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Home My WebLink About199-0151a. Well Status:Oil Gas SPLUG Other Abandoned Suspended GINJ WINJ WAG WDSPL No. of Completions: 2. Operator Name: 3. Address: 4a. Location of Well (Governmental Section): 4b. Location of Well (State Based Plane Coordinates, NAD 27): 5. Directional or Inclination Survey: 6. Date Comp., Susp., or Aband.: 1b. Well Class: 7. Date Spudded: 14. Permit to Drill Number / Sundry: 15. API Number: 16. Well Name and Number: 17. Field / Pool(s): 18. Property Designation: 19. DNR Approval Number: 20. Thickness of Permafrost MD/TVD: 21. Redrill/Lateral Top Window MD/TVD: 8. Date TD Reached: 9. Ref Elevations: KB: 10. Plug Back Depth MD/TVD: 11. Total Depth MD/TVD: 12. SSSV Depth MD/TVD: 13. Water Depth, if Offshore: GL: BF: Development Service Exploratory Stratigraphic Test 20AAC 25.105 20AAC 25.110 Surface: Top of Productive Interval: Total Depth: Yes No(attached) Surface: TPI: Total Depth: x- x- x- y- y- y- Zone- Zone- Zone- Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion suspension, or abandonment; or within 90 days of acquisition of the log, 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 only if necessary. CASING WT. PER FT.GRADE TOP BOTTOM TOP BOTTOM HOLE SIZESETTING DEPTH TVDSETTING DEPTH MD CEMENTING RECORD AMOUNT PULLED CASING, LINER AND CEMENTING RECORD23. Yes No Yes No 24. Open to production or injection? If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd or liner run): 25. TUBING RECORD SIZE DEPTH SET (MD)PACKER SET (MD/TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED 27.PRODUCTION TEST Date of Test:Hours Tested: Flow TubingPress. Casing Press: Oil-Bbl: Oil-Bbl: Gas-MCF: Gas-MCF: Water-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: Oil Gravity - API (corr): Production for Calculated 24-Hour Rate Test Period Method of Operation (Flowing, gas lift, etc.): WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 4/5/1999 50-029-22227-01-00 PBU 02-31A 199-015 8830' / 8495' PRUDHOE OIL ADL 028308 74-01711220' / 8947' 8830' / 8427' ~1900' 9074 / 8708 0 12/26/2024 N/A 4/16/1999 ASP4 ASP4 ASP4 5950629 5951045 5951859 688426 689759 688458 4642' FNL, 3532' FEL, SEC 25, T11 N, R14E, UM 210' FNL, 2252' FEL, SEC 36, T11 N, R14E, UM 593' FNL, 3593' F/EL, Sec. 36, T11N, R14E, UM 20"94#H-40 Surface 118'Surface 118'30"280 Sx Class G 9-5/8"36#J-55 Surface 3499'Surface 3495' 12-1/4" 1920 cubic ft CS lit & 348 cubic f 7"26#L-80 Surface 8735'Surface 8415'8-1/2"983 cubic ft Class G 2-7/8"6.16#L-80 8322 11151'8060'8944'3-5/8" 27 bbls 15.8 ppg LARC 5"15#L-80 8454 9074'8175'8708'6"189 cubic ft Class G 4-1/2" 12.6# 13Cr80 x L-8 8303 - 8830 8199 / 8204 , 8311 / Tbg x IA x OA, Surface -3403 115 bbls 15.2 ppg Type 1-2cmt OA top job, Surface - 44 60 gal Arctic Set 1 cmt Not on production 68 324-222 PRUDHOE BAY Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Date First Production: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov By James Brooks at 8:39 am, Jan 27, 2025 Abandoned 12/26/2024 JSB RBDMS JSB 013025 xGJJL 5/8/25 DSR-4/7/25A.Dewhurst 02APR25 28. CORE DATA Conventional Cores(s): Yes No Sidewall Cores(s): Yes No If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and persence of oil, gas or water (submit separate pages with this form if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)30. FORMATION TESTS Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this for, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. MD TVDNAME Permafrost - Top Permafrost - Base Top of Productive Interval Formation Name at TD: 31. List 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. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071 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. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TPI (Top of Producing Interval). The Kelly Bushing, Ground Level, and Base Flange 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. 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. 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. General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 84578785 Daily Operations Summary, Wellbore Schematic, Well Photos Top of Sag River Sand Top of Shublik Top of Sadlerochit Top of Zone 1 B 8668' 8718' 8785' 9390' 8358' 8400' 8457' 8898' Zone 1 Ivishak 11220' 8947' Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Date: 2025.01.24 16:16:12 - 09'00' David Bjork (3888) ACTIVITYDATE SUMMARY 5/10/2024 T/I/O=0/75/50 Temp=S/I (Perform MIT-OA/LLR) Pumped down the OA for 3 minutes at 1 BPM OA stayed around 160-170 psi. Increased Rate to 2 BPM for 2 minutes OA stayed around 160-185 psi. Increased Rate to 3 BPM for 5 minutes OA Stayed around 170-190 psi. Pumped a total of 23 BBLS 60/40 to Test the LLR of the OA. FWHP= 0/50/75 6/10/2024 ***WELL S/I UPON ARRIVAL*** MIRU HES PT PCE 300PSI LOW, 3000PSI HIGH, FUNCTION TEST WLVS RIH WITH 10' 3.125" OD MAXFIRE 6SPF; STACK OUT AT 387' CCL DEPTH RUN 3.5" SL CENTRALIZER DRIFT TO 3450'; RUN 10' X 2.785" DMY GUN (3.16RINGS)/3.50" SL CENTRALIZER, SET DOWN AT 390' RUN 6' X 3.375" DMY GUN (3.66RINGS), SET DOWN AT 390' RDMO HES ***WELL S/I UPON DEPARTURE*** 6/25/2024 T/I/O=25/0/0. Pre P&A. Removed 4" CIW upper tree and installed 4" P&A valve #35 as dryhole tree. Torqued flanges to API spec. PT dryhole against MV to 300/5000 psi. Pass, Cycled MV. ***Job Complete*** Final WHP's 25/0/0. 7/21/2024 ***WELL S/I ON ARRIVAL*** BRUSHED RESTRICTION w/4-1/2'' BLB 3.80'' G-RING DRIFT FREELY TO 3500'SLM w/6.5' x 3.16'' DMY GUN RAN 10' x 3.16'' DMY GUN, UNABLE TO PASS 379'SLM DRIFT FREELY TO 3500'SLM w/10' x 2.29'' DMY GUN ***WELL LEFT S/I ON DEPARTURE*** 10/18/2024 *** WELL S/I UPON ARRIVAL *** (TUBING PUNCH) MIRU HES, WAIT ON WEATHER PT PCE 300PSI LOW, 1500PSI HIGH, FUNCTION TEST WLVS PUNCH TUBING AND CASING FROM 3403' TO 3412' 2.75" BH RDX CHARGES. - 3 GUN RUNS PRE SHOT 500/0/0, POST SHOT 300/300/0 PERFORM MAN DOWN DRILL WITH WSL ***JOB COMPLETE, WELL S/I ON DEPARTURE*** 11/1/2024 T/I/O = 60/0/30 Confirm circulation through perf tunnels TxIAxOA (P&A) Spear in with 1 bbl of 60/40 down the tubing up the IA and pressure to ~300 psi to a closed choke. OA remained at 30 psi. Open choke and take returns to OTT. Established a rate of 5 bpm @ ~200 psi. At 120 bbls see 9.8 ppg Nacl on return MM. SD pump and line up to pump down the tubing taking returns from the OA. Pump 40 bbls 9.8 ppg NaCl at 4 bpm but unable to establish returns from the OA. Contact OE and decide to bullhead down the OA. Bullhead 110 bbls of 9.8 NaCL down OA at 5 bpm @ ~150 psi. Monitor WHPS for 30 mins. Freeze protect TxIA xOA to ~65¿ with 60/40. RDMO. Final WHPs Vac/Vac/66 upon departure. Daily Report of Well Operations PBU 02-31A Daily Report of Well Operations PBU 02-31A 11/26/2024 T/I/O = Vac/230/0. Temp = SI. Bleed T & IA to 30 psi (eval P&A). No WH or flowline. Dryhole tree. Drilling scaffold around well. P&A hardline RU. Bled IAP through hardline to OT tank to 30 psi in <1 min (fluid). No monitor. Final WHPs = Vac/30/0. SV = C. MV = O. IA, OA = OTG. 16:30 12/5/2024 ***Job Postponed for Snow Removal*** Prove Injection ( Pre Cement ) 12/6/2024 Halliburton cementers w/ LRS Assist (P&A) Bullhead OA cement. Circulated 150 bbls of warm fresh water down the tbg taking returns from IA. Line up and bullhead 30 bbls of surfactant followed by 10 bbls freshwater spacer and 115 bbls 15.3 ppg Type1-2 cement with the first 10 bbls mixed with Bridgemaker