test. ***DSO notified of well status and future activities*** 12/19/2017 ***JOB CONTINUED FROM 19-DECEMBER-2017*** (SLB ELINE JET CUT/ PERF) RIH RUN 2 W/5' X 2" POWERFLOW 2006 HMX. 6 SPF, 60 DEG PHASING. PERFORATE 1495' - 1500'. CCL TO TOP SHOT= 5.4'. CCL STOP DEPTH = 1489.6'. GOOD INDICATION OF SHOT. POOH. PUMP DIESEL DOWN FRONT AND BACK CONTROL LINE W/TRIPLEX. CIRCULATE DIESEL W/TRIPLEX FROM TUBING TO IA,TAKING RETURNS TO BLEED TRAILER CIRCULATE DIESEL W/TRIPLEX FROMTUBING TO OA,TAKING RETURNS TO BLEED TRAILER. RDMO. WELL SHUT IN ON DEPARTURE. FINAL T/I/O = 0/100/140 12/19/2017 ***JOB COMPLETE ON 19-DECEMBER-2017*** T/I/O = SSV/0/0. Temp = SI. PT C & B lines (Pre P&A). No AL. Hardline rigged up for cementing. Balance line PT passed to 2908 psi. Control line PT passed to 3181 psi. 12/21/2017 SV, WV, SSV= C. MV= O. IA, OA= C (flagged). 1250 hrs. T/I/O=0/0/0 SI Injectivity Test (PLUG AND ABANDONMENT) Pumped total of 12 bbls DSL down TBG to establish injection rates. Injectivity through tubing punches pumping diesel down TBG, taking returns up OA to tank- 5 bpm @ 550 psi. Injectivity through tubing punches pumping diesel down TBG, taking returns up IA to tank- 5 bpm @ 150 psi. WSL/DSO notified Valve positions=SV CV SSV WV CVs closed MV open Hardline to tanks 12/22/2017 SI FWHP=40/10/10 SLB Fullbore Pumping Crew. Job Scope: Plug &Abandonment cement down 3 1/2" TBG taking returns from OA Pumped 5 spear of 60/40 methanol/water, 50 bbl 147 deg F. fresh water pill w/U67 & F103 followed by 100 bbls of fresh water, Clean returns observed mid point of 100 bbls fresh water returned to surface. Pumped 5 bbl fresh water spacer then pumped 145 bbls of 15.8 ppg cement down TBG taking returns from OA until clean cement seen at tank then realined lines to start taking returns form IA until clean cement at return tanks. Shut down flushed and freeze protected surface lines. Hung tags on Master, tree and wellhead valves serviced. DSO notified. Class G Cement in TBG from 1500'MD/ 1500' TVD to Surface Class G Cement in IA from 1500' MD/ 1500' TVD to Surface Class G Cement in OA from 1500' MD/ 1500' TVD to Surface 12/23/2017 ***Job complete*** Abandonment/Suspension. Job Scope: Hydro esxcavation. Set up and start process 4' in front of wellhouse wash/dig/trench looking for anomolies found during survaying for excavation and cutting of wellhead for abandonment/Suspension. Suspend operation tell 5/1/2018 next morning. • • Daily Report of Well Operations 05-18A Abandonment/Suspension. Job Scope: Hydro esxcavation. Set up and start process 4' in front of wellhouse wash/dig/trench looking for anomolies found during surveying for 5/2/2018 excavation and cutting of wellhead for abandonment/Suspension. Suspend operation till next Excavate Around Wellhead for Plug &Abandonment. Used an excavator to excavate around wellhead to a depth of—5' to allow for the Goliath Saw to be placed on the tree to cut the tree off at 1' below pad grade. The footprint of the excavtion hole is —30'x30' (15' out from each side of wellhead). The bottom of the hole is 10'x10' at the 5' depth, with the sides sloping out and up at 2to1 slope (no confined space).. All material removed was manifested to GNI (-81 5/3/2018 cy). Placed baricades and open excavation signs around excavation hole. Job Scope: Pug and Abandonment- Prep for wellhead cut Stage equipment, install Goliath saw, verify barriers, Tested IA to 1375 psi w/gas 5/4/2018 Cont on WSR 5/5/18 5/5/2018 Job Scope: Plug and Abandonment- Diagnostics for wellhead cut and removal. High winds. Job Scope- Plug and Abandonment Prep. Attempt to remove liquid from IA. Unable to insert hose. Dump 1 sack of bentonite and 2 sacks of AS1 into IA to gunk up free liquid. Top of Inner annulus w/ 1.3 bbls AS1 cement. Thaw ice/snow from excavation and from around saw w/ 5/6/2018 portable heaters Job Scope: Plug and Abandonment- Cut Wellhead 2.5' below pad grade. TOC in Tbg @ 17', IA @ surface, OA 2.5', Conductor @ 3.3'. AOGCC inspection then topped off all strings to 5/8/2018 surface w/ 1.08 bbls Arctic Set cement. Job Scope: Plug and abandonment. 5/9/2018 AOGCC inspection, take final pictures and Install marker plate Casing stub cement top inspected by Austin Mcleod (AOGCC). Stub cap installed (pictures 5/9/2018 taken). k #„ � , ,r k ♦y", %" f ' C, .}_+%"�• ytewP'rv.»w+«r.7. +ymsrs�M4i ' ' .f♦' �.,�^-.{j• , � .,- 5 1-, ;7 , 1.1,',"..‘•41- a ! *.t.0,0"-4,, ,a{ , , w,t # �; >"7 �-,P , " „,:c Ave."! ' 4/rt�. X %f *' ,Y r -s*. . t s ! tT � • • ▪"E* : d ,' } � F ltr4 F • r . « 1.o- � 'F ;"."$'7."'' „ ' ice' '�,��dPr : i�; .- • Y r ;"f `•A t fy }x s' � ..i'° �` o:e 4 s 'v { , � ' } `s # 0" f ▪j' 4 '*4 a . •..., „,/..-..:1•47. y• te � F' 1 p„ , le 441 .00v: At '44.* . 7 S d. �1d 7. 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', . des I.r .r.,- w= s I TTZEE= FMC STES:WELLHEAD CUT OFF 2.5'BELOW PAD EL 4VLFEAD= FMC SUSPIALED G SMENT TO SURFACE,MARKER CAP ACTUATOR= AXELSON 0 5-1 A KB.ELEV= 68' INSTALLED,t3ACKRJLLED 05109r18 BF.ELEV #1i+###'*#1i1+. &A 63' --{4-1/2"X3-1/2"XO,0=2.992" KOP= 4900' 1.+►�♦####,,•'r•a 410 41, -4. Max Angle 57'g 9030' OAT TO SURFACE - 1500' i /'# !a 1496' 1500' -1 TBG PUNCH 6 SPF(12/19/17) I Datum MD= 9342' TBG/IA/OA 1606' -I JET CUT TBG(12118/17) Datum ND= 8800'SS (12/23/17) 2192' -3-11/2-AVATRSVSSSV,D=2.812" 4-1/2"TBG-PC,12.6#,L-80, H 63' GAS UFT MANDf24iS .0152 bpf,D=3.958" ST MD ND DEV TYPE V LV LATCH PORT GATE [10-3/4"CSG,45.5#,L-80,D=9.953" (- 361T J / 1 3097 3096 TGPD DEti nr TG 0 04/07/02 CEMENTED LA(11/08/17) -{ 6620' -8473' ..4 TO r4 2 5303 5290 17 TGPD DRAY TG 0 04/07/02 !�?�7►♦ 3 6656 6508 27 TGR) DAtY TG 0 CEMENTED TED TBG(11/08/17) -{6390'-9610' ##i�����#�j`f�i 4 7429 7196 27 TGPD DMY TG 0 04/07/02 i##### 6$ ##1�'k*###1�►*#'� 5 7781 7513 25 TGPD DMY TG 0 Minimum ID = 1.25" 9388' .41104i•••••4#+Ii�i�iCs:'�#'� @ 6 8074 7781 23 _ TGPD DMY TO 0 4`4140##'••41 6#;4 Cl EMC AL MANDRELS WFD ER PATCH i*•+#Ir•,1 #4 TBG PUNCH,6 SPF(t 1!06!17) 8468'-8473' ,166•4:440414.4414: . ST MD ND DEV TYPE VLV LATCH PORT DATE_!_� I`01:41:16:411: 7 8457 8071 18 CA-KBUG-LT B,FTY - - 09/23117 �#►####j �*t###thj� 8639' -13-1/7 OTIS STRAIGHT SLOT LOC SEAL ASSY ####� F • .:.,►�� 8541' -7-5/8"X 3-1/2"OTIS WPERM 00 C.:. WD PERM ••••. PKR(8850'ELM 08/28/89) ####,1 '######++1' 8646' -{3-1/2"SEAL BORE E XT/MLLOUT EXT •######� TOP OF 5-112"LNR - 8693' ###4##CO1/#1 �,%% j -8630' -1 3-1/2"BKR I-I-t CAST ERON CMT RETAINER(09/28/17) ####' , 410 TOP OF 2-3/8"LNR -� 8703' 1 I III. 8697' -12-78"DE33 SLV ii►*#!4 •#4 ►## *#•4 8816' _13-1/2"OTIS XN NP,ID=2.75" ►####4 ►*###4 #4 I ►*•4* 3-1/T TBG-FO,9.3#,L-80, -I 8827' F###,44 8827' --{3-1/2"1M.EG,D=2.992" .0087bpf,D=2.992' ##4 �* **4 -I E LMO TT NOT LOGGED ► 41 ####4 ##4 114146 7-5/8"CSG,29.7#,L-80.0=6.875" -1 8871' ►####4 ##4 * +�*#*4 1ALLOUT WMDOw(05-18A) 8888' #4 ##1 PERFORATION SUN/MARY • ####4 #• 411 1 4*# 9388'9462' 1.80 WFD 1302 f32 PATCH(06/21/09),D=1.25" REF LOG:SVVS MCNL ON 11/05/98 11(►###* -- - ---- 1* #�##...*.f.. ANGLE AT TOP PERE:38'@ 9400' /11'• �......f#,• Note:Refer to Production TB for historicalpert data 1111111111•�+4. #*#` 1111111 ..�.#. SIZE SPF INTERVAL Opn/Sgz DATE 111111111111111 ..70.... Nip 9676' -�2-3/8"PACK OFF BUSHING,D=1.0" 4 11111111AN- 1-11/16 6 9400-9414 C 04/16/02 '�##�.gI 1111111 i 11111111 A%-41040 1-11/16" 4 9423 9443 C 03126/01 1111111 , 11111111 -wig##•'4 1-11/16' 4 9465-9485 S 11/08/17 1111111 ##### 1-11/16" 4 9490-9510 S 11/08/17 11111111 1 ;i4 #� 11111111 11111 +���+:,oei4 1111111 •• 11111111 6.6.6.6.4.4.6.1 Olt Oil- 410111. 2-3/8'LNR,4.4#,L-80, -1 9593' .0039 bpf,D=1.995" 5-1/2"LNR,17#,L-80,.0232 bpf,ID=4.892" -1 9377' TD H 9696' DATE REV BY COt,fvEE34TS DATE REV BY COMMENT'S PRIDHOE BAY UNIT 11/89 ORIGINAL COMPLETION 11/13/17 AB/JVD CMT EA&TBG(11/08/17) WELL: 05-18A 10/29/98 SIDETRACKED 12/21/17 NXW/JMD JET CUT TBG&TEIG/CSG R.*ICH Pff2MT No:'1981740 02/09/02 RTVTP CORRECTIONS 12/27/17 DMS/JM)CMT TO SURFACE TEBG/IA/OA AR No: 50-029-21960-01 09/26/17 JPK/JMD C!ENACAL MANDREL C/O 05/09/18 AB/JM) SUSFB'DE D SEC 32,T11 N,R15E,2188.96'FR.,2137.99'FINE 10/11/17 LLG/JMD SET CAST RON CMT RET(9/28/17) 11/07/17 MS/J6.4) TBG PUNCH(11/06/17) BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commis ion TO: Jim Regg I`eti DATE: 5/9/18 P. I. Supervisor FROM: Austin McLeod SUBJECT: Surface Abandon (Temporary) Matt Herrera PBU 05-18A Petroleum Inspectors BPXA PTD 198-174; Sundry 317-182 - 5/812018: Matt and I traveled to PBU DS5 and met up with Arvell Bass to observe a cut off and suspension of well 18A. All strings of pipe were found to be full of set up cement at surface and cut off 21/2 feet below pad level. The marker plate installed was NOT welded but yet a "set on/bolt on" which did have slight overhang of outermost casing string (mainly bolt heads). The plate did have all the proper markings bead welded onto it (see photos) and was %" thick. BPXA's rep was reminded that at pad remediation all ,/ strings must be cut to 3' below tundra grade and a marker plate with the same above information must be welded and not extend past the outermost casing string. Because the cutoff depth and temporary marker plate do not meet final abandonment requirements, PBU 05-18A is classified as SUSPENDED in AOGCC well records. SCAMS JUN 0 1 2018 Attachments: Photos 2018-0508_Surface_Abandon_temp_PBU_05-18A_am.docx Page 1 of 3 e • Surface Abandonment (Temporary) — PBU 05-18A (PTD 1981740) Photos by AOGCC Inspector A. McLeod 5/8/2018 , ' e. .• 66.7015 1 ' ,,,,'" "' . ------ . '0,-..•-_-7. lik. , , , " -1 ..._. , �. 1 a x d. µt01 t$+s •` w, . F'.1.sx";"mit ,k.,rl; 1.'''' ; "'..i.-•7''...;."-• zr 6m' f 'S a4 c' Cutoff depth 2.5 ft xw . • below pad level J . , t t �� r i j k ��Fi'' 1' fir.; �,."ti+i AeV I. , f b^'i F� .! .17. ,[� r I r .. . t' yeti {!r __N.,.., .,, r''''''' :,4' :,'; f C # tr` r 4Y-,/ yr • ...rr. > ars , tM". ! �' !.4.11:,,,a,‘,4"::.,,yy.ma, } a F #` 4 Cement to surface; t'.„la r" �� ,A , ``F, ; ' all strings ,r. •• 1. M t' fiy t !sr+ 2018-0508_Surface_Abandon_temp_PBU_05-18A_am.docx Page 2 of 3 • • 4'� •e.. ,t .S3rs, 7•4.-_. S R "t t 1 p,.,, !j� t• cit' ;4 3; ter , ,, � r , .,, 7 1 , � R� / -;,,,a,';ii.- '''*, .. tr-1.0,..ft- P.:iv,, .74:;-* 'I-' ''' •7. �rr;:i�1to i rvn} ;�! t + d k + S n '1 `{� v. • „� 4 'x ate , ' `1'-t. h y` -..e,`. R Temporary bolt-on marker plate PBU 2018 0508 Surface Abandon temp 05-18A am.docx Page 3 of 3 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Z4�Z''� 7 DATE: 12/09/17 P. I. Supervisor FROM: Guy Cook SUBJECT: Plug Verification Petroleum Inspector PBU 05-18A - BP Exploration Alaska Inc. PTD 198-174 Sundry 317-182 - 12/07/17: The job started on the 7th of December 2017. I arrived on site and met with Dan Gray with BP Exploration Alaska and discussed the job. Schlumberger slick-line unit was on site to tag the cement and bring back a sample. ASRC DHD was also on site for the MIT-Tubing (MIT-T) and the MIT-Inner Annulus (MIT-IA). The job was also discussed with these gentlemen. The job started with slickine tagging cement at 3456 feet and bailing to 3458 feet. They were running a 1.5-inch bailer that was 2 feet long with a ball valve. The sample was contaminated with no signs of solid cement. After the first run with the slickline unit, the MIT-T was performed to 2500 psi. The MIT-T passed. The second run with slickline tagged at 3458 feet and was driven down to 3462 feet. For this run they changed bailers— at my request—to a 1 %-inch bailer that was 4 feet long with a flapper valve. The sample showed contaminated cement, but the cement was firmer with less liquid than the previous run. They proceeded on with the MIT-IA as weather was getting bad and the wind speed forced slickline to rig down their equipment for the day. The well passed a 2500 psi MIT-IA. After the MIT-IA it was decided to wrap up the job for the day and to return after weather improved and the location had been cleared of snow drifts. 12/09/17: I returned to the job-site and witnessed the Schlumberger slickline bailing on the well. They made two more runs with a 1 %-inch drive-down bailer that was 4 feet long and equipped with a flapper valve. After the first run, and bailing down to 3455 feet, the sample produced a small amount of good cured cement. The last run, bailing back down to 3462 feet, produced a good sample of cured cement that all but filled the bailer. Summary: I witnessed the successful abandonment plug verification on PBU 05-18A. I informed Dan Gray that they could move on with the rest of their P&A operations for this well. Attachments: MIT-T; MIT-IA; Photo SCANNED 2017-1209_Plug_Verification_PBU_05-18A_gc.docx Page 1 of 2 • 0 X U O b U oo in ' PQ x �� NP A, N 2 N y N % A ,, �� 10 ,,,,j.,'' N 0 ,., l ti T"' o � N CO 0) Ci Os o 0 < 0 CO IA L- 0 0 n U cow a a is cU O▪ 0 C.) O CD ID C CD o rn 0 0 c• "--i • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ---7DATE: Monday,December 11,2017 P.I.Supervisor r 1(\670/11 \670/�j //Z/� 7 SUBJECT: Mechanical Integrity Tests l ` / BP EXPLORATION(ALASKA)INC. 05-18A FROM: Guy Cook PRUDHOE BAY UNIT 05-18A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 05-18A API Well Number 50-029-21960-01-00 Inspector Name: Guy Cook Permit Number: 198-174-0 Inspection Date: 12/7/2017 Insp Num: mitGDC171210132321 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well O5-18A Type Inj i N 'TVD Tubing 304 2500 2352 - 2303 - PTD 1981740 -,Type Test[SPT Test psi 2500 . IA 5 75 . 