II at 4 bpm slowing rate down to 2 bpm last 10 bbls. Close OA valve and flush surface lines. Line up and pump 30 bbls of surfactant followed by 10 bbs freshwater spacer and 145 bbls of 15.3 ppg Type 1-2 cement down the tbg taking returns from the IA but did not get cement to surface due to losses. Reverse circulate140 bbls of 60/40 and see cement at 95 bbls at return MM. Recover ~22 bbls of cement in OTT. Leave well shut in and wait for wait for fluids to circulate the well with warm water until compressive strength on the cement reached 1000 psi in the OA. FWHPs=510/513/11 WIl returrn at later date to complete TxIA cement to surface 12/6/2024 T/I/O=15/408/0 Circulate warm fluids for cement job. Pumped 1 bbls 60/40 to verify flowpath to open top. Pumped 3 bbls 60/40 and 29 bbls 160* Fresh water down IA taking returns up tbg to open top. ***job continued to 12-07-24*** 12/7/2024 ***job continued from 12-06-24***Pumped 198 bbls 160* Fresh Water down IA up tbg. Pumped 180 bbls 160* DSL down tbg up IA to open top tanks. Pumped 20 bbls down IA taking returns up the TBG into an OTT. Freeze protected surface lines with 3 bbls of 60/40. DSO notified upon departure. FWHP = 5/16/0 12/10/2024 Halliburton Cementing with LRS assist Job Scope: P&A TxIA from 3412' to surface Pressure test surface lines to 4000 psi. Pump 295 bbls of fresh water, 30 bbls of surfactant, 10 bbl FW spacer, and 120 bbls of 15.3 ppg Type 1-2 cement 1:1 returns for 76 bbls of cement then 20% losses but regained 1:1 returns at 88 bbls on RMM. At 102 bbls see cement at surface. At 115 bbls see good 15.2 ppg cement. Shut in choke and pressure up to 1200 psi held solid, Bleed off to 0 psi. Wash-up surface lines. RD and release rig-up. Grease crew service tree valves. Job Complete Note: OA bullhead cement completed on 12/06/24 12/20/2024 ***P&A in Progress*** Pad Eleveation = 31.7'. Tundra Elevation = 25'. Excavate with bucket to a depth of 10' below pad elevation. Tundra elevation clearly visible 7' below pad elevation. No water inflow. Cover excavation with rig mats LDFN. 12/21/2024 ***P&A in Progress*** Pad Elevation = 31.7'. Tundra Elevation = 25'. Remove rig mats and continue excavation. Excavate to 15' below pad elevation. Set shoring box. LDFN 12/22/2024 *** P&A in Progress*** Pad Elevation 31'.7". Tundra Elevation = 25'. Conduct CSE PJMS with DS lead and HSE Rep. Set Wachs Goliath guilotine saw 4' below tundra elevation. Cut well head. Cement at surface in tubing, IA, and surface casing. 44' void in OA. Notify AOGCC for witness. LDFN 12/23/2024 *** P&A in Progress*** Conduct CSE PJSM with DS lead and HSE Rep. AOGCC Inspector Brian Bixby verified cut casing strings, void in OA, cement and marker plate. LDFN Daily Report of Well Operations PBU 02-31A 12/24/2024 *** P&A in Progress*** Conduct CSE PJMS with DS lead and HSE Rep. Perform top job on OA void using 60 gallons of Arctic Set 1 cement. Apply heat to cut off well. Notify State for reinspection. LDFN 12/26/2024 ***P&A Complete*** Conduct CSE & Hot Work PJSM with DS Lead, HSE Rep & Worley welding. AOGCC Inspector Kan Stjohn verified cut casing strings, cement and marker plate. Remove rig mats, pull shoring box and backfill excavation. Photo documentation of P&A stored in the U:drive. ***P&A Complete*** FULL ABANDONMENT - ALL CSG STRINGS CEMENTED TO SURFACE & CUT 4' BELOW TUNDRA MARKER PLATE WELDED (12/26/24) 2024-1225_Surface_Abandon_PBU_02-31A_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:12/26/2024 P. I. Supervisor FROM: Kam StJohn SUBJECT:Surface Abandonment - Final Petroleum Inspector PBU 02-31A Hilcorp North Slope LLC PTD 1990150; Sundry 324-222 12/25/2024:I traveled to PBU 02-31A for the surface abandonment inspection after the surface cement job was complete. Refer to 12/2302024 report documenting the post- cutoff inspection showing the tubing-casing annulus void requiring the remedial cementing. Steven Dubose was the Hilcorp representative. I verified the Well Name, PTD, API #, and Operator were correct on the ¼-inch thick steel marker plate. The cut tubing and casing strings were clean and flush, and the cement was hard in all sections of the tubing and casing – verified by hitting with a hammer. The cutoff depth below tundra was at 4 feet. Welding went well and marker plate was fit as per regulations. No follow up needed. Attachments: Photos (2) 2024-1225_Surface_Abandon_PBU_02-31A_ksj Page 2 of 2 Surface Abandonment – PBU 02-31A (PTD 1990150) Photos by AOGCC Inspector K. StJohn 12/25/2024 2024-1223_Surface_Abandon_PBU_02-31A_bb Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:December 23, 2024 P. I. Supervisor FROM: Brian Bixby SUBJECT:Surface Abandonment Petroleum Inspector PBU 02-31A Hilcorp North Slope LLC PTD 1990150; Sundry 324-222 12/23/2024:I arrived location and got up with Steven DuBose (Hilcorp) to look at the wellbore after cutoff. There is a 44-foot void in annulus. I gave him approval to proceed with fill it to surface. Follow-up inspection recommended after they complete top job to confirm cement integrity and mark plate information/installation. Attachments:Photo 2024-1223_Surface_Abandon_PBU_02-31A_bb Page 2 of 2 Surface Abandonment – PBU 02-31A (PTD 1990150) Photo by AOGCC Inspector B. Bixby 12/23/2024 From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Cc:Lau, Jack J (OGC) Subject:20241107 1113 02-31 APROVAL P/A sundry# 324-222 PTD 199-015 Date:Friday, November 8, 2024 9:12:49 AM APPROVAL FOR OA CEMENT DOWN SQUEEZE Hi Dave – Is there any sign of communication from the IA into the OA post-perfs? I realize there weren’t returns up the OA and there was not a pressure response on the IA while pumping on the OA. If there is potential communication then both the OA down squeeze and TxIA cement plug should be pumped in concurrence to avoid any issues. You have approval to modify the procedure to abandon the OA by down squeezing ~100 bbls of cement. If there is potential IAxOA communication perform both the OA down squeeze and the TxIA plug on the same rig up. Jack From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, November 7, 2024 11:17 AM To: David Bjork <David.Bjork@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: 20241107 1113 02-31 P/A sundry# 324-222 PTD 199-015 David, Thanks for this information. Jack Lau is now working PBU. He and I have discussed this. He will be the approver for the rest of this sundry work. He will get back to you with conditions later today. For Jack’s benefit, this can all be done via email. Please copy me on the remaining correspondence for the P&A work. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Jack and Bryan From: David Bjork <David.Bjork@hilcorp.com> Sent: Thursday, November 7, 2024 10:59 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: 02-31 P/A sundry# 324-222 PTD 199-015 Morning Mel, We made 3 gun runs with 2-3/4” (4ft) BH RDX charges and perforated 3,403ft- 3,412ft. I was unable to get larger guns in the hole due to tubing buckling. I could not get to target depth with; 10ft 3.125”, 10ft 2-7/8”, 6ft 3-3/8”. We could move up and perforate again, I would not expect the results to change. Modeling indicted we should have a 0.294” holes in the 7”. We can get deeper penetrating charges but they all risk damaging the 9- 5/8” casing. Historically the OA has exhibited and behaviors consistent with an open shoe. We were able to put away a casing volume of brine with no response in the IA ,conductor and neighboring wells. 