110 - 139 - BBL Pumped: - OA 0 0 0 0 1.7 BBL Returned: 2.2 Interval OTHER P/F P Notes: MIT-T required for P&A.Sundry#317-182 i Monday,December 11,2017 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,December 11,2017 P.I.Supervisor t Z Z1 I c'� SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 05-18A FROM: Guy Cook PRUDHOE BAY UNIT 05-18A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J6t2--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 05-18A API Well Number 50-029-21960-01-00 Inspector Name: Guy Cook Permit Number: 198-174-0 Inspection Date: 12/7/2017 Insp Num: mitGDC171210132641 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 05-18A Type Inj N'TVD 1 Tubing 18 233 • 243 - 238 - — PTD 1981740 - Type Test SPT Test psi 2500 IA 43 2500 2337 2260 - ------- -- - BBL Pumped: 2 BBL Returned: 1.9 • OA 0 0 0 0 Interval OTHER [P/F P ✓ Notes: MIT-IA for P&A.Sundry#317-182 Monday,December 11,2017 Page 1 of 1 • • • • y of Tb �•\�\�yyy,s� THE STATE Alaska Oil and Gas N ►' ►ts ofA L A S KA Conservation Commission 333 West Seventh Avenue 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o ,;,,m ` Main: 907.279.1433 ALASY)*. Fax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert Well Interventions Engineer %AH MED ,!I.J 0 5?r 17, BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt. Prudhoe Bay Oil Pool, PBU 05-18A Permit to Drill Number: 198-174 Sundry Number: 317-182 Dear Mr. Hibbert: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 6 day of June, 2017. RBDMS C. (JUt4 - 2 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend m • Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 198-174" 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development 0 99519-66126.6. API Number: 50-029-21960-01-00" Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I3 PBU 05-18A • RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028326. PRUDHOE BAY,PRUDHOE OIL- MAY 0 4 2017 11. PRESENT WELL CONDITION SUMMARY ,A Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): JAC QOC 9595• 9064 - 8600 8276 8600 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 34-114 34-114 1490 470 Surface 3484 10-3/4" 34-3518 36-3517 5210 2480 Intermediate 8839 7-5/8" 34-8870 34-8536 6890 4790 Liner 295 5-1/2" 8593-8888 8269-8553 7740 6280 Liner 898 2-3/8" 8697-9595 8369-9064 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9400-9510 8913-8998 4-1/2",12.6#x 3-1/2",9.3# L-80 30-8825 Packers and SSSV Type: 3-1/2"Otis WD Packer Packers and SSSV MD(ft)and TVD(ft): 8538/8217 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic ® 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory 0 Stratigraphic El Development ® • Service 0 14.Estimated Date for Commencing Operations: July 1,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended ® • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert,Michael be deviated from without prior written approval. Contact Email: Michael.Hibbert@BP.com Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions Engineer Authorized Signature: ''' ::•`.\W-- Date: 573/i 7. COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: • � ?jk7- 14� Z Plug Integrity IV BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 19' KSc (,‘,1, 01q Other: v 0 h 7c7 /tr7 a C 4 1 y2 re j-z,r Gt ✓I al p h b ,fb of e,C Li t`l' Post Initial Injection MIT Req'd? Yes El No Spacing Exception Required? Yes❑ No I3l Subsequent Form Required: J 3- b 0� r APPROVED BYTHE / Approved by: • COMMISSIONER COMMISSION Date:a/(/(? vrl- /31117— ORIGINAL 31117-- ORIGINAL RBDMS C L JUN - 2 2017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. ���� Attachments in Duple 17 i • Well: 5- 18 5-18 Suspend Well Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Finn Oestgaard (907) 564-5026 History GPB Well 5-18 was initially drilled & completed in August 1989. The initial completion was in the 13P sands of Zone 1A. The well was side-tracked in 1998. In February 2010 an LDL confirmed a production casing leak @ 6150'. ✓ Well 5-18 has no future utility and has been fully approved by co-owners for permanent abandonment. Objective Place reservoir cement plug, lower lateral cement plug, lateral surface cement plug and cut off tubulars and wellhead at surface. The well will remain in suspended status until final removal of the casings and welding of marker plate 3' below original Tundra level. Procedural Steps Slickline & Fullbore 1. OA integrity test. 2. Pull WRP, confirm injectivity into tubing Eline 3. 5' Tubing punch @ 8520'-8525'. 4. Set plug with ball-drop seat @ 8680'. Fullbore— Place Cement Plug #1 5. Place reservoir and lower cement plug — Liner cement, isolating ball, tubing and IA cement. Target TOC at 7700' in tubing and IA. • Liner volume = 3.2 bbls + 10 bbls excess • 3-1/2" tubing volume up to 7700' MD = 8.7 bbls • 3-1/2" x 7-5/8" annulus volume from packer to 7700' MD = 27.9 bbls • Total cement to pump = 13.2 + 8.7 + 27.9 = 49.8 bbls of Class G Cement • Pump the following pump schedule: i. 5 bbls fresh water spacer ii. 13.2 bbls of Class G Cement iii. Isolation ball iv. 36.6 bbls of Class G Cement v. Two 6" foam balls followed by 45 bbls seawater displacement vi. Freeze protect cap to 2500' —22 bbls of diesel/crude • Cement Calculations —Cement Plug #1 Total cement to pump 50 bbls Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab+/-0.1 ppg Slurry Temperature 80°to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 1 Safety 2 Minimum required thickening time: 5 Cement Ramp for Blend Time Volume Pumped Temperature Pressure (bbls) (°F) (psi) 0:00 0 100 0 0:30 50 150 3870 1:00 117 170 3380 2:00 117 180 3380 3:00 117 185 3380 4:00 117 190 3380 5:00 117 191 3380 Slickline 6. Drift and tag TOC with sample bailer. Notify AOGCC Inspector of the timing of the Cement plug tag and pressure test. (24 hour minimum notice). 7. MIT-T to 2000 psi Eline 8. Perforate through 3-1/2" tubing, and 7-5/8" casing @ -1500' MD. 9. Set 3-1/2" CIBP @ 1550' MD. Fullbore— Place lateral surface cement plug 10. Rigup on well to be able to pump into the tubing and take returns up the IA and OA. 11. Circulate well with hot seawater/KCL to remove any arctic pack and/or hydrocarbons from the wellbore and annuli. 12. Cement volumes to pump: • Tubing volume = 13.5 bbls • IA volume = 51 bbls • OA volume = 59.5 bbls • Total cement volume = 124 bbls of Class G Cement • • 13. Pump 10 bbl FW spacer followed by 124 bbls + of Class G cement down the tubing taking returns of the OA until clean returns are verified at surface, then begin taking returns up the IA until clean returns are verified at surface. Cement Calculations-Cement Plug #2 Total cement to pump -150 bbls (25 bbls of excess) Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab+/-0.1 ppg Slurry Temperature 80°to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 1 Safety 2 Minimum required thickening time: 5 Cement Ramp for Blend Volume Pumped Temperature Pressure Time (bbls) (°F) (psi) 0:00 0 100 0 0:30 50 90 1230 1:00 117 80 1230 2:00 117 70 1230 3:00 117 60 1230 4:00 117 50 1230 5:00 117 40 1230 e Ph �a vti� do t-"vrn Special Projects U ) 14. Notify AOGCC Inspector of wellhead removal. (24 hour minimum notice) 15. Cut off all casings and wellhead -1' below pad level. Install marker capon outermost casing string. Note: Final excavation, casing removal to 3' below tundra, and marker plat welding to occur at pad remediation. Pre Job Schematic 3 • I rttE= FMC WELLHEAD �= AXELSON 05-1 8 A FMC SAFETY NOTES: KB.a.EV= 68 BF.t3_EV= ? KOP= 4900 Li/ 63' F.L._-1/2" I Minx Angle= 57 a 9030' Datum MD= 9342' Datum ND= 8800'SS j fix'- I 2192' H3-1/2'AVA TRSV SSSV,D=2.812" I 4-1/7 TBG-FC,12.6#.L-80, --I 63' I/f GAS LFT MANDRELS .0152 bpf,D=3.958" ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3097 3096 1 TGPO DMY TO 0 04/07/02 2 5303 5290 17 TGPD DPM TO 0 04/07/02 M 3 6656 65081 27 TORO DPM TO 0 I, D 10-3/4"CSG,45.5#,1-80, =9.953' —1 3517' 4 7429 7196 27 TORO DMN TO 0 04/07/02 . 5 807 751 25 TGPD DPM TG 0 6 80744 7788 1 23 TCDD DPA' TG 0 CHEMICAL MANDRELS CW ST ME) ND DEV TYPE VLV LATCH PORT DATE Minimum ID = 1.25"@ 9388' 1 8457 8071 18 CA-KBUGLT BK-2 WFD ER PATCH 8539' H3-1/2'OTS STRAIGHT SLOT LOC SEAL ASSY I �w M 8541' H7-5/8"X 3.1/2'OTS WD PERM R(R(8850'ELM 08/28/89) I 8545' H3-112"SEAL BORE EXT/MLLOUT EXT I _ 1 TOP OF5 112'LNR f I 8593' 0� ✓ I 8600' I--13.1/2'WPP(2.78'OD)-SET 0U13H0 , I TOP OF 2- a a LNR I-1 8703' I 1 1 I 8697' H2-7/8"DEPSiv I 1 { I I-- I 8816' 143-1/2"CMS XN NP,D=2.75' I 3-1/7 TBG-FC,9.34,1-80, 8827" i k L 8827' H3.1/7 1M.EG.D=2.997 I .0087 bpf,D=2.992' I HB-MD TT NOT LOGGED I 17-5/8'CSG,29.7#,L-80,ID=6.875" H 8871' I MLLOUT WIJDOW(05-18A) 8888' PERFORATION SUMMARY ,• REF LOG:SWS MCtJL ON 11/05198 r 19388'-9452'H1.80'WFD 13C/t B2 PATCH(O6/21/09i.ID r.1.25'I ANGLE AT TOP PERF:38 @ 9400' 1 4w No Note:Refer to Production D8 for historical pert data 0I��♦ `F 04/44.11.11 y3 s Iv SIZE SPF IVIERVAL Opn/Sgz DATE 11/111 9575' 2-318'PACK-OFF BUSHIJG.D=1.0' I 1-11/16' 6 9400-9414 0 04/16/02 '!111111 1-11/16' 4 9423-9443 0 03/26/01 1111111 ti,1-11/16' 4 9465-9485 0 11/05/98 11H111111111 1-11116' 4 9490-9510 0 11105/98 1.1+1111111 M 1111 INA. 4,.1111 elVAIVArt /111 2.3/8"LNR.4.4#,L-80. I--I 9593' 1 �'V -0039 bpf,D=1.995' D I r I 15-1/2'LNR,17#,L-80,.0232 bpi, =4.897 H 9377' TD 9595' DATE REV BY COMMENTS DATE REV BY 1 COMMENTS PRUD OEBAY U4T 11189 ORIGINAL COMPLETION 01/3110 G JF.!P...0 SET WRP101/13/101 WELL:05-18A 10/29/98 SIDETRAC KB) REMIT No:'981740 02/09/02 RWTP CORRECTIONS AR No: 50-029-21960-01 06/27/09 3KDrTLH PATO-1 SET(06/21/09) - SEC 32.T1 1N,R15E 2188.96'FEL.2137.99`FRL 12/09/09 JMFSV SET WRP(12/08/09) 01/01/10 BSERPC RILED WRP(12/28109) BP Exploration(Alaska) 4 • r Post P&A Schematic TRE- FMC Vut3LHEAD- ENC 05-18A ACTUATOR= AXF1.SON KB.ELI/= 68' Proposed P&A __--- 8F.ELEV= ? r.r.r.r.r. KOP_ 4900' .:.-1.- .ti"::.::"."-::::: 73~ ►' 63' 4-1/2"X 3-1/2"XO.D=2.992" Max Angle- 57 @ 9030' ♦ :rti ti •r ,. r• r�: I:Yai,101M-, 9342' ♦ ! ['wain TVD= 8800'SS •.. .�'.??,El , ,: 2192• 3-1/ 2"AVATRSVSSSV.D=2-812" -444.4. ♦ �rti :: ►1 GAS LF?MANDRELSTop of Cement Job#2 TOC at /1 �.,;titir.rti r O.T1 M3 TVD DEV TYPE VLV LATCH PORT DATE Surface in()E1.IA and Tubing /* 4$''r%rti~" ' l' 1 13097 3096 1 TGPD DMY TG 0 04/07102 1;;4fti,1,4;14~" 14 • ►ii 2 5303 5290 17 TGR) DMY TG 0 04/07/02 r,r..r... _:,•:; 0 3 6656 6508 27 TGPD DMY TG 0 4.1/2"TBGPC,12.64,L-80, B3' '� -....- ► 0152 bpf,D=3.958' _ __ '4 7429 7196 27 TGFD DMY TG 0 04/07/02 6 7781 7513 25 TGR) DMY TG 0 10-3t4"CSG,45.5#,L-80,D=9.953' H 3517' :' 6 8074 7781 23 TCDD DMY TG 0 il i ;r��1+ CHEMICAL MANDRELS rl ]+ • ST MD TVD DEV TYPE VLV LATCH PORT DATE Top of Cement Job#1-Target u w I no�` 8457 8071 18 CA-KBUG LT BK-2 TOC in Tubing and IA-7,700' 1 Ilr eiR v 6411/1111%111 I 7,661'-9.82"x 7-518"Est TOG,63 wr- k�/ 85 -13 112"OTIS STRAIGHT SLOT LOC SEAL ASSY bbis Class G.40%Excess :_ N — i s—' ► `�,� 8541' —7-5/8"x 3-1/2"OTIS WD PERM www r; TKR(8850'ELM08/2880) - r �♦; 8545' H3-1/2"SEAL BORE EXT/M LLOUT EXT TOP OF 5-1/2"LM4R H 8593' v. �i1 iium 1,1� 8697' 2-718"t7FPSLv TOP OF 2-3/8"LNR 8743' TIC 01 PI r ii 1+1 O i 8816' i_3-112"OT15 XN NP,D=2.75' f 1 __ r 11 3-1/2"TBG-FC,9.3#,L-80, --I 8827 Mr 8827' -3-1/2'WIG,n=2.992' 0087 ttpf.D=2.992' 1 kA. HELNO TT NOT LOGGED- 1 . v 7-518"CSG,277#,L-80.D=6.875' 8871' {R1' ' I MILLOUT WN)OW(05-18A) 8888' PERFORATION SUMMARY RE=LOG:SWS MCNL ON 11/05/98 4 ' II' _ -+1.SD'VVFD 13C PATCH(06/21/09),D=125' ANGLE AT TOP PERF.38 9400 ! o"? 9388'$452' f�bte:Refer to Roduction DB for historical data !♦ •` -"�". P !1♦��- ww.42t' 1•44•••*"..,'- �� SfZE SFF t4Tfl AL Opn/Sgz DATE 4.4..11" a"-` 1-11/16' 6 9400-9414 0 04/16/02. 1!1♦1111 ' ++-N 9575' 2-3/8"PACK-OFF BUSHING.I)=1.0" !14141♦ �—�_ 1-11/16" 4 9423-9443 0 03/26/01 11/1///111/111/ ' .:' 1-11/16" 4 9465-9485 0 11/05/98 1!♦111111111♦11 � ► 1♦111111 =� 1-11/16" 4 9490-9510 0 11/05/98 111!!14 4.111 l411/♦1 �`rwi«��► .44144•• t1 1i1 111111111111111 --�-- 1441 4�414�411 �11t rill • 2-3/8"LNR.4.4#.1-80. 9593" ._...__. ., 1 5-1(2'LNR 175.1-80_0232.0232 bpf,D=4.892' H 9377 .0039 bpi,ID=1.995" TD 9595' DATF RFV 1W CONVENTS DATE REV BY COM '1TS PRUDti)F BAY UNIT P 11/89 ORIGINAL COM PLETICN4 :01/31/10 GIF/PJCiSE1Wl (01/13110) WELL. 05-18A 10/29198 SIDETRACKED PERN1TNo:'1981740 02/09102 R.W'TP COQ __.. AR No: 50.029.21960-01 06/27/09 JKD/TLH PATCH SET(06/21/09) SEC 32,T11 N,R15E,2188.96'FEL,2137.97 FM. 12/09/09 JIVF/SV SET Wf (12/08/09) 01/01/10 BSE/RPC PULED WRP(12/28/09) 8P Exploration(Alaska) 5 ki 4.0 • • Atr Well: 5- 18 5-18 Suspend Well Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Finn Oestgaard (907) 564-5026 History GPB Well 5-18 was initially drilled & completed in August 1989. The initial completion was in the 13P sands of Zone 1A. The well was side-tracked in 1998. In February 2010 an LDL confirmed a production casing leak @ 6150'. Well 5-18 has no future utility and has been fully approved by co-owners for permanent abandonment. Objective Place reservoir cement plug, lower lateral cement plug, lateral surface cement plug and cut off tubulars and wellhead at surface. The well will remain in suspended status until final removal of the casings and welding of marker plate 3' below original Tundra level. Procedural Steps SOP E.RSED07 Slickline & Fullbore 1. OA integrity test. 2. Pull WRP, confirm injectivity into tubing Eline 3. 5' Tubing punch @ 8520'-8525'. 4. Set plug with ball-drop seat @ 8680'. Fullbore 5. Place reservoir and lower cement plug — Liner cement, isolating ball, tubing and IA cement. Target TOC at 7700' in tubing and IA. Slickline 6. Drift and tag TOC with sample bailer 7. MIT-T to 2000 psi Eline 8. Perforate through 3-1/2" tubing, and 7-5/8" casing @ —1500' MD. 9. Set plug at 1550' aft Sc(,./ei "rts.•aoJ 'r fi"dvGil )41f rfe tntll 4i1 604 4-ell O too /1►CF/" 4Aco Orr( (Q lCf OF N fOo'/f° !% 5787"7 • S Fullbore 10. Pump Class G cement down tubing and up OA until neat cement returns at surface, then begin taking returns up IA until neat cement returns at surface. Shut in well. Special Projects 11. Cut off all casings and wellhead - 1' below pad level. Install marker cap on outermost casing string. Note: Final excavation, casing removal to 3' below tundra, and marker plate welding to occur at pad remediation. SUPRSEDED • SUP .RS �'�P 2 • 4110 • Pre Job Schematic TREES FMC WELLHEAD= FMC E ACTUATOR= A XELSON 05-1 8A SAFTY NOTES: ._.i KB.ELEV= 68' BF ELEV= ? I KOP 490 I 63 H4-1/7 X 3-1/7 X0.D=2.99211 = 0' 1)/L' h /7lax Angle= 57 02 9030' Datum MD= 934 Z Daturn TV D= 8800'SS (3 I 2192' H3-1AV A 1RSV SSSV.ID=2.817 1 4-1/7 TBIG-FC,12.S#,L-80. 63' r// GA S LIFT MANDRELS _01 52 bpf..D=3.958' ST MD TV D Da? TYPE VLV LATCH PORT DATE 1 3C@7 3096 1 TGPD OMY TG 0 04/07/02 2 5 303 5290 17 TGPD DM( TG 0 04/07/02 i3 6656 6508 27 TGPD Mk TG 0 I ID-34 C SG.4558,L-80,13=9.953' H 351T I— It 4 7 429 7196 27 5 7 781 751 3 25 TGPD DMY TG 0 04107,'02 TGPD CM' TG 0 6 8074 7781 M TGPD MAY TO 0 O-IEMCAL MANDRELS CW1 ST MD.Ti D DE/ TYPE VLV LATCH PORT DATE Minimum ID = 125" @ 9388' I 5457 807 1 18 C.A-KBLIG-LT BK-2 WFD ER PATCH I 8539' H3-F2'OTIS STRAIGHT SLOT LOC SEAL ASSY 1 II Cif 8541 7-5'8'X 3-1.'2"OTIS'ND PERM PK R I e8.50'a.M.0121891 85rn--13-1,7 SEAL BORE EXT/MLLOUT EXT 'TOP OF 5-1'7 LNR H 8593' I _ 00.....004. --I 8600' H3-1'2'WPR(2.78.(n)-SET 01 1 2110 1TOP OF 2-3,8'LNR H 8703' I L2 1 . - .8697' til, 8, DEP S L 1 0 0 I 8816' 43-1/7.'011S XN NP,D=2 7 5' 1 ' 1-1;2'TBG-PC.9.3#,L-80. —I 882T . i.. I 8827' —13-1"2"W03. ID=2:997 .0987 bpf, D=2.997 I —I a.mo TT NOT LOGGED I I 7-18"MG,29.78,L80.ID=6.875 H 8871 1.— I\ MLLO UT WINDOW(0 5-18A) 6888' PERFORATION SUMMARY rt I REF LOG:SWS MLON 11/05/98 9388-9452'H. 1.8 0'WFD 1 3aR.ER PAT]-1(06121,091.ID r-• 125 4A4 ANGLE AT TOP FERE 38 i§94(XY .0.• ••• 4Z+1St 'YAM•Note:Refer to Production DB for historic al perf data ••.•••0 0 tnsii, 4111111114114,444444w SIN EE SFF ILHVAL Op r.,'S= DATE k............ NI%p 9575' 2-18"FA 0<-OFF BUSHING,U=I.D' 1 1-11/1T 6 9400-941 4 0 041602 114..10 1-11/16' 4 942 3-9443 0 0126/01 WAPM A. 1 0**Oft ,of -.411P totto 1-11/16" 4 9465-948 5 0 11/05198 ,4•41.1. .0011 1-11116" 4 949 0-951 0 0 11/05/98 4.04111 .011411 44.11# 4...111 10%., 14•a 4141 0017 ss- forolv i 2-3/fr LW.4.4#,L 80 9593' 0039 13 pf,ID=1.995'5-1,:2"LNR 17#,L-80, 0232 bpf,D=4.892- H 9377- . TD 9595 I DA TE REV BY COMENTS GATE REV BY COMkENTS PRUDHOE BAY UNIT r 11/89 ORIGINAL COMPLETION 0 1;3 110 GJF:RIC SET WRP 1,01'131 0; WELL. 05-18A 1 0129/98 SIDETRAC KB) REIRIAT No:99 817 40 02/09102 RNfTP CORFECTIONS AR No: 50-029-21 960-01 06/27/09 JKEYTLH PATCH SET(06/21109) SEC 32.Ti 1N. RISE 2188.96'FEL,21 37 9 9'FNL 1 210909 JW/SV SET WRP(12/0 10 9) 01/01.1 0 BSERPC FULLED WRP(122109) BP Exploration(Alaska) 3 . • • Post P&A Schematic TREE= FMC W43.LHEAD= FMC 05-18A ACTUATOR= AXELSON KB.ELEV= ss' Proposed P&A BF ELEV= KOP 4900' 1 :s�rtirtr f. 63' 4-112'X 3-112"XO,D=2.992' 4 ::::::::I.V. ?tip 11 Max Angle- 57 CO 9030' �� .e. e.. r..-r 1 i Datum M)= 9342' rti?3 1 Datum N0= 8800"-SS 11 , r I- 2192' -1/2"AVATRSVSSSV,D=2812" 4 . }ti„} 1 ii �:, .ta. ! GAS LFT MANORS Topof Cement Job#2-TOC at 1+ ;r{fti::; %f I1' 4 = .4..r. 4,�T MD ND DEV TYPE VLV LATCH PORT DATE Surface in OA,IA and Tubing 14 ~ ���r rti"*'i 11; 1 3097 3096 1 TGR) DMY TG 0 04/071(2 14 :p....---ti r•ti.- 111 2 5303 5290 17 TGPO OMY TG 0 04/'07002 4 1r?'TRC,R 1?&# I•80 63' .4 ".-• hi 3 6656 6508 27 TGPD DMY TG 0 0152 t>p1 IG 3 998- Mill 4 7429 7196 27 TGPO DMY TG 0 04/0X02 • _ __ • 7781 7513 25 TGF) DMY TG 0 n 3-a"GSC,45 5#,L 80 ID 9 953' ;— 351 T v.- Ell=+.+��-- - �-N 6 8074 7781 23 11 D DMY TG 0 ----- -- !( O-I ACAL MANDRaS !1 ! ST MD TVD DEV TYPE VLV LATCH PORT DATE hl Top of Cement Job#1-Target 1 1��••>•�. .� •i..�.r I • 8457 8071 18 CJI-KBLIG-LT_ BK-2 TOC in Tubing and IA-7,700' �!' , 01111114 I 7,661' -9.92"x7-518"est TOC,63 y,!• �� bbls Class G,409:Excess V j alE_�` r 1. 8539' H3-1n"OTIS STRAIGHT SLOT LOC SEAL ASSY 1 •�_=aav— 1 L 4.y� Z::��• 8541' J 7-5/8"X 3-1/2"OT1S WD PERM �� ir'T. 0 ��. !( fKR(8850'Elk/108/28/89)Hi ,�-�- mem ! r 14 8545' H3-112"SEAL BORE DO7MIL LOUT EXT TOPOF 5-112'LNR -_ 8593' s 1 j' 4 8697' 2-7/8'DEP SLV iTOP OF 2-3/8'LNR 8703' i ma=y 4 4,14 ! 141 1! m� 1 � I 8$16 ' i_3-112'OTIS XN NP,D=2.75' IP 1'""' IFC Ia_' g: L. 8827' 6. r-� 882T H3-1/2'V4LEG.D-2.992' 008/bpf ID 2.992' ,m 8827' % 4 L__ — _ awe TT NOT LOGGED 4, MOM4 ! 410/ 7-5/8"CSG,29.7#,L-80,D=6.875' - 8871' El MILLOUT WIDOW(05-18A) 8888' I F137FORATIDN SUMMARY REF LOG:SWS Mat ON 11/05/98 ! ANGLE AT TOPPBZF_38 Q 9400liwng- 9388.-9452' --11.80'WFD 13CR 92 PATCH(06/21/09),D=1.25' PM:Refer to Froxwctx n DB for historicaldata , ':---tea• perf111•.-��._.� 011*7'-••m SEE SPF NTEtVAL Qpxl+Sgz DATE .00 01���`r.� 101111':. — 1-11/16" 6 9400-9414 0 04/16/02 0001101 ` 9575' �2 18"MACK OFF BUSHING,D=t.o" 111110 1-11/16" 4 9423'9443 0 03/26/01 10111114 1-11116" 4 9465-9485 0 11105/98 400400. 11111114 ...•� 1-11/16" 4 9490-9510 0 11/05/98 0041/04/4 43 �" ►!!1!1 4. •���__ 100!1 •�_!� 111111111111114 �rliY ZIA. 111111111111114 2-3/8"LNR.4.4#.1-80. 9593` _ — - 0039 bpf,ID=1 995' 5-1'2'LMR.174 L-80 0232 bpi,ID-4.892"7-1-1-937T TD 9595' DATF REV BY COMhFNTS DATF REV BY C:14.13JTS F1 IL*UEBAY UW 11189 ORIGINAL COMPLETION I,01/31/10 GJF/PJC SET WRP(01/13/10) WELL. 05-18A 10/29/98 SIDETRACI® PERIVET No:'1981740 02/09/02 RN/1P CORRECTIONS API No: 50-029-21960-01 06/27/09 .1OD+TLH PATCH SET(06/21/09) SEC 32,Ti 1 N,R15E,2188 96'FEL,2137 99'FTL 12/09109 JMF/SV SET WRP(12i08/09) 01/01/10 BSE/RPC PULLEDVOW(12/28/09) BP Exploration(Alaska) 4 • Loepp, Victoria T (DOA) From: Hibbert, Michael <Michael.Hibbert@BP.com> Sent: Tuesday, May 30, 2017 1:48 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU 05-18A(PTD 198-174, Sundry 317-182) Suspend Attachments: 5-18 P&A Sundry 5-30-17.doc Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Please see the attached sundry. I provided some additional detail around the cement volumes and pump schedules. Please let me know if there is any other specific information you would like included. Thanks, Michael Michael Hibbert BP Alaska—Intervention&Integrity Engineer G1i Email: Michael.HibbertPbp.com 903-5990 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, May 26, 2017 9:49 AM To: Hibbert, Michael Subject: PBU 05-18A(PTD 198-174, Sundry 317-182) Suspend Michael, Please include more detail in your procedural steps. I have included an example for your reference. You may mail the modified procedure to me. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeop aC�a laska.gov 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by: Beverly Mildred Daretha owell Date: [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ WELL LQG ~ S TRAIVSMfTTAL ~~~ PrtoAcTive D'~aynosric SeewcES, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 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 following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 J Leak Detection - WLD 14-Feb-10 05-18A 1 BL / EDE 2J Signed Print Name: F 4 ~~ ~~ ~ ~C `~ 3~ ~ 50-029-21960-01 _ _„ -, __ -- -- ~ ~~,~ Date : ~ as ,~ ~ ; PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL . °^' WEBSITE C `.Documenrs and SettutgslDiane Williazns~Desktop\T.ansmit_ BP.docx 10/16/09 Scwoberper NO. 5418 Alaska Data & Consulting Services F r j j V J Company: State of Alaska 2525 Gambell Street, Suite 400 f. r• L3.�i��v!1t1 )' �.,' �_. Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838 rt �: -n'. C3tC.d Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job X Log Description Date SL Color CD P1 -25 AP30 -00063 INJECTION PROFILE — j AhL, 10/0209 1 1 W -01A 82NJ -00026 MEMORY GLS 10/02109 1 1 12.06A AZCM -00043 LDL — 10/03/09 1 1 W -36 AViH -00028 PROD PROFILEW /GL 09/29/09 / 1 E -35A 82NJ -00027 MEM CEMENT BOND LOG 10/03/09 1 1 12 -34 AYS4 -00104 INJECTION PROFILE 10/11/09 1 1 Z -07A AYS4 -00101 PRODUCTION PROFILE 10/08/09 1 1 15 -18A B2WY -00015 MEM PROD PROFILE 07/01/09 1 1 05.18A B04C -00069 SCMT 07/30/09 1 1 U -05A 6148.00068 USIT — 08/17/09 1 1 P -07A AWJI-00051 MEM P PROFILE 10/09/09 1 1 09 -03 AZCM-00044 PRODUCTION LOG 10/10/09 1 1 1- 45/0 -26 B2NJ -00032 MEM LDL 10/10/09 1 1 S -134 AWLS -00039 USIT 09/28/09 1 1 V -105 83S0 -00026 (PROF 10/03/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Sude 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 G~.zaAcriv~ ~inc-vmsric ~~~vic~s, ~~_ ~ ~ ~~ ~' ~ ~ ~. ~. ~~ ~ T~: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing 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 following : BP E~loration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and .~ ~ ;~r~.~~~~ ..~ ~.?! : v za~ ProActive Diagnostic Services, (nc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907] 245,8952 ~~Uf ~(~ ~`ZS~ ~D ~- l'3~(- /`~l ~~ 1 1 j Coil 19,Jun-09 05-18A ~DE 50-029-21 2J Coil Flag 22,1un-09 E 03A 0 lJ ~"~~ ° + - ,~..__--/ Signed : ~,_;~' ~'~ Print Name: E~ 50-029-20181-01 Date : _ ff~ROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, AMCHORAGE, AK 99518 PHONE: (907~245-8951 FAx: (907~245-88952 E-RAAIL : } . : ; , : , . ~IVEBSITE : . ; ; , . ,~ C:~Da,~umen¢ and Settings\Owner~Desktop\Transmit_BP.docx 198-174-0 PRUDHOE BAY UNIT 05-18A 50- 029-21960-01 BP EXPLORATION Roll/41: Start: Stop Roll #2: Start Stop (ALASKA) INC MD 09595 TVD 09064 Completion Date: 11/15/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D D 8860 1 SCHLUM MCNL CH 1/6/99 1/15/99 D 9132 1 BH GR OH 3/23/99 3/26/99 D 9133 1 BH GR PB1 OH 3/24/99 3/30/99 L GR-MD FINAL 8875-9567 OH 3/23/99 3/26/99 L GR-MD FINAL 8888-9006 PB1 OH 3/24/99 3/30/99 L GR-TVD FINAL 8475-8974 OH 3/23/99 3/26/99 L GR-TVD FINAL 8485-8577 PB1 OH 3/24/99 3/30/99 L MCNL FINAL 8501-9527 CH 2 1/6/99 1/15/99 R SRVY LSTNG BHI 8800.-9595. OH 11/20/98 11/20/98 R SRVYLSTNG BI-II 8800.-9006. PB1 OH 11/20/98 11/20/98 Tuesday, January 09, 2001 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2782' FNL, 4146' FEL, Sec. 32, T11N, R15E, UM At top of productive interval 2151' FNL, 2285' FEL, Sec. 32, T11N, R15E, UM At effective depth At total depth 2138' FNL, 2189' FEL, Sec. 32, T11N, R15E, UM 5. Type of Well: Development Exploratow__ Stratigraphic__ Service__ (asp's 698212, 5948689) (asp's 700054, 5949370) (asp's 700149, 5949384) 6. Datum elevation (DF or KB feet) RKB 68 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 05-18A 9. Permit number / approval number 198-174 10. APl number 50-029-21960-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 81' Surface 3449' Production 8803' Liner 295' Liner 898' 9595 feet Plugs (measured) 9064 feet 9495 feet Junk (measured) 8987 feet Tagged PBTD @ 9495' MD on 3/26/2001. Size Cemented Measured Depth True Vertical Depth 20" 284 sx PF 81' 81' 10-3/4" lOOO Sx CS ~, 152 Sx CS ~, & 351 7' 3516' 350 sx Class G 7-5/8" 300 Sx C~ass G 8871' 8537' 5-1/2" 10o sx Class G, 117 Sx 8888' 8553' Thixotrophic, & 100 Sx Latex 2-3/8" 20 bbls 15.8 ppg I_ARC 9538' 9020' Perforation depth: Tubing (size, grade, and measured depth) =ackers & SSSV (type & measured depth) measured9423'-9443'; 9490'-9510'; 9465'-9485'. true vertical 8931' - 8947'; 8983' - 8998'; 8964' - 8979'. APR 06 zOOt 4-1/2", 12.6¢, L-80 PCT @ 63' MD; 3-1/2", 9.3#, L-80 PCT @ 8827' M~.) ~ ,~.. ~ - LINER TOP PACKER e 8667' MD; 7-5/8" X3-1/2" OTIS WD PERMANENT PACKER ~ 8~1' MD. 3-1/2" AVA TRSV SSSV ~ 2192' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see affached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 582 Representative Daily Avera.qe Production or Injection Data Gas-Mcr Water-Bbl 17723 97 1430 37631 560 Casing Pressure Tubing Pressure - 808 1135 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .__X 16. Status of well classification as: Oil __X Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~ Title: DS 5 Surveillance Engineer Brian Carlson Date April 4, 2001 Prepared by Paul Rauf 564-5-799 SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 · 05-18A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 2/01/2001' 3/15/2001' 3/26/2001' RIH & drifted to 8993' SLM (HAW). RIH & pulled 3-1/2" AVA TRSV Hold Open Sleeve. Tested TRSV - found TRSV to be working correctly. Pulled 3 1/2" Eclipse Packer @ 8667' MD. MIRU CTE. PT'd equip. RIH w/20' of 1-9/16" PJ Perforating Guns, 4 SPF, standard phasing, & random orientation. Tagged PBTD @ 9495'. Did tie-in. Perforated the following interval underbalanced: 9423'- 9443' MD (Zone lB) Reference Log: SWS MCNL 11/05/1998. POOH w/perforating guns. ASF. RD CTE. Placed well BOL. Obtained a representative well test. RECF!VED Page 1 · Ua/ZZ/ZOOl lO:g§ FAX 907 B§4 42§4 BP EXPLORATION bp March 21,2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 t~] 001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: RECEIVED HAR 2 J 2001 Ala~tm Oil & Gas Cons. Common Re: Prudhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as req~uired under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list 6f well work tentatively" scheduled for March 19 - 26, 2001' Well Work Planned 05-01C 05,18A ~ . 06-24A CTE PERFORATION CTE ADD PERFORATION CT ACID STIMULATION W/DIVERTER 12-15 13-27A SAG HYDRAULIC FRACTURE TREATMENT CT ADD PERFORATION W/WORK PLATFORM 16-23Ai NK-65i CHEMICAL CUT TUBING (PRE RIG ST) CTE ADD PERFORATION S-101 ADD PERFORATION S-103 IN~ PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at mufpc@bp.com. Sincerely, Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells U3/14/ZOO1 1~:41 FAA 907 564 42~4 BF EAFLURA'I'IDN ~uu~ bp March 14, 2001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Pmdhoe-EOA, Pt. Mac, & L/sbume Well Work BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 56 !-5111 This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for March 12 - 19, 2001: Well 03-27 03 -28 . :OSq,aA 12-15 13-27A 16-21 NK-65i S-101 S-103 Work Planned REPERFORATION / HYDRAULIC FRACTUR~ TREATMENT REPERFORATION CTE ADD PERFORATION SAG HYDRAULIC FRACTURE TREATMENT CT ADD PERFORATION W! WORK PLATFORM REPERFORATION CTE ADD PERFORATION ADD PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc ~bp.com. Sincerely, Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells Af¢ 1.5 State of Alaska AOGCC, Lori Taylor 3001 Porcupine St. Anchorage, AK 99501 Well Reference Data: Well No: 05-18A PB1 Field: County: State: Prudhoe Bay Unit North Slope Alaska Date: 03/24/99 API No: 500292196070 BHI Job#: 101735 Enclosed is the following data as listed below: Log T~ Bluelines Navigamma USMPR MDL/MNP DPR/MDL/MD~ Log Type Navigazmna USMPR ~DL/~N~ DPR/MDL/MD~ Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks : LIS VerificationReport & Listings : Depth Shift Monitor Plot : Upon Receipt, Please sign and fax to: Baker Hughes INTEQ Fax# ~~~t~.D 1 ~/' ~---~--~~~ Attn :' ~q~u~r¥ Sut~rland , / ~: "' ~'..~.~ $0 t999 Receivad :~r: !,) (-- Da~_~ka Oil & Gas Cans. Commission An~orage State of Alaska AOGCC, Lori Taylor 3001 Porcupine St. Anchorage, AK 99501 Well Reference Data: Well No: 05-18A Field: County: State: Prudhoe Bay Unit North Slope Alaska Date: 03/23/99 API No: 500292196001 BHI Job#: 101735 Enclosed is the following data as listed below: Log Type Bluelines Navigamma USMPR DPR/MDL/MDP TOTALS: Log Ty~e Navigamma USMPR DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks : LIS Verification Report & Listings : Depth Shift Monitor Plot : Upon Receipt, Please sign and fax to: Baker Hughes INTEQ ~-",'~ £ 6 !999 Date: Alaska Oil a Gas Cons. 1/6/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATI'N: Sherrie NO. 12207 Companl Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape OWDW-S~- /X/C. Trap Pm~SSU~ SURWY 9812~ 1 1 O~W-CENTER ~/ ~ T~P P~SS~ S~Y 981219 1 1 o~-~ ~y~ ~ ~P P~ss~ s~Y ~2~ 1 1 L2-08A P~ ~LRY LOG 981225 1 1 D.S. 5-31A (~) 98635 MCNL 981108 1 *REDO-TO CORRECT K.B. 71, D.F. 35 & G.L 70 -PLEASE CORRECT PRINTS SENT PREVIOUSLY. ~ ' ~ ~ D.S. 2-~3A ~a65~ ~c~ ~ ~~ ~02~ 1 1 1 D.S. 6-1~ 58S58 RST-SIGMA ~ ~~ ~81115 1 1 1 D.S. ~-30 · ~SS~7 MCNL "~ ~S~ ~sx~o~ 1 1 1 P.S. ~-~ ~002 MCm ~ ~%~ ~S~20~ 1 1 1 s]~/. 077 q ~. o'7~ DATE: 3~i,1 ] ~ i999 Alaska Oil & Gas O0~s. (;0mmi~si0rl Please sign and return one copy of this transmitlal to Sherrie at the above address or fax to (907) 562-652/I,R~you STATE OF ALASKA ALASr,,A OIL AND GAS CONSERVATION COMA :-.JSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I1. Status of well Classification of Service Well Oil [~] Gas E~ Suspended E] Abandoned E] Service 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 98-174 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-21960-01 4. Location of well at surface ...... ~,,L.~.. .......... 9. Unit or Lease Name 2496' FSL, 1133' FWL, SEC. 32, T11N, R15E, UM i -' ' i, '.i~.' '~ ~ ~ ~';~;t':'.~ ~ PRUDHOE BAY UNIT /,~_/ : ~ .......... ~ 10. Well Number At Top Producing Interval ; ]~ _~.~i~)~ 3140' FSL, 3090' FWL, SEC 32, T11N, R15E, UM ................ PRUDHOE BAY FIELD 5. Elevat~n in feet (indicate KB, DF, etc.) ~6. Lease Designation ~d Sed~ No. RKB ~ feet~ ADL 28326 PRUDHOE BAY OIL POOL 12. Date Spu~ 13. Date T.D. Reached 14. Date Co~., Susp. Or ~and. ~15. Water Depth, it o~shore 16. No. ol Completions I October 13, 1998 October 26, 1998 November 5, 1998~ N/A fe~ MSL 1 17. Total Depth (MD + ~D) 18. Plug Back Depth (MD + TVD) 19. Dimct~n~ Su~ey ~20. Depth where SSSV set 21. Thic~e~ of Pe~afmst 9595' MD/9064' TVD 9519' MD/9005'~D YES ~ No ~J 2192' MD. fe~MD 1900' (approx) 22. T~e Ele~ric or Other Lo~ Run CCUG~CNL, MWD/GR 23. CASING, LINER AND CEME~ING RECORD S~ING DEPTH MD CASING SIZE ~. PER ~. G~DE TOP BOSOM HOLE SIZE CEME~ING RECORD~ AMOU~ PULLED 20" 91.5~ H-40 Surfa~ 110' 30" 2~ Sx PF 10-3/4" 45.~ L-80 Surfa~ 3517' 13-1/2" 1000 Sx cs III, 152 Sx cs II & 350 Sx Class G 7-5/8" 29.7~ L-80 Surfa~ 8871' ~7/8" 3oo Sx Cla~ G 5-1/2' 17~ L-80 8953' 8888' 6-3/4" 100 Sx G, 117 Sx Th~otrophic, & 100 Sx Latex 2-3/8" 4.43~ L-80 8640' 9538' 2-3/4' 20 bbls 15.8 ppg ~RC 24. Perorations open to Pmdu~ion (MD + TVD of Top and BoUom and 25. TUBING RECORD inte~al, size and nu~er) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 63' 8541' 9490' - 9510' MD; 8983' - 8998' ~D; ~4 SPF 3-1/2" 882~ 8667' 9465' - 9485' MD; 8964' - 8979' ~D; ~4 SPF 26. ACID, F~CTURE, CEME~ SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOU~ & KIND OF MATERIAL USED 27. PRODUCTION TEST Date Fir~ Produ~ion Method of Operation (Flowing, gas I~, etc.) November 21, 1998 Flowing Date of Test Hours Test~ Production for OIL-BBL ~S-MCF WATER-BBL CHOKE SIZE ]~S-OIL ~TIO I 11/23/1998 3.00 Test Pedod > 1235 6241 0 ~ 5199 Row Tubing Casing Pre~ure Calculated OIL-BBL ~S-MCF WATER-BBL OIL G~VI~ - APl (co~) Pre~. 400 psi 24-Hour Rate > 28. CORE DATA Brief de~dption of litholo~, pomsi~, fractures, ~p~ent d~s ~d pr~n~ of oil, ~s or water. Submit ~re chips. * ~is 1~407 is submitt~ as dire 1 ed September 9, 1998 (Permit ~8-174) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME Sag River Top Shublik Top Top of Sadlerochit Zone 1B Base of Sadlerochit GEOLOGIC MARKER~ MEAS. DEPTH 8758' 8799' 8860' 9444' 9520' TRUE VERT. DEPTH 8428' 8460 8526' 8948' 9006' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravily. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of 05-18A CT Sidetrack Drilling Operations + Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed /~ ~ J~L~,._ ,_ TrUe AAI Coil Tubinq Drillin,q Supervisor Bruce E. Smith, P.E. ~ 'S~ Date INSTRUCTIONS Prepared by Paul Rauf 263-4990. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27; Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 05-18A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 10/13/1998: MIRU CTU. N/U BOP. 10/14/1998: Cont. RU. BOPE tested. 10/15/1998: RIH w/BHA & tagged hard cement @ 8868' MD. Milled to 8965'. POOH w/BHA. 10/16/1998: Performed inj test (press to 2000 psi & held for 15 min). RIH w/UR & tagged 8860'. Reamed to 8990'. 10/17/1998: Pumped Biozan sweep & POOH w/UR. RIH w/CT nozzle & tagged BTM @ 8987' MD. Loaded wellbore w/140° F 1% KCL Water. Pumped 6.9 bbls of 17.5 ppg Neat Class G Cement & PUH to 8300'. WOC. Contaminated Cement w/Biozan & cleaned out to 8855'. POOH w/nozzle. WOC. RIH & tagged TOC @ 8870'. Milled pilot hole to 8890'. 10/18/199~:[ POOH. RIH w/window milling BHA & time milled f/8887' to 8891'. 10/19/1998: '~ Drilled window to 8995' & POOH w/BHA. RIH & dressed window area. POOH w/BHA. RIH w/bi-centered BHA & displaced wellbore to FIo Pro. POOH due to MWD problems. 10/20/1998: RIH & drilled to 8917'. Performed LOT to EMW of 9.5 ppg. Drilled to 8930'. POOH. 10/21/1998: RIH & reamed f/8895' to 8926'. Drilled to 8978' & lost returns. POOH. RIH & spotted LCM pill. PUH to 5000' & squeezed pill w/max press of 1500 psi. Circulated BU f/5000'. POOH. Tested BOPE. 10/22/1998: RIH & drilled ahead to 9006'. Lost all returns. POOH. RIH to BTM & spotted LCM pill. Sqz'd to 1600 psi. Cleaned out to 9000'. Displaced well w/2% KCL Water. Pumped 4.3 bbls of 17 ppg Neat Class G Cement. Cleaned w/Biozan to 8900' MD. POOH & WOC. 10/23/1998: WOC. CTU maintenance. RIH & tag TOC @ 8908'. Drilled to 9020' & POOH. RIH & drilled to 9050' MD. Lost returns. 10/24/1998: Drilled to 9236' & POOH. RIH w/CT & pumped 60 bbl LCM pill. Pumped Magne Plus Plug. Sqz'd 10 bbls into FM. POOH w/CT. 10/25/1998: Lost all returns. Pumped FB 80 ppb LCM pill. RIH & drilled to 9282'. POOH. 10/26/1998: RIH & drilled to 9372'. POOH. RIH & drilled to TD @ 9595'. POOH w/BHA. 10/27/1998: RIH w/2-3/8" liner assembly. Liner stuck @ 9454'. Disconnected from liner & POOH. RIH w/ jars/accelerators & engaged fish @ 8491'. POOH w/fish. 10/28/1998: RIH & reamed tight spots to 9540' but unable to get any further. Pumped LSRV FIo Pro fl 9540' to 8950'. POOH. RIH w/liner assembly & landed it @ 9538'. Released from liner. Pumped 20 bbls of 15.8 ppg LARC to cement liner in place. TOL @ 8640' MD. 10/29/1998: Cleaned out liner w/Biozan & POOH. RDMOL. Sidetrack Summao/ Page I 05-18A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 11/05/1998: 11/18/1998: MIRU CTU. PT'd equip to 4000 psi. RIH w/CT pumping Crude & drifted liner to 9505' MD. POOH w/CT. RIH w/CCL/GR/CNL logging tools & killed well w/2% KCL Water. Tagged PBTD @ 9519' & displaced liner w/2% KCL Water. Logged f/9515' to 8500'. POOH w/ logging tools. RIH w/TCP guns & shot 40' of Initial Perforations located @: 9490' - 9510' MD (Zone lB) 9465' - 9485' MD (Zone lB) Used 1-11/16" carriers & shot all perfs @ 4 SPF, 0° phasing, balanced press, & random orientation. POOH w/guns. ASF. FP'd well & RDMOL. RIH & set 2-3/8" x 3-1/2" Liner Top Packer @ 8667' MD. Placed well on initial production & obtained a valid well test. Sidetrack Summary Page 2 At- CO Alaska, Inc. Sfructure · D.S. 5 Field · Prudhoe Boy Well' 5-18 Locafion : North Slope, Alaska East (feet) -> 1360 1400 1440 1480 1520 1560 1600 1640 1680 1720 1760 1800 1840 1880 1920 1960 2000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I t I I I I 8200- 8300- 8400- 8500 8600 O 8700 Q.1 8800 "'I 8900 I V 9ooo 9100 5-18bhs 5-18ohs Tie on - 15.09 Inc, 8800.00 Md, 8400.26 Tvd, 1557.2.3 Vs Kick off Point J 5--_..~~ ......../ Kick off Point Tie on - 8400.26 Tvd, 552.50 N, 14-66.17 E 5-18bhs I 5-18Al NOV 20 1998 5- 18ehs ] ~- 18A J ..... ,~nc~,ora,ge .......... ~ ....... 92OO 1400 1500 1600 1700 1800 lgO0 2000 2100 2200 2.300 2400 Verticol Section (feet) -> , '...' Az[,m. uth 75.69 with reference 0.00 N, 0.00 E from 5-18 L .......... Li , ,;: ' ,:,, Crec[ed by ptonner Data plotted: 1(3-Nov-§8 Plot Reference is 5-18A CT S~de[rQck. Coordinates <ire In feet reference 5-18. True VerUcol Depths ere reference MSL - rkb = 8R I't. ----- Beker Hughs. INTEQ --- 80O 76O 72O 680 640 Z 0 600 560 (1) 520 480 440 ARCO Alaska, Inc. D.S. 5 5-18 5-18 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes !NTEQ Your ref : 5-18A Our ref : sw/371 License : Date printed : lO-Nov-98 Date created : lO-Nov-98 Last revised : lO-Nov-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 696997.000,5951440.940,999.00000,N Slot location is n70 15 50.084,w148 23 50.512 Slot Grid coordinates are N 5948688.600, E 698211.900 Slot local coordinates are 2783.35 S 1142.50 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. D.S. 5,5-18 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 5-18A Last revised : lO-Nov-98 Measured [nclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 8800,00 15,09 68.36 8400.26 552.50N 1466.17E 0.62 1557.23 699663.02 5949279.26 8890.00 16,70 68.20 8486.82 561.63N 1489.06E 1.79 1581.67 699685.67 5949288.98 8919.00 23,80 69.60 8514.01 565.22N 1498.43E 24.54 1591.64 699694,94 5949292.81 8958.00 35,80 69.00 8547.79 572.08N 1516.52E 30.78 1610.86 699712.84 5949300.14 8997.00 50,70 69.00 8576.11 581.62N 1541.40E 38.21 1637.32 699T57.46 5949310.34 9030.00 57.30 74.00 8595.51 590.04N 1566.70E 23.45 1663.93 699762.54 5949319.41 9113,00 55.70 80.62 8641.35 605.27N 1634.15E 6.92 1733.05 699829.56 5949336.40 9154.00 52.50 85.42 8665.40 609.33N 1667.10E 12.28 1765.97 699862.38 5949341.32 9192.00 47.10 89.82 8689.93 610.58N 1696.07E 16.73 1794.35 699891.31 5949343.33 9227.00 45.40 74.90 8714.20 613.87N 1720.99E 31.13 1819.32 699916.14 5949347.27 9260.00 41.70 86.70 8738.15 617.57N 1743.34E 27.03 1841.89 699938.38 5949351.56 9293.00 43,00 87.12 8762.54 618.77N 1765.54E 4.03 1863.69 69996b.54 5949353.33 9337.00 38.90 87.02 8795.77 620.24N 1794.33E 9.32 1891.96 699989.28 5949355.56 9420.00 37.80 75.10 8860.95 628.15N 1845.01E 9.00 1943.02 700039.73 5949364.79 9484.00 40.90 75.70 8910.43 638.37N 1884.28E 4.88 1983.59 700078.72 5949376.03 9518.00 40.80 81.90 8936.16 642.69N 1906.07E 11.93 2005.77 700100.39 5949380.92 9559.00 39.00 90.80 8967.64 644.39N 1932.25E 14.59 2031,57 700126.52 5949383.31 9595.00 39.00 90.80 8995.62 644.08N 1954.91E 0.00 2053.44 700149.17 5949383.59 All data in feet un[ess otherwise stated. Calculation uses minimum curvature method. Coordinates from 5-18 and TVD from MSL - rkb = 68 ft. Bottom hole distance is 2058.27 on azimuth 71.76 degrees from wellhead. Vertical section is from wellhead on azimuth 75.69 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 5,5-18 Prudhoe Bay,North Stope, Alaska SURVEY LISTING Page 2 Your ref : 5-18A Last revised : lO-Nov-98 Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 5-18ehs ?00033.000,5949384.000,999.00 8970.00 647.53N 1838.78E 6-Aug-98 5-18bbs 700033.000,5949384.000,999.00 8870.00 647.53N 1838.78E 6-Aug-98 NOV 20 1998 Aia~k~ Oil & G~ C;on~, gommi~ion ~chorage ARCO Alaska, Inc. D.S. 5 5-18 5'18 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 5-18A ST1 Our ref : svy349 License : Date printed : lO-Nov-98 Date created : 22-0ct-98 Last revised : lO-Nov-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 696997.000,5951440.940,999.00000,N Slot location is n70 15 50.084,w148 23 50.512 Slot Grid coordinates are N 5948688.600, E 698211.900 Slot local coordinates are 2783.35 S 1142.50 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, [nc. D.S. 5,5-18 Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N 8800.00 15.09 68.36 8400.26 552.50N 8900.00 16.70 68.20 8496.43 562.64N 8922.00 21.80 93.10 8517.23 563.60N 8934.00 21.90 74.00 8528.38 564.09N 8961.00 19.10 55.60 8553.70 567.98N 8989.00 18.00 45.20 8580.25 573.62N 9006.00 18.00 45.20 8596.42 577.32N SURVEY LISTING Page 1 Your ref : 5-18A ST1 Last revised : lO-Nov-98 U L A R Dogleg Vert G R ! D C 0 0 R D S A T E S Deg/lOOft Sect Easting Northing 1466.17E 0.62 1557.23 699663.02 5949279.26 1491.61E 1.61 1584.39 699688.19 5949290.06 1498.64E 43.44 1591.44 699695.19 5949291.20 1503.02E 59.01 1595.81 699699.56 5949291.81 1511.52E 25.89 1605.00 699?0?.95 5949295.92 1518.37E 12.43 1613.03 699714.65 '5949301.73 1522.10E 0.00 1617.56 699718.28 5949305.53 All data in feet unless otherwise stated. Calculation uses minimum curvature method, Coordinates from 5-18 and TVD from MSL - rkb = 68 ft. Bottom hole distance is 1627.91 on azimuth 69.23 degrees from wellhead. Vertical section is from wellhead on azimuth 75.69 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes [NTEQ ARCO ALaska, Inc. D.S. 5,5-18 Prudhoe Bay,North SLope, ALaska SURVEY LISTING Page 2 Your ref : 5-18A ST1 Last revised : lO-Nov-98 Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 5-18ehs 700033.000,5949384.000,999.00 8970.00 647.53N 1838.78E 6-Aug-98 5-18bbs ?00033.000,5949384.000,999.00 8870.00 647.53N 1838.78E 6-Aug-98 TONY KNOWLE$, GOVEI~NOFt ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 9. 1998 Erin Oba Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Prudhoc Bav Unit 5-18A ARCO Alaska. Inc. Permit No: 98-174 Sur Loc: 2946'FSL. 1133'FWL. Sec. 32. T11N. R15E. UM Btmhole Loc. 2134'FNL, 2181'FEL, Sec. 32, T1 IN, RI5E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to rcdrill 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 arc made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximatcl.x.' 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 bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Johnston Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc~ Department of Fish & Game, Habitat Section w/o encl. Departmcnt of Environmental Conservation w/o cncl. STATE OF ALASKA l ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: AJter casing _ Change approved program _ Abandon _X Suspend _ Ope'alon Shutdown _ Repak we~l _ Plugging _X Time extension _ Pull tJbing __ Vanance _ Perforate_ Reeflte~ ~sp~ded wel _ 9fimulate _ Ohef _ Name of Operator. ARCO Alaska, Inc. Address: P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Dove~t~nent_X Exploratory _ S1ratagra~c _ Service_ Location of well at surface: 2946' FSL, 1133' FWL, Sec 32, T11N, R15E, UM At top of productive interval: 2225' NSL, 2613' FWL Sec 32, T11N, R15E, UM At effective depth: At total depth: 2178' FNL, 2554' FEL, Sec 32, T11N, R15E, UM 12. Present well condition summary - Total Depth: measured true vedical 9389 feet 9041 feet Effective Depth: measured 9325 feet true vertical 8978 feet Casing Length S~e Cemented Plugs (measured) Junk (measured) 6. Datum of elavation (DF or KB feet): 68' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number. 05-18 9. Permit number. 89-76 10. APl number. 50-029-21960 11. Field/Pool: Prudhoe Bay Oil Pool Bottom tagged @ 9325 feet' MD (7/30/98) Measured depth True vertical depth Conductor 80' 20" Sudace 3484' 10-3/4" Production 8838' 7-5/8" Uner 784' 5-1/2" Perforation Depth measured 9268' - 9295'. 284 Sx PF Cement lOO0 Sx CS Ill &350 Sx Class G & 152 SxCS II 300 Sx Class G 10o Sx Class G & 117 Sx Thixotropic & 100 Sx Latex Cmt true vertical 8923' - 8949'. Tubing (size. grade, and measured depth) 4-1/2". 12.~, L-80, PCT @ 6,3' MD: 3-1/2". 9.3. L-80, PCT @8827' MD. Packers and SSSV (type and measured depth) Otis WD Permanent Packer @ 8541' MD; 3-1t2" AVA TRSV SSSV @ 2192' MD. 110' 110' 3517' 3516' 8871' 8537' 9377' 9029' 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _X 14. Estimated date for commencing operation 15. Status of well classification as: Oil _X Gas _ [ Service October, 1998 16. If proposal was verbally approved Name of appmver Date approved 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Signed ~ Suspended _ Questions: Call Dan Kara at 263-4837. Erin Oba Engineering Supervisor Date FOR COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness .,Plug integrety ,,~ BOP test ~ Location clearance ~fO~/e~ Go~JMechanicalint~re~/test_ Subsequent form required 10. /"(07 David W. Johnston IAp~mved ¥ ord~,r of the Commissioner Form 10-403 Rev 06/15/88 Commissioner Prepared by Paul Rauf 263-4~90 Date SUBMIT IN TRIPUCATE STATE OF ALASKA ALA~,~A OIL AND GAS CONSERVATION COMr~SION PERMIT TO DRILL 20 AAC 25.005 11a. Type of Work Ddll -,, Reddll ~ lb. Type of Well Exploratory_ Stratigraphic Test_ Development Oil Re-Entry._ Deepen _ Service ~ Development Gas_ Single Zone ~ Multiple Zone _ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARC© Alaska, Inc. RKB 68' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 028326 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2946' FSL, 1133' FWL, Sec 32, T11N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2225' NSL, 2613' FWL, Sec 32, T11N, R15E, UM 5-18A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 2134' FNL, 2181' FEL, Sec 32, T11 N, R15E, UM November, 1998 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property i 15. Proposed depth (MD and TVD) property line I No Close Approach 9710' MD / 9188' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 8900' MD Maximum hole angle 60° Maximum surface 2500 psis] At total depth (TVD) 3400 psi~ @ 8800' 18. Casing program I Setting Depth Size Specification Top Bottom Quantity of cement Hole ! Casing Wei~]ht Grade I Couplin~l !Length MD TVD i MD TVD (include stage data) 2-3/4" 2-3/8" 4.6 L-80 FL4S 850' 8860' 8525' 9710' 9188' , 15 bbls , I I ! 19. To be completed for Redrill, Re-entry, and Deepen Operations. / ! Present well condition summary Total depth: measured 9389 feet Plugs(measured) Bottom tagged @ 9325' MD (7/30/98) true vertical 9041 feet Effective depth: measured 9325 feet Junk (measured) true vertical 8978 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 284 Sx PF Cmt 110' 110' Surface 3484' 10-3/4" 1000 Sx CS III & 350 SX 3517' 3516' Class G & 152 Sx CS II Production 8838' 7-5/8" 300 Sx Class G 8871' 8537' Liner 784' 5-1/2' 100 SxClass G & 117SXsx 9377'E( E~ VE¢029' Thixotropic & 100 Latex Cmt i~ I Perforation depth: measured 9268' - 9295' AUG 2 -G !998 true vertical 8923' - 8949' Naska 0il & Gas Cons. Commission 20. Attachments Filing fee ~ Property plat _ BOP Sketch ~ Diverter Sketch _ ArlCl'lora01~ng program ~ Drilling fluid program __ Time vs depth pict..,, Refraction analysis _ Seabed report_ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions: Call Dan Kara @ 263-4837. Signed '~¢'-.-/~ % · ~ Titlle Engineerin~ Supervisor Date ~;:~' .,. ~,.. t../ _ ~ ~,' Erin Oba Commission Use Only Prepared by Paul Rauf 263-4990 Permit~;~b~ I APInumber Approvaldate ~,... ~'.... ~ See cover letter for - ,~ ~ 50- O ~_._~;~' ,.-- ~__//~',~4:3 '"~ / other requirements Conditions of approval Samples required _Yes ,~"No Mud Icg required _ Yes ~o Hydrogen sulfide measures ,,~-'Yes _ No Directional survey required ~,Yes _ No Required working pressure for BOPE _ 2M; _ 3M; '~ 5M; _ 10M; _ 15M X 3500 psi for CTU Other: Original Signed By David W.Johnstonby order of ¢ ..., ~q.--, ~ Approved by Commissionerthe commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMfvn~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill_~ Reddll X lb. Type of Well Exploratory_ Stratigraphic Test_ Development Oil_~X Re-Entry ~-- Deepen _ Service _ Development Gas _ Single Zone__X Multiple Zone _ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 028326 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2946' FSL, 1133' FWL, Sec 32, T11N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2225' NSL, 2613' FWL, Sec 32, T11 N, R15E, UM 5-18A ~ #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 2134' FNL, 2181' FEL, Sec 32, T11 N, R15E, UM November, 1998 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 9710' MD / 9188' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 8900' MD Maximum hole angle 60° Maximum surface 2500 psig At total depth (TVD) 3400 psig @ 8800' 18. Casing program Setting Depth Size Specification Top Bottom i Quantity of cement Hole I Casing Weight Grade Coupling Length MD TVD I MD t TVD I (include stage data) 2-3/4" 2-3/8" 4.6 b-80 FL4S 850' 8860' 8525' 9710' I 9188'I 15bbls I I I ! I I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9389 feet Plugs(measured) Bottom tagged @ 9325' MD (7/30/98) true vertical 9041 feet Effective depth: measured 9325 feet Junk (measured) true vertical 8978 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 284 Sx PF Cmt 110' 110' Surface 3484' 10-3/4" 1000 Sx CS III & 350 SX 3517' 3516' Class G & 152 Sx CS II Production 8838' 7-5/8" 300 Sx Class G 8871'I CEIVE[) Liner 784' 5-1/2" 100 Sx Class G & 117 Sx 9377' Thixotropic & 100 Sx Latex Cmt Perforation depth: measured 9268' - 9295' A~J 0 2 6,!998 true vertical 8923' - 8949' A~ask~ 0il & Gas Cons. C0mt~issi0n Anchorage 20. Attachments Filing fee __x Property plat _ BOP Sketch ~ Diverter Sketch _ Ddlling program Ddlling fluid program Time vs depth plot_ Refraction analysis Seabed report_ 20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions: Call Dan Kara @ 263-4837. Signed '~-,/~ % · ~ Titlle Engineerin~l Supervisor Date Erin Oba Commission Use Only Prepared by Paul Rauf 263-4990 Perm --be2,~/-~ 50-~:~.~_ ~;~ - ..~--/' 'c/ ~' O '4:~/ ~' -"" ¢"' f~ other requirements Conditions of approval Samples required _Yes ~L,4No Mud Icg required_ Yes Hydrogen sulfide measures ',~.~Yes _ No Directional survey required ,~'¢es _ No Required working pressure for BOPE _ 2M; _ 3M; '~I~5M; _ 10M; _ 15M [ 3500 psi for CTU Other: Original Signed By Approved by David W. Johnston by order of Commissionerthe commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DS 5-18A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a twin replacement well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate and produce. Intended Procedure: · Cement squeeze and plugback the existing completion to - 8870' md. Mill window in 5-1/2" liner at --8900' md. Drill 10' of formation with 8.5 ppg Flopro fluid and perform Leak off test to 9.0 ppg. · Directionally drill 2.75" x -800' sidetrack to access Romeo reserves. · . Run and cement 2-3/8 ....liner to TD. · Perforate selected intervals. · Place well on production. August 24, 1998 DS 5-18A Proposed CT Conventional Sidetrack 3-1/2" Tubing Packer @ 8541' 3-1/2" AVA TRSV @ 2192' 5-1/2" Liner Top @ 8593' 3-1/2" XN Nipple @ 8816' Top of 2-3/8" Liner in TT Cement top ~8740' Window cut in 5-1/2" liner at ,.-8900' 2-3/8" Cemented liner Initial Perfs P&A existing interval 5-1/2" Liner Shoe @ 9377' :::::::::::::::::::::::::::::::::::::::::::::::::::::: 2-3/4" Open hole TD @ ~9710' DS 5-18A Potential Drilling Hazards POST ON RIG The last test for H2S production was 5 ppm in 1995. BHP: 3400 psi @ 8800' ss (7.4 ppg EMW), BHT 190 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/full column of gas: 2400 psi. · Gas saturated intervals are expected in build section. Shop Fuel Boilers Mu~ Water Tanks Pump Rool Fire Ext. 60/40 I TrplxJ Ext. ,~Pipe rac,~ Fire Ext. Dowell Drilling Equipment Trailer Preferred Major Equipment Layout for CT Drilling · , C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I '-- 7" Riser Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE J Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold Cutters or Combination CuttedBlinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus ARCO Alaska, Inc. D.S. 5 5-18 Prudhoe Bay North Slope, Alaska PROPOSAL L ] ST I NG by Baker Hughes !NTEQ Your ref : 5-18A CT Sidetrack Our ref : prop63 License : Date printed : 25-Aug-98 Date created : 6-Aug-98 Last revised : 20-Aug-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 696997.000,5951440.940,999.00000,N Slot location is n70 15 50.084,w148 23 50.512 Slot Grid coordinates are N 5948688.600, E 698211.900 Slot local coordinates are 2783.35 S 1142.50 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. D.S. 5,5-18 Prudhoe Bay,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D ! N A T E S PROPOSAL LIS?]NG Page 1 Your ref : 5-18A CT Sidetrack Last revised : 20-Aug~98 Dogleg Vert Deg/lOOft Sect 8800.00 15.09 68.36 8400.26 552.50 N 1466.17 E 0.00 1557.23 8900.00 14.84 68.22 8496.87 562,06 N 1490.16 E 0.25 1582.84 Kick off Point 9000.00 34.83 69.57 8587.16 576.93 N 1529.21E 20.00 1624.36 9082.59 51.35 69.94 8647.27 596.35 N 1581.98 E 20.00 1680.28 3 9100.00 54.83 70.00 8657.72 601.12 N 1595.05 E 20.00 1694.13 9100.84 55.00 70.00 8658.20 601.36 N 1595.70 E 20.00 1694.82 9133.54 60.00 75.00 8675.77 609.61 N 1621.99 E 20.00 1722.33 9176.95 56.62 76.35 8698.57 618.76 N 1657.77 E 8.21 1759.26 4 9200.00 54.84 77.10 8711.55 623.13 N 1676.31 E 8.21 1778.31 9300.00 47.15 80.84 8774.46 638.12 N 1752.47 E 8.21 1855.82 9400.00 39.62 85.63 8847.10 646.40 N 1820.57 E 8.21 1923.85 9429.28 37.46 87.32 8870.00 647.53 N 1838.78 E 8.21 1941.77 9443.52 36.32 87.38 8881.39 647.93 N 1847.32 E 8.00 1950.14 5 9500.00 31.81 87.66 8928.17 649.30 N 1878.92 E 8.00 1981.10 9600.00 23.81 88.38 9016.54 650.95 N 1925.50 E 8.00 2026.65 9700.00 15.83 89.77 9110.54 651.57 N 1959.38 E 8.00 2059.63 9710.37 15.00 90.00 9120.54 651.58 N 1962.13 E 8.00 2062.30 All data is in feet unless otherwise stated. Coordinates from 5-18 and TVl) from Mean Sea Level. Bottom hole distance is 2067.49 on azimuth 71.63 degrees from wellhead. Vertical section is from wellhead on azimuth 75.69 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes !NTEQ ARCO Alaska, Inc. D.S. 5,5-18 Prudhoe Bay,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 5-18A CT Sidetrack Last revised : 20-Aug-98 Comments in we[[path MD TVD Rectangular Coords. Comment 8900.00 8496.87 562.06 N 1490.16 E Kick off Point 9082.59 8647.27 596.35 N 1581.98 E 3 9176.95 8698.57 618.76 N 1657.~7 E 4 9443.52 8881.39 647.93 N 1847.32 E 5 Targets associated with this weltpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 5-18bbs 700033.000,5949384.000,999.00 8870.00 647.53N 1838.78E 6-Aug-98 5-18ehs 700033.000,5949384.000,999.00 8970.00 647.53N 1838.78E 6-Aug-98 8200 83O0 8400 8500 8600 87OO 8800 8900 I V 9ooo 9100 9200 9300 ARCO Alaska, Inc. / Structure : D.S. 5 Slot' 5-18/~ plotRef ...... i, 5-18ACTSidetrock. Coordin(3tee ore in feet reference 5-18. Field · Prudhoe Bay Location · North Slope, Alaska TrueV,~eo' O~.th --- Baker Hughe.~ INTirQ --- East (feet) -> 1440 1480 1520 1560 1600 1640 1680 1720 1760 1800 1840 1880 1920 1960 2000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I T.D. & End of Drop - 9120.54 Tvd, 651.58 N, 1962.13 E Tie on - 8400.26 Tvd, 552.50 N, 1466.17 E Tie on - 15.09 Inc, 8800.00 Md, 8400.26 Tvd, 1557.23 Vs 5-18bhs Kick off Point - 5-1Bahs T.D. &' End of Drop/Turn - 15.00 Inc, 9710,37 Md, 9120.54 Tvd, 2062.30 Vs I i I i I i I i i i i I i I i i I I i I I I 400 1500 1600 1700 1800 1900 2000 21 O0 2200 2300 2400 2500 Vertical Section (feet) -> Azimuth 75.69 wHh reference 0.00 N, 0.00 E from 5-18 5-18bhs 5-18ehs 720 680 640 600 560 52O 48O 440 400 g 0 WELL PROFILE DATA Point ..... MD Inc D;r TVD North East V. Sect Deg/1 O0 Tie on 8800.00 15.09 68.36 8400.26 552.50 1466.17 1557.25 0.00 End of Drop/Turn 8900.00 14.84 68.22 8496.87 562.06 1490.16 1582.84 0.25 End of Build/Turn End of Build/Turn End of Drop/Turn 9100.84 55.00 70.00 8658.20 601.56 1595.70 1694.82 20.00 9133.54 60.00 75.00 86~5.77 609.61 1621.99 1722.35 20.00 9429.28 37.46 87.32 8870.00 647,53 1838.78 1941.77 8.21 T.D. & End of Drop/Turn 9710.37 15.00 go.o0 9120.54 651.58 1962,1,3 2062.30 8.00 DS 5-18A CT Sidetrack and Completion Intended Procedure Ob. jective: Plugback existing wellbore. Directionally drill a twin replacement well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate and produce. Intended Procedure: · Cement squeeze and plugback the existing completion to - 8870' md. Mill window in 5-1/2" liner at -8900' md. Drill 10' of formation with 8.5 ppg Flopro fluid and perform Leak off test to 9.0 ppg. · Directionally drill 2.75" x -800' sidetrack to access Romeo reserves. · Run and cement 2-3/8'"' liner to TD. · Perforate selected intervals. · Place well on production. RECEIVED AUG 1998 Alaska O/J & Gas Cons. C0mmi~ion Anchor~e August 24, 1998 DS 5-18A Proposed CT Conventional Sidetrack 3-1/2" Tubing Packer @ 8541' 3-1/2" AVA TRSV @ 2192' 5-1/2" Liner Top @ 8593' 3-1/2" XN Nipple @ 8816' Top of 2-3/8" Liner in TT Cement top ~8740' Window cut in 5-1/2" liner at ~8900' 2-3/8"' Cemented liner Initial Perfs P&A existing interval 5-1/2" Liner Shoe @ 9377' TD @ ~9710' 2-3/4" Open hole DS 5-18A Potential Drilling Hazards POST ON RIG The last test for H2S production was 5 ppm in 1995. BLIP: 3400 psi @ 8800' ss (7.4 ppg EMW), BHT 190 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/full column of gas: 2400 psi. Gas saturated intervals are expected in build section. Shop Fuel Boilers Mu~ Water Tanks Pump Roo~ Fire Ext. 60/40 I TrplxI Ext. ,~Pipe rac,~ Fire Ext. Dowell Drilling Equipment Trailer Preferred Major Equipment Layout for CT Drilling .... C T Drilling Wellhead Detail ~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection Otis 7" WLA Quick Connect -- 7" Riser 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual Choke Manifold k I I Alignment Guide Flange I Man e HCR I .~ Annular BOP (Hydril),7-1/16" ID 5000 psi WP Cutters or Combination CuttedBlinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve O.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus ARCO Alaska, Inc. D.S. 5 5-18 Prudhoe Bay North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 5-18A CT Sidetrack Our ref : prop63 License : Date printed : 25-Aug-98 Date created : 6-Aug-98 Last revised : 20-Aug-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 696997.000,5951440.940,999.00000,N Slot location is n70 15 50.084,w148 23 50.512 Slot Grid coordinates are N 5948688.600, E 698211.900 Slot local coordinates are 2783.35 S 1142.50 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. D.S. 5,5-18 Prudhoe Bay,North Slope, Alaska Measured IncLin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 5-18A CT Sidetrack Last revised : 20-Aug-98 Dogleg Vert Deg/lOOft Sect 8800.00 15.09 68.36 8400.26 552.50 N 1466.17 E 0.00 1557.23 8900.00 14.84 68.22 8496.87 562.06 N 1490.16 E 0.25 1582.84 Kick off Point 9000.00 34.83 69.57 8587.16 576.93 N 1529.21E 20.00 1624.36 9082.59 51.35 69.94 8647.27 596.35 N 1581.98 E 20.00 1680.28 3 9100.00 54.83 70.00 8657.72 601.12 N 1595.05 E 20.00 1694.13 9100.84 55.00 70.00 8658.20 601.36 N 1595.70 E 20.00 1694.82 9133.54 60.00 75.00 8675.77 609.61 N 1621.99 E 20.00 1722.33 9176.95 56.62 76.35 8698.5? 618.76 N 1657.77 E 8.21 1759.26 4 9200.00 54.84 77.10 8711.55 623.13 N 1676.31 E 8.21 1778.31 9300.00 47.15 80.84 8774.46 638.12 N 1752.47 E 8.21 1855.82 9400.00 39.62 85.63 8847.10 646.40 N 1820.57 E 8.21 1923.85 9429.28 37.46 87.32 8870.00 647.53 N 1838.78 E 8.21 1941.77 9443.52 36.32 87.38 8881.39 647.93 N 1847.32 E 8.00 1950.14 5 9500.00 31.81 87.66 8928.17 649.30 N 1878.92 E 8.00 1981.10 9600.00 23.81 88.38 9016.54 650.95 N 1925.50 E 8.00 2026.65 9700.00 15.83 89.77 9110.54 651.57 N 1959.38 E 8.00 2059.63 9710.37 15.00 90.00 9120.54 651.58 N 1962.13 E 8.00 2062.30 All data is in feet unless otherwise stated. Coordinates from 5-18 and TVD from Mean Sea Level. Bottom hole distance is 2067.49 on azimuth 71.63 degrees from wellhead. Vertical section is from wellhead on azimuth 75.69 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, [nc. D.S. 5,5-18 Prudhoe Bay, North Stope, Alaska PROPOSAL LISTING Page 2 Your ref = 5-18A CT Sidetrack Last revised = 20-Aug-98 Coma~nts in wet[path ND TVD Rectangular Coords. Cor~nent 8900.00 8496.87 562.06 N 1490.16 E Kick off Point 9082.59 8647.27 596.35 N 1581.98 E 3 9176.95 8698.57 618.76 N 1657.77 E 4 9443.52 8881.39 647.93 N 1847.32 E 5 Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 5-18bhs 700033.000,5949384.000,999.00 8870.00 647.53N 1838.78E 6-Aug-98 5-18ehs 700033.000,5949384.000,999.00 8970.00 647.53N 1838.78E 6-Aug-98 82OO 8300 8400 85OO 8600 0 8700 .4-.- ~ 8800 >. "~ 8900 I v 9000 9100 92OO ARCO Alaska, I c. 1 ..... , Dote plotted : 20-Aug-98 [ Structure · D.S. 5 Slot' .5-18& PlotRef ...... isS-18ACTSidetrock. I Coordinotes ore in feet reference 5-18. Field · Prudhoe Bay Location · NoMh Slope, Alaska TrueVertlcol Depth ...... f ...... Mean Sea Level. Raker Huqhes NTEQ --- Eesf (feet) -> 1440 1480 1520 1560 1600 1640 1680 1720 1760 1800 1840 1880 1920 1960 2000 ~0 N, 14-66.17 E T.D. & End of Drop - 9120.54 Tvd, 651.58 N, 1962.13 E Tie on - 15.09 Inc, 8800.00 Md, 84-00.26 Tvd, 1557.23 Vs 5-18bhs 5-18ohs Kick off Point 5-18bhs 720 68O 64O 6OO 560 520 48O 440 400 - 5-18ehs %0. & End of Drop/Turn - 1.5.00 Inc, 9710.37 Md, 9120..5~. Tvd, 2062.30 Vs 9300 I I I I I I I I I I I I I I I I I I I I I I 1400 1500 1600 1700 1800 1900 2000 2100 2200 2500 2400 2500 Verficol Section (feet) -> Azimuth 75.69 with reference 0.00 N, 0.00 E from 5-18 WELL PROFILE DATA Point Tie on z End of Build/Turn 9100,84 55.00 70.00 8658.20 601.36 1595.70 1694.82 20.00 End of Build/Turn 9133.54- 60.00 75.00 8675.77 609.61 1621.99 1722.53 20.00 End of Drop/Turn 9429.28 37.46 87,32 8870,00 647,53 1838.78 1941.77 8.21 T.D. & End of Drop/Turn 9710.37 15.00 go.o0 9120.54 651.58 1962.13 2062.30 8,00 End of Drop/Turn 8900,00 14,84 68,22 8¢96.87 562.06 1490.16 1582.84- 0.25 8800.00 15.09 68.36 8400.26 552,50 1466.17 1557.23 0.00 MD Inc Dir TVD North East V. Sect Dog/lO0 WELL PERMIT CHECKLIST FIELD & POOL ~ ~.~__,~'~ ADMINISTRATION 2. 3. 4. 6. 7. 8. 9. 10. 11. ,~R DATE,' 12. ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. D&TE ,. GEOLOGY .~, DA'rE COMPANY ,,Z¢¢'¢"/_,,,-. WELL NAME ~',,~_--,/' ,5""-'"//~,,~----/ PROGRAM: exp [] dev/~redrll'~serv [] wellbore · · ~ · -- . _ ~. ~ , ,. , j INIT CLASS _/~ /--~:~ ~'j GEOL AREA ~'~ UNIT# //~b/__~ ON/OFF SHORE Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMl' vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMl will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... ANNULAR DISPOSAL 35. APPR DATE seg II ann. disposal para req II N DOPEs, do they meet regulation ................ (~ N DOPE press rating appropriate; test to ,5'"'O4~ (:~ _psig. g N Choke manifold complies w/APl RP-53 (May 84) ........ N Work will occur without operation shutdown ........... N Is presence of H2S gas probable ................. ~--e'~'i t--~b~- i s--~'~'e'-8'-'~~~ V N/ Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ..... ' ........ //Y N __~__~ ,__~'Z._~____-: ...................................................................................................................................................................................... Seabed condition survey (if off-shore) ............. // Y N Contact name/phon,e,for weekly progress reports ...... ./ Y N ...................................................................... [exploratory onlyj ./ .......... With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N Y N GEOLOGY: ENGINEEBING: UlC/Annular BEWj~!~tt_ ~/~--~' WM I~ ~,l,_ JDH / COMMISSION: DWi -~' RNG co -C~-~/~_ Comments/Instructions: M:cheklisi u~;v 05129198 rill('; \nlsolh( :\w )rdiml\di; nab'.l r (<1 :, 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. Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 99/ 3/23 BHI O1 LI~ Customer Format Tape **** TAPE HE~DER MWD 99/ 3/23 101735 01 1 3/4" NaviGamma, Gamma Ray Data LIS COMMENT RECORD(s): ~234567890~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ Remark File Version 1.000 Extract File: Header.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame #MNEM.UNIT Data Type Information #- STRT.F 8500.0000: Starting Depth STOP.F 9700.0000: Ending Depth STEP. F 0.5000: Level Spacing NULL. -999.2500: Absent Value C~P. COMPANY: ARCO Alaska, Inc. WELL. W~LL: 05-18A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 2946' FSL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1 3/4" NaviGamma REF . JOB REFERENCE: 101735 DATE. LOG DATE: 27 Oct 98 API. API NUMBER: 500292196001 ~Parameter Information Block #MNEM.UNIT Value Description FL 1133' FWL : Field Location SECT. 32 : Section TOWN.N tin : Township RANG. 15E : Range PDAT. M.S.L. : Permanent Datum LMF . KB : Log Measured From FAPD. FT 68 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .M 68' : Elevation Of Kelly Bushing EDF ,M N/A : Elevation Of Derrick Floor EGL .M N.A : Elevation Of Ground Level CASE.F 8888' : Casing Depth OS2 . DIRECTIONAL : Other Services Line 2 ~Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 05-18A is represented by runs 10, 11, 12, 13 and 14 which are all Directional with Gamma Ray. (5) The well was initially kicked off @ 8888' MD (8485' TVD), RECEIVED ' 2 6 1999 Oil & Gas Cons. Commission An omSe through a window cut in the casing of Well 05-18. (6)Run 1 through run 6 were milling runs, and no logging data was acquired in new hole. (7) Run 7, 8 and 9 were drilled in the wellbore of Well 05-18A PB1 which was later plugged with cement. (8)Well 05-18A was drilled to TD @ 9594' MD (8974' TVD) on Run 14. (9) The interval from 9574' MD (8964' TVD) to 9594' MD (8974' TVD) was not logged due to the sensor to bit offset. (10) The Gamma Ray log has been depth shifted to match the Schlumberger MCNL Gamma Ray logged on 05 November 1998. (11) A Magnetic Declination correction of 28.02 degrees has been applied to the Directional Surveys. ~Mnemonics ROPS -> Rate of Penetration (ft/hr) GRAX -> Genoa Ray MWD-API [M~] (MWD-API units) TVD -> True Vertical Depth, feet ~Sensor Offsets RUN GAMMA DIRECTIONAL 10 20.50 ft. 15.66 ft. 11 20.38 ft. 15.54 ft. 12 20.38 ft. 15.54 ft. 13 20.71 ft 15.87 ft 14 20.38 ft 15.54 ft Tape Subfi!e: 1 71 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. ~ 05-18A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by ARCO Alaska, Inc. 3. The PDC used is the Schlumberger's MCNL Gamma Ray data, dated November 5, 1998. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX 0.0 2 ROP ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( t) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode( 66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode( 68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode( 65) Frame spacing units: IF ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(t6) Size( 1) Repcode( 66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 t 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 API 4 2 ROP ~WD 68 t 4 DATA RECORD (TYPE# 0) Total Data Records: 18 1014 BYTES API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 Tape File Start Depth = 8875,000000 Tape File End Depth = 9590.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet ***~ FILE TRAILER LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 4297 datums Rep Code: 79 2 datums Tape Subfile: 2 25 records... Minimum record length: 42 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 05-18A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO ~EM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode{ 79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c [F ] t. OOOO0000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 1 1 1 i i Rep Code Count 68 2 Sum: 2 fndun a IF ] 7 8 9 10 11 12 13 14 15 16 0 1 1 0 1 0 1 0 0 1 Bytes 8 8 8 1.00000000 3 FRAME SPACE = 0.500 * F ONE DEPTH PER FR3~ME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAXMWD 68 1 4 2 ROPS MWD 68 1 4 * DATA RECORD (TYPE# O) Total Data Records: 18 1014 BYTES * Tape File Start Depth = 8879.000000 Tape File End Depth = 9596.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 4309 datums Rep Code: 79 2 datums Tape Subfile: 3 25 records,.. Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER MWD 99/ 3/23 101735 01 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 **** REEL TRAILER **** MWD 99/ 3/23 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 23 MAR 99 3:28p Elapsed execution time = 1.10 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS [] Tape Subfile 2 is type: LIS DEPTH GR ROP 8875,0000 -999.2500 -999.2500 8875.5000 -999.2500 -999.2500 8900.0000 30,8000 -999.2500 9000.0000 35.4200 90.0000 9100.0000 33.8800 133.3000 9200,0000 41.5800 124,1000 9300.0000 35.4200 72.0000 9400.0000 32.8080 63,3190 9500.0000 131.0400 59,0000 9590,0000 -999,2500 -999.2500 Tape File Start Depth = 8875.000000 Tape File End Depth = 9590.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 8879.0000 -999.2500 -999.2500 8879.5000 -999.2500 -999.2500 8900.0000 54.6700 -999,2500 9000.0000 34.9070 94.7000 9100,0000 33,8800 133.3000 9200.0000 36.9600 126.1850 9300.0000 75.4600 38.5470 9400.0000 42.0000 63.1910 9500.0000 120.9600 41.3000 9596.0000 -999.2500 -999.2500 Tape File Start Depth = 8879.000000 Tape File End Depth = 9596.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS RECEIVED Tape Subfile 1 is type: LIS ****MwDREEL HEADER **** C~ ~ 99/ 3/24 LIS Customer Format Tape ***~ TAPE HEADER MWD 99/ 3/24 101735 01 1 3/4" NaviGamma, Gamma Ray Data LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~234567890~234567890~23456789~~234567890 !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: Header.las ~Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame ~Well Information Block Data Type Information #MNEM. UNIT #- STRT.F 8800.0000: Starting Depth STOP.F 9000.0000: Ending Depth STEP.F 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ARCO Alaska, Inc. WELL. WELL: 05-18A PB1 FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 2946' FSL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1 3/4" NaviGamma REF . JOB REFERENCE: 101735 DATE. LOG DATE: 27 Oct 98 API . API NUMBER: 500292196070 ~Parameter Information Block #MNEM.UNIT Value Description FL 1133' F~rL : Field Location SECT. 32 : Section TOWN.N lin : Township RANG. 15E : Range PDAT. M.S.L. : Permanent Datum LMF . KB : Log Measured From FAPD. FT 68 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .M 68' : Elevation Of Kelly Bushing EDF .M N/A : Elevation Of Derrick Floor EGL .M N/A : Elevation Of Ground Level CASE.F 8888' : Casing Depth OS2 . DIRECTIONAL : Other Services Line 2 ~Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 05-18A PB1 is represented by runs 7, 8 and 9 which are all Directional with Gamma Ray. (5) The well was initially kicked off @ 8888' MD (8485' TVD) from RECEIVED the wellbore originally drilled for Well 05-18. The sidetrack 05-18A PB1 was later plugged back. (6) Run 1 through run 6 were milling runs, and no logging data was acquired in new hole. (7) The interval from 8958' MD (8550' TVD) to 8977' MD (8569' TVD) was not logged due to the sensor to bit offset. (8) The data from 8977' MD (8569' TVD) to 9006' MD (8577' TVD) was lost at the rigsite. (9) Well 05-18A PB1 was drilled to TD @ 9006' MD (8577' TVD) on Run 9. (10) A Magnetic Declination correction of 28.02 degrees has been applied to the Directional. Surveys. ~Mnemonics -> GRAX = Gamma Ray MWD-API [MWD] (MWD-API units) -> ROPS = Rate of Penetration (ft/hr) -> TVD = True Vertical Depth (feet) ~Sensor Offsets RUN GAMMA DIRECTIONAL 7 20.49 ft. 15.65 ft. 8 20.50 ft. 15.66 ft. 9 20.50 ft. 15.66 ft. Tape Subfile: 1 68 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 05-18A PB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here is the unedited field raw data. INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode( 79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c IF ] 1.00000000 , 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 t 1 .1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX MWD 68 1 4 2 ROPS MWD 68 1 4 DATA RECORD (TYPE# 0) 1014 BYTES Total Data Records: 4 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 Tape File Start Depth = 8833.000000 Tape File End Depth = 8980.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 889 datums Rep Code: 79 2 datums Tape Subfile: 2 Minimum record length: Maximum record length: 11 records... 54 bytes 1014 bytes Tape Subfile 3 is type: LIS **** TAPE TRAILER MWD 99/ 3/24 101735 01 **** REEL TRAILER **** MWD 99/ 3/24 BHI 01 Tape Subfile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 24 MAR 99 2:20p Elapsed execution time = 0.77 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS [] Tape Subfile 2 is type: LIS DEPTH GRAX 8833.0000 -999.2500 8833.5000 -999.2500 8900.0000 37.1250 8980.0000 -999.2500 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units ROPS -999.2500 -999.2500 12.1750 -999.2500 , 8833.000000 8980.000000 0.500000 = Feet Tape Subfile 3 is type: LIS RECEIVED A~a~a Oil & Gas Cons. Commi~ion Anyone * ALASKA COMPUTING CENTER * ....... SCHLUNfl~ERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : D. S . 11-30 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292248400 REFERENCE NO : 98657 RECEIVED JAN '151999 Alaska Oil & Gas Cons. Commission LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12 '.19 PAGE: * * * * REEL HEADER * * * * SERVICE NAME : EDIT DATE : 99/01/ 4 ORIGIN : FLIC REEL NAME : 98657 CONTINUATION # : PREVIOUS REEL : CO~IENT : ARCO ALASKA, PRUDHOE BAY, DS 11-30, API #50-029-22484-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/01/ 4 ORIGIN : FLIC TAPE NAME : 98657 CONTINUATION # : 1 PREVIOUS TAPE : CO~IENT : ARCO ALASKA, PRUDHOE BAY, DS 11-30, API #50-029-22484-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 11-30 API NUMBER: 500292248400 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 30 -DEC- 98 JOB NUMBER: 98657 LOGGING ENGINEER: R HERRMANN OPERATOR WITNESS: S RENNIER SURFACE LOCATION SECTION: 28 TOWNSHIP: 1 iN RANGE: 15E FNL: FSL: 1185 FEL: 383 FWL : ELEVATION (FT FROM MSL O) F~ELLY BUSHING: 62. O0 DERRICK FLOOR: 61. O0 GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 4. 500 11322.0 12.60 2ND STRING 7. 000 12825.0 26. O0 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWC CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SPERRY SUN BASELINE DEPTH 88888.0 12794.0 12779.5 12776.5 12766.5 12763.0 12730.0 12728.5 12724.5 12720.0 12715.5 12707.5 12690.5 12687.0 12656.5 12655 0 12648 0 12635 5 12616 5 12616 0 12607 0 12598 5 12588 0 12574 0 12564.0 12561.0 12558.5 12556.0 12546.5 12540.0 12536.5 12528.5 12509.0 12495.5 12494.0 12472.0 12469.5 12460.5 12456.5 12452.0 12442.5 12439.5 12404.0 12403.5 12396.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... G R CH CNT 88887.5 12793.5 12777.0 12767.0 12764.0 12729.5 12723.5 12689.0 12653.0 12632.5 12614.5 12605.5 12586.0 12571.0 12561.5 12555.0 12537.0 12524.0 12504.5 12488.5 12469.0 12458.5 12455.0 12405.5 12396.5 88887.0 12778.5 12730.0 12718.5 12714.5 12707.0 12686.0 12656.5 12648.0 12614.0 12597.5 12561.0 12555.0 12546.5 12537.0 12496.0 12469.0 12453.0 12442.5 12440.0 12402.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 12394.5 12376.5 12375 0 12361 5 12329 5 12324 5 12311 5 12309 5 12307 0 12300 0 12294 0 12293 0 12290.5 12288.5 12284.5 12278.5 12274.0 12273.0 12257.0 12251.0 12248.5 12225.5 12207.0 12206.0 12191.5 12191.0 12180.0 12173.5 12170.5 12164.0 12154.0 12153.5 12137.5 12128.5 12121.5 12116.5 12111.5 12108.5 12102.0 12095.0 12090.5 12070.5 12065.0 12061.5 12059.5 12058.5 12051.0 12039.0 12031.5 12030.0 12025.0 12024.5 12006.5 100.0 $ 12375.5 12329.0 12324.0 12309.5 12299.0 12292.5 12290.5 12287.0 12278.0 12273.5 12250.0 12223.0 12203.5 12189.0 12177.5 12169.0 12152.5 12135.5 12114.5 12107.0 12091.5 12088.0 12068.5 12056.0 12050.0 1203 O. 5 12024.0 12006.0 99.5 12394.0 12376.0 12361.5 12312.0 12308.0 12293.0 12285.0 12274.0 12256.0 12252.0 12208.0 12191.5 12172.5 12163.0 12153.0 12137.0 12128.5 12121.0 12112.5 12102.0 12066.0 12064.0 12060.0 12039.0 12031.0 12026.0 101.0 4-JAN-1999 12:19 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 REb~ARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE EDIT CONTAINING MEMORY CNL DATA ACQUIRED ON ARCO ALASKA ' S D.S. 11 - 30 WELL. THE DEPTH SHIFTS ABOVE REFLECT CORRELATIONS BETWEEN THE MWD GAi~4A RAY AND PASS #1 MCNL GA~A RAY, ALSO BETWEEN THE MWD GAbgdA RAY AND PASS #1 NEUTRON RATIO CARRYING ALL MCNL CURVES WITH THE RATIO SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12800.0 12000.0 CNT 12804.0 12009.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNT REMARKS: THIS FILE CONTAINS PASS #1 CASED HOLE MCNL DATA. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 5 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 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 1022542 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI 1022542 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1022542 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1022542 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 1022542 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNT V 1022542 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 1022542 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13671.000 GRCH. CNT -999.250 NCNT. CNT -999.250 FCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 GR.MWD 52.270 DEPT. 11266.500 GRCH. CNT -999.250 NCNT. CNT -999.250 FCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 GR.MWD 107.269 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUNk~h~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12800.0 12000.0 CNT 12804.0 12009.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 12795.5 12778.5 12763.5 12763.0 12758.0 12746.0 12740.0 12738.0 12735.0 12733.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT 88890.5 88883.5 12781.0 12767.0 12759.0 12742.0 12739.0 12738.0 12791.0 12759.0 12743.0 12730.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 12730.0 12727.0 12724.0 12704.5 12689.5 12680.5 12677.0 12675.5 12665.5 12663.5 12659.0 12650.0 12649.0 12643.0 12639.0 12621.5 12617.0 12612.0 12608.5 12607.0 12602.5 12598.5 12594.0 12590.0 12586.0 12585 5 12580 0 12571 0 12570 0 12561 5 12558 0 12554.5 12545.0 12539.5 12536.5 12532.5 12530.5 12524.0 12520.5 12515.0 12499.5 12494.5 12492.5 12485.0 12478.0 12472.0 12469.5 12467.5 12464.0 12461.0 12453.5 12444.0 12434.5 12430.5 12417.0 12730.0 12724.0 12704.5 12689.0 12674.5 12665.0 12658.5 12647.5 12636.0 12612.0 12602.0 12597.0 12589.0 12584.0 12577.5 12569.5 12555.0 12542.5 12515.5 12496.5 12489.0 12479.0 12475.5 12469.5 12463.0 12459.0 12724.5 12674.5 12673.0 12663.5 12645.0 12640.5 12620.0 12614.0 12605.5 12603.0 12592.5 12584.0 12572.5 12561. 0 12555.0 12544.5 12537.0 12533.5 12531.5 12524.5 12521.5 12496.5 12473.5 12472.0 12469.0 12463.0 12457.0 12444.5 12434.0 12427.5 12416.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 12411.0 12407.5 12396.0 12378.5 12366.0 12354.0 12349.0 12341.0 12330.0 12324.5 12320.5 12310. 5 12305.0 12299.0 12291.0 12286.0 12273.0 12265.5 12257.5 12251.0 12243.5 12236.0 12228.0 12223.5 12215.0 12208.5 12200.0 12199.5 12169.5 12156.0 12151.0 12150 0 12137 5 12134 5 12124 0 12117 0 12114 0 12111 5 12108.5 12090.0 12074.0 12069.5 12062.0 12060.5 12049.5 12046.5 12040.5 12033.5 12030.0 12027.5 12024.0 12022.0 12017.5 12006.0 100.0 12408.5 .12396.5 12378.0 12365.5 12353.5 12329.0 12324.0 12299.5 12291.0 12273.5 12250.5 12242.0 12198.5 12150.0 12136.0 12121.5 12114.5 12113.0 12107.5 12088.5 12069.0 12061.5 12050.5 12041.0 12030.5 12026.5 12024.5 12018.0 12006.0 100.0 12411.0 12348.0 12340.5 12321.0 12312.0 12305.0 12299.5 12285.5 12264.5 12255.5 12233.5 12225.5 12223.0 12214.0 12208.5 12200.5 12168.5 12155.5 12148.5 12135.0 12113.0 12074.5 12064.0 12048.5 12035.0 12024.5 102.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: REMARKS: THIS FILE CONTAINS PASS #2 MCNL DATA. THE SHIFTS ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1 AND ALSO BETWEEN NEUTRON RATIO PASS #1 AND NEUTRON RATION PASS #2 CARRYING ALL MCNL CURVES WITH THE RATIO SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CH_AN ** 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 1022542 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI 1022542 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 1022542 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 1022542 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 1022542 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNT V 1022542 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 10 DEPT. 12802. 000 GRCH. CNT 21. 201 NRAT. CNT -999. 250 CCL. CNT -999. 250 DEPT. 12000.500 GRCH. CNT 13.749 NRAT. CNT -999.250 CCL.CNT -999.250 NCNT. CNT NCNT. CNT -999.250 -999.250 FCNT. CNT FCNT. CNT -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUFkZ~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12800.0 12000.0 CNT 12804.0 12009.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNT LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 11 88888.0 12767 5 12764 5 12758 0 12740 0 12738 5 12726 5 12716 0 12705 0 12692 0 12672.0 12667.0 12649.5 12630.5 12613.0 12607.0 12582.0 12572.5 12557.0 12545.5 12526.5 12511.5 12481.5 12465.5 12462.5 12437.0 12416.5 12408.5 12401.0 12393.5 12384.0 12381.0 12380.0 12365.0 12360.0 12339.0 12330.0 12326.5 12326.0 12321.5 12315.0 12296.5 12293 0 12288 5 12284 0 12281 0 12252 0 12248 0 12241 0 12235 0 12229 0 12219.0 12213.5 12206.0 88887.5 12764.0 12758.5 12741.0 12739.0 12715.5 12671.5 12647.0 12605.5 12555.0 12508.5 12464.0 12408.5 12394.0 12380.5 12338.5 12326.0 12296.5 12292.5 12287.5 12250.5 12241.0 12217.0 12203.5 88887.0 12766.5 12724.5 12703.0 12690.0 12670.5 12663.5 12646.0 12629.0 12612.0 12580.5 12572.5 12547.0 12526.5 12481.0 12463.0 12436.0 12416.5 12401.5 12386.5 12382.5 12366.0 12360.0 12331.0 12327.5 12321.0 12316.0 12285.0 12283.0 12250.5 12243.0 12237.0 12227.5 12211.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 12 12204 5 12202 0 12196 5 12191 0 12169 5 12169 0 12156 5 12154 5 12138 0 12135 0 12118 0 12112 5 12110 0 12105 5 12104 5 12101.0 12095.5 12091.5 12085.0 12074.5 12065.0 12062.0 12059.0 12057.5 12052.5 12040.5 12038.5 12028.5 12026.5 12025.5 12015.0 100.0 $ 12189.0 12169.0 12153.0 12136.0 12107.5 12103.0 12088.5 12083.0 12056.5 12040.5 12026.5 12015.0 100.0 12205.0 12201.5 12195.5 12168.0 12155.5 12134.5 12118.5 12113.5 12105.5 12102.0 12095.0 12074.5 12066.0 12063.5 12060.0 12055.0 12039.0 12030.5 12027. 0 101.5 REMARKS: THIS FILE CONTAINS PASS #3 MCNL DATA. THE SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN PASS #1 GRCH AND PASS #3 GRCH ALSO BETWEEN PASS #1 NEUTRON RATIO AND PASS #3 NEUTRON RATIO CARRYING ALL MCNL CURVES WITH THE RATIO SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 13 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 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 1022542 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNT GAPI 1022542 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNT CPS 1022542 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNT CPS 1022542 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNT 1022542 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNT V 1022542 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12803.000 GRCH. CNT -999.250 NCNT. CNT 2952.470 FCNT. CNT 121.840 NRAT. CNT 26.078 CCL.CNT -999.250 DEPT. 12001.000 GRCH. CNT 17.498 NCNT. CNT -999.250 FCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE 14 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE · 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AFJMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, MCNL $ REMARKS THIS FILE CONTAINS THE ARITHIMETIC AVERAGE OF MCNL PASSES 1,2 AND 3. ALL PASSES WERE DEPTH MATCHED TO A SPERRY SUN MWD GAMMA RAY. ALL PASSES WERE CLIPPED OF INVALID DATA PRIOR TO AVERAGING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 15 TYPE REPR CODE VALUE 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 TY. PE CLASS MOD NUMB SAMP ELEM CODE (HE~) DEPT FT 1022542 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNT GAPI 1022542 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1022542 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1022542 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1022542 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12802.500 CRCH. CNT -999.250 NCNT. CNAV -999.250 FCNT. CNAV NRAT. CNAV -999. 250 DEPT. 12000.500 GRCH. CNT 18.909 NCNT. CNAV -999.250 FCNT. CNAV NRAT. CNAV -999. 250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 16 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: 0.1000 FILE S~Y VENDOR TOOL CODE START DEPTH MCNL 12804.0 $ 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 12000.0 03-NOV-98 RELO0350 12808.0 12808.0 12000.0 12804.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MCNL MEMORY CNL $ TOOL NUMBER MCNL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 12825.0 12825.0 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) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 17 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): 1100 NEAR COUNT RATE LOW SCALE (CPS): 2200 NEAR COUNT RATE HIGH SCALE (CPS): 14300 TOOL STANDOFF (IN): REMARKS: ALL PERFS OPEN FIELD PICK GOC 12140 FIRST TWO PASSES MADE WITH KCL WATER IN WELLBORE. THIRD PASS MADE WITH CRUDE IN WELLBORE. EACH PASS HAD A PUMP RATE OF 1 BPM. THIS FILE CONTAINS THE RAW DATA FOR MCNL PASS #1. ALL DATA IS SAMPLED AT 0.1'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 O. 1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE 18 ** 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 1022542 CVEL PS1 F/HR 1022542 GR PS1 GAPI 1022542 NCNT PS1 CPS 1022542 FCNT PS1 CPS 1022542 NRAT PS1 1022542 CCLD PSi V 1022542 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12813.543 CVEL.PSi -999.250 GR.PS1 -999.250 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 -999.250 DEPT. 11997.543 CVEL.PS1 -999.250 GR.PSl -999.250 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 85.000 NCNT. PS1 NCNT. PS1 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 19 DEPTH INCREMENT: O. 1000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MCNL 12804.0 $ LOG HEADER DATA STOP DEPTH 12000.0 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): 03 -NOV-98 RELO0350 12808.0 12808.0 12000.0 12804.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MCNL MEMORY CNL $ TOOL IVIIMBER MCNL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12825.0 12825.0 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) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 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): 1100 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 2O NEAR COUNT RATE LOW SCALE (CPS): 2200 N~ COUNT RATE HIGH SCALE (CPS): 14300 TOOL STANDOFF (IN): REMARKS: ALL PERFS OPEN FIELD PICK GOC 12140 FIRST TWO PASSES MADE WITH KCL WATER IN WELLBORE. THIRD PASS MADE WITH CRUDE IN WELLBORE. EACH PASS HAD A PUMP RATE OF 1 BPM. THIS FILE CONTAINS THE RAW DATA FOR MCNL PASS #2. ALL DATA IS SAMPLED AT 0.1'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 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 1022542 O0 000 O0 0 6 1 1 4 68 0000000000 CVEL PS2 F/HR 1022542 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1022542 O0 000 O0 0 6 1 1 4 68 0000000000 NCNT PS2 CPS 1022542 O0 000 O0 0 6 1 1 4 68 0000000000 FCNT PS2 CPS 1022542 O0 000 O0 0 6 1 1 4 68 0000000000 NRAT PS2 1022542 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE .. 21 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) CCLD PS2 V 1022542 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12813.742 CVEL.PS2 -999.250 GR.PS2 -999.250 NCNT. PS2 FCNT. PS2 -999.250 NRAT. PS2 -999.250 CCLD.PS2 -999.250 DEPT. 11997.342 CVEL.PS2 -999.250 GR.PS2 -999.250 NCNT. PS2 FCNT. PS2 -999.250 NEAT. PS2 -999.250 CCLD.PS2 85.000 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE ' 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE · 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.1000 FILE SU~94ARY VENDOR TOOL CODE START DEPTH STOP DEPTH MCNL 12804.0 12000.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 22 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): 03-NOV-98 RELO0350 12808.0 12808.0 12000.0 12804.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MCNL MEMORY CNL $ TOOL NUMBER MCNL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12825.0 12825.0 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) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 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): 1100 NEAR COUNT RATE LOW SCALE (CPS): 2200 NEAR COUNT RATE HIGH SCALE (CPS): 14300 TOOL STANDOFF (IN) '. REMARKS: ALL PERFS OPEN FIELD PICK GOC 12140 FIRST TWO PASSES~E WITH KCL WATER LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JA1V-1999 12:19 PAGE: 23 IN WELLBORE. THIRD PASS MADE WITH CRUDE IN WELLBORE. EACH PASS HAD A PUMP RATE OF 1 BPM. THIS FILE CONTAINS THE RAW DATA FOR MCNL PASS #3. ALL DATA IS SAMPLED AT 0.1'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 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 SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022542 O0 000 O0 0 7 1 1 4 68 0000000000 CVEL PS3 F/HR 1022542 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1022542 O0 000 O0 0 7 1 1 4 68 0000000000 NCNT PS3 CPS 1022542 O0 000 O0 0 7 1 1 4 68 0000000000 FCNT PS3 CPS 1022542 O0 000 O0 0 7 1 1 4 68 0000000000 NRAT PS3 1022542 O0 000 O0 0 7 1 1 4 68 0000000000 CCLD PS3 V 1022542 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1999 12:19 PAGE: 24 DEPT. 12813 . 941 CVEL. PS3 FCNT. PS3 -999. 250 NRAT. PS3 -999.250 GR.PS3 -999.250 CCLD.PS3 DEPT. 11997.742 CVEL.PS3 -999.250 GR.PS3 FCNT. PS3 -999.250 NRAT. PS3 -999.250 CCLD.PS3 -999.250 NCNT. PS3 -999.250 -999.250 NCNT. PS3 85.000 -999.250 -999.250 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/01/ 4 ORIGIN : FLIC TAPE NAME : 98657 CONTINUATION # : 1 PREVIOUS TAPE : CO~k4ENT : ARCO ALASKA, PRUDHOE BAY, DS 11-30, API #50-029-22484-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/01/ 4 ORIGIN : FLIC REEL NAME : 98657 CONTINUATION # : PREVIOUS REEL CO~4MENT : ARCO ALASKA, PRUDHOE BAY, DS 11-30, API #50-029-22484-00