3/16/99 13.8gpm @ 140 psi 9/12/07 2bpm @ 40-psi 12/31/09 2bpm @ 200-psi 2/18/11 4bpm @ 200-psi 5/10/24 3bpm @ 170-psi Best Regards, Dave From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, November 6, 2024 4:52 PM To: David Bjork <David.Bjork@hilcorp.com> Subject: [EXTERNAL] RE: 02-31 P/A sundry# 324-222 PTD 199-015 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. David, Did you perforate at 3400’ MD? How about moving up 100’ and perforating again. How do you assure your cement is going out the shoe if you downsqueeze. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: David Bjork <David.Bjork@hilcorp.com> Sent: Wednesday, November 6, 2024 1:47 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: 02-31 P/A sundry# 324-222 PTD 199-015 Mel, Program update Fullbore went out to confirm TxIAXOA communication before cementing. We were unable to get returns from the OA. We were able to pump down the OA at 5bpm~ 150- psi (110bbls). There was no pressure response on the IA during pumping. We would like to modify the procedure to abandon the OA by down squeezing ~100bbls of cement. Please call if you have any questions. Best Regards, Dave Bjork The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:Approval: 20241107 1113 02-31 P/A sundry# 324-222 PTD 199-015 Date:Friday, November 8, 2024 8:27:29 AM From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, November 7, 2024 5:31 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: 20241107 1113 02-31 P/A sundry# 324-222 PTD 199-015 Thanks Jack. Mel From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Thursday, November 7, 2024 5:17 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; David Bjork <David.Bjork@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: 20241107 1113 02-31 P/A sundry# 324-222 PTD 199-015 Hi Dave – Is there any sign of communication from the IA into the OA post-perfs? I realize there weren’t returns up the OA and there was not a pressure response on the IA while pumping on the OA. If there is potential communication then both the OA down squeeze and TxIA cement plug should be pumped in concurrence to avoid any issues. You have approval to modify the procedure to abandon the OA by down squeezing ~100 bbls of cement. If there is potential IAxOA communication perform both the OA down squeeze and the TxIA plug on the same rig up. Jack From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, November 7, 2024 11:17 AM To: David Bjork <David.Bjork@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: 20241107 1113 02-31 P/A sundry# 324-222 PTD 199-015 David, Thanks for this information. Jack Lau is now working PBU. He and I have discussed this. He will be the approver for the rest of this sundry work. He will get back to you with conditions later today. For Jack’s benefit, this can all be done via email. Please copy me on the remaining correspondence for the P&A work. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Jack and Bryan From: David Bjork <David.Bjork@hilcorp.com> Sent: Thursday, November 7, 2024 10:59 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: 02-31 P/A sundry# 324-222 PTD 199-015 Morning Mel, We made 3 gun runs with 2-3/4” (4ft) BH RDX charges and perforated 3,403ft- 3,412ft. I was unable to get larger guns in the hole due to tubing buckling. I could not get to target depth with; 10ft 3.125”, 10ft 2-7/8”, 6ft 3-3/8”. We could move up and perforate again, I would not expect the results to change. Modeling indicted we should have a 0.294” holes in the 7”. We can get deeper penetrating charges but they all risk damaging the 9- 5/8” casing. Historically the OA has exhibited and behaviors consistent with an open shoe. We were able to put away a casing volume of brine with no response in the IA ,conductor and neighboring wells. 3/16/99 13.8gpm @ 140 psi 9/12/07 2bpm @ 40-psi CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 12/31/09 2bpm @ 200-psi 2/18/11 4bpm @ 200-psi 5/10/24 3bpm @ 170-psi Best Regards, Dave From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, November 6, 2024 4:52 PM To: David Bjork <David.Bjork@hilcorp.com> Subject: [EXTERNAL] RE: 02-31 P/A sundry# 324-222 PTD 199-015 David, Did you perforate at 3400’ MD? How about moving up 100’ and perforating again. How do you assure your cement is going out the shoe if you downsqueeze. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: David Bjork <David.Bjork@hilcorp.com> Sent: Wednesday, November 6, 2024 1:47 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: 02-31 P/A sundry# 324-222 PTD 199-015 is safe. Mel, Program update Fullbore went out to confirm TxIAXOA communication before cementing. We were unable to get returns from the OA. We were able to pump down the OA at 5bpm~ 150- psi (110bbls). There was no pressure response on the IA during pumping. We would like to modify the procedure to abandon the OA by down squeezing ~100bbls of cement. Please call if you have any questions. Best Regards, Dave Bjork The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 02-31A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 199-015 50-029-22227-01-00 ADL 0028308 11215 Conductor Surface Intermediate Liner Liner 8948 80 3461 8699 620 2829 7003 20" 9-5/8" 7" 5-1/2" 2-7/8" 6916 38 - 118 38 - 3499 37 - 8735 8454 - 9074 8322 - 11151 2500 38 - 118 38 - 3495 37 - 8415 8175 - 8708 8060 - 8944 9470 520 2020 5410 4490 13890 7003 , 8830 1530 3520 7240 7000 13450 8790 - 11000 4-1/2" 12.6# 13cr80 , L80 34 - 84398461 - 8950 Structural 4-1/2" Baker S3 (2) No SSSV 8199 , 8311 8051 , 7953 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY 5-1-2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:49 am, Apr 17, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.04.16 16:44:23 - 08'00' Bo York (1248) 324-222 10-407 MGR24APR24 DSR-4/23/24 * AOGCC to witness cement in all annuli before grouting. * AOGCC to witness cement in all annuli after grouting. * AOGCC to witness marker plate in place. Photo document as described. SFD 4/20/2024*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.26 08:24:52 -08'00'04/26/24 RBDMS JSB 042624 P&A Sundry Well: PBU 02-31A PTD #199-015 Well Name:PBU 02-31A API Number:50-029-22227-01 Current Status:Shut-In Producer Rig:SL, EL, FB Estimated Start Date:May 2024 Estimated Duration:1month Regulatory Contact:Carrie Janowski 564-5179 Reg.Approval Req’d?Yes - 403 First Call Engineer:David Bjork 907 564-4672 (o)907 440-0331 (m) Second Call Engineer:Oliver Sternicki 907-564-4891 (O) Current Bottom Hole Pressure:3,380 psi @ 8,800’ TVD 7.4 PPGE | Calc from shut in WHP Max. Anticipated Surface Pressure:2,500 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:200 psi (Taken on 02/28/23) Min ID:2.38” ID CT liner crossover @ 8,326’ MD Max Angle:97 Deg @ 11,007’ Brief Well Summary: 02-31 was drilled in December 1991 and worked over in 1995 and 2008. It was coil sidetracked to a new BHL in 1999. In Sept 2021 a subsidence drift set down at 371 ft. A MIT and CMIT both passed on 9/21 after securing the well with a nipple reducer and plug. The well has been offline since 2020 due to high GOR. A reservoir abandonment was performed in 2022. Objective: Plug and abandon the well to surface. 03/19/2022 TOC was tagged with slickline at 6,990 ft. Recovered good sample, witnessed by Bob Noble. 03/19/2022 MIT-T to 2,500 psi (passed) witnessed by Bob Noble. MIT-IA to 2,500 psi (passed) witnessed by Bob Noble. Wells Support: 1. MIT-OA to 1,000 psi or establish LLR (estimated 4 bpm @ 200 psi) 2. ND tree, install dryhole tree for final cementing. E-line: 3. Perforate 4-1/2” tubing, and 7” casing @ ~3,400 ft MD w/ 2-7/8” BH HMX guns (or similar), 6 spf, 60 deg phase. Fullbore: 4. Circulate TxIAxOA, The OA is filled with crude or diesel. 5. 5 bbls MeOH 6. 290 bbls FW or 9.8 ppg brine (can forgo the brine if going right into cementing – brine is only for FP). Lead each stage with a soap pill. Pump down the tubing taking returns up the IA, when circ’d out close in IA and take returns from the OA. Max pressure 2,000 psi. Volumes: 3,400ft of 4-1/2” tubing 51.7 bbls 3,400ft of 7” x 4-1/2” annulus 63.2 bbls 2,000ft of 9-5/8” x 7” annulus 101 bbls 3400ft -mgr P&A Sundry Well: PBU 02-31A PTD #199-015 7. RU cementers and pump TxIAxOA cement plug surface-to-surface as follows: ¾5 bbls MeOH ¾30 bbls hot FW + surfactant (160 deg F) ¾5 bbls FW ¾240 bbls 14-15.8 ppg Class G or Arctic Set cement (24 bbls excess) Pump down the tubing taking cement returns up the IA, when cement is seen at surface close in IA and take returns from the OA. Max pressure 2,000 psi. Volumes: 3,400ft of 4-1/2” tubing 51.7 bbls 3,400ft of 7” x 4-1/2” annulus 63.2 bbls 3,400ft of 9-5/8” x 7” annulus 101 bbls =216 bbls Total cement: 240 bbls Cement Design Parameters: ¾SBHT: 10 deg F @ 800’ MD ¾Thickening time: 4 hours ¾Fluid Loss: No Fluid Loss additives required. Wells Support 8. Excavate and install shoring box. 9. Cut off all casings 3’ below original tundra level. 10. AOGCC witness of TOCs before top-jobbing with cement. 11. Top job of cement voids in all annuli. 12. Bead-weld ¼” thick steel marker cap on the 20” conductor. 13. AOGCC witness of installed marker cap before backfilling. 14. Remove shoring box and backfill. Marker cap as follows: Hilcorp North Slope, LLC PBU 02-31A PTD#: 199-015 API#: 50-029-22227-01 Attachments: 1. Current Schematic 2. Proposed Schematic 3. Sundry Change Form -00 SFD Photo document TOC in annuli. - mgr PTD# 199-015 PBU 02-31A Photo document marker plate in place. - mgr P&A Sundry Well: PBU 02-31A PTD #199-015 Current Schematic: P&A Sundry Well: PBU 02-31A PTD #199-015 Proposed Schematic: P&A Sundry Well: PBU 02-31A PTD #199-015 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. 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Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Prod. Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" WELD 118 9-5/8" J-55 3495 7" L-80 8415 5" FL45 8708 2-7/8" L-80 8944 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 4/16/1999 4/5/1999 ADL 0028308 74-017 ~1900 (Approx.) 9074' / 8708'N/A None 11215 / 8946 MWD, Mem CNL , GR Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Oil-Bbl: 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 N/A 20 Bbls Class G Cement Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing 94.5# 36# 118 37 8735 Gas-Oil Ratio:Choke Size: 7003' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 9074 37 8175 DEPTH SET (MD) 8199 , 8311 / 7954 , 8051 PACKER SET (MD/TVD) 8322 38 CASING WT. PER FT.GRADE 15# 689759 688462 TOP SETTING DEPTH MD 38 SETTING DEPTH TVD 5951856 BOTTOM TOP 8-1/2" 38 12-1/4" HOLE SIZE AMOUNT PULLED 50-029-22227-01-00 PBU 02-31A 688426 5950629 210' FNl, 2252' FEL, Sec. 36, T11N, R14E, UM CEMENTING RECORD 5951045 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 3/19/2022 589' FNL, 3596' FEL, Sec. 36, T11N, R14E, UM 4646' FNL, 3528' FEL, Sec. 25, T11N, R14E, UM 199-015 / 321-623 Prudhoe Bay Field , Prudhoe Bay Oil Pool 68 7003' / 6916 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC WAG Gas 30" 6.5# 38 3499 1920 cu ft CSIII, 348 cu ft Glass G 3-5/8" 280 Sx Class G 11151 983 cu ft Glass G 8060 8454 84394-1/2" SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 189 cu ft Class G6" TUBING RECORD 27 bbls 15.8 ppg LARC Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment RECEIVED by James Brooks on 10/19/22 at 8:54 am Suspended 3/19/2022 JSB RBDMS JSB 110722 xGDSR-11/10/22A.Dewhurst 02APR25MGR05JUNE2023 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 8785' 8457' 8668' 8358' 8718' 8400' 8785' 8457' 9390' 8898' Top of Zone 1B 9390' 8898' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Dave Bjork Contact Email:David.Bjork@hilcorp.com Authorized Contact Phone: (907) 564 - 4672 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS 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. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Top of Zone 1B Top of Sag River Sand If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Bo York Authorized Title: Operations Manager Top of Sadlerochit Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Formation at total depth: Top of Shublik FORMATION TESTS Permafrost - Top This form and the required attachments provide a complete and concise record for each well drilled 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. 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. Summary of Work, Wellbore Schematic Signature w/Date: Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2022.04.13 12:07:52 -08'00' Bo York (1248) ACTIVITYDATE SUMMARY 3/1/2022 ***WELL S/I UPON ARRIVAL*** (Suspend/Re-enter Suspended) RAN 2.25" CENT, 2 7/8" X-CHECK TO XX-PLUG @ 8,223' MD (pressure loss) ***CONT WSR ON 3/2/22*** 3/2/2022 ***CONT WSR FROM 3/1/22*** (Suspend/Re-enter Suspended) PULLED 2 7/8" XX-PLUG FROM NIPPLE REDUCER @ 8,223' MD PULLED 4 1/2" X 2 7/8" NIPPLE REDUCER FROM 8,223' MD (covered in hard paraffin) B&F W/ 4 1/2" BRUSH, 3.50" GAUGE RING TO 3,000' SLM (lrs pumped 50bbls 180* crude) ***JOB COMPLETE, WELL SECURE*** 3/2/2022 T/I/O=246/360/22 Assist SL B&F (Stuck) Pump 2 bbls 60/40 'down tbg Pump 50 bbls 180* crude down tbg. final WHP's 330/695/41 SL on well at departure 3/8/2022 (Suspend/Re-enter Suspended) Assisted cement with cement plug. Pumped 5 bbls 60/40 followed by 200 bbls 2% SKL to establish injection rate. After cement pumped cement pill pumped 2 bbls 60/40 followed by 103 bbls diesel. FWHP's = 2908/138/17 Tag hung on master 3/8/2022 HES pump unit + LRS pump truck Reservoir P&A. MIRU. Pump well kill with 200 bbls 2%SKL + 5bbl 60/40. See log for injection pressures (tight). Pumped 20bbls of 15.8 class G, displaced with 60 deg diesel. Once cement hit pers, whp rose to 3000psi and held ~2880psi. Cement top ~7203'. FP surface/circulate through choke out to tanks. RDMO. ***Job Complete*** 3/19/2022 T/I/O= 84/VAC/VAC TEMP= S/I (LRS UNIT 76) ** (Suspend/Re-enter Suspended)Suspend RESERVOIR AOGCC MIT-T to 2500 PSI ( 2750 PSI MAX APPLIED) ( WITNESSED BY AOGCC BOB NOBLE ) MIT-IA to 2500 PSI ( 2750 MAX APPLIED) PUMPED 2 BBLS 10* CRUDE DOWN TBG TO REACH TEST PRESSURE.** PASS** BLED BACK TO 75 PSI (~ 2 BBLS) ( SEE LOG FOR DETAILS ) PUMED 2.5 BBLS 10* CRUDE DOWN IA TO REACH TEST PRESSURE. **PASS** BLED BACK TO 0PSI ( ~2.5 BBLS) (SEE LOG FOR DETAILS) . TAG HUNG ON MV & IA VALVE. DSO NOTIFIED OF POSSIBLE THERMAL EXPANSION. FWHP'S= 150/0/VAC 3/19/2022 ***WELL S/I ON ARRIVAL*** (Suspend/Re-enter Suspended) LRS PERFORMED PASSING STATE WITNESSED MIT-T TAGGED TOP OF CEMENT @ 6,990' SLM RECOVERED GOOD CEMENT SAMPLE (BOTH WITNESSED BY BOB NOBLE) ***JOB COMPLETE, LRS PERFORMING MIT-IA ON DEPARTURE*** Daily Report of Well Operations PBU 02-31A Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 InspectNo:susLOL220806125157 Well Pressures (psi): Date Inspected:8/6/2022 Inspector:Lou Laubenstein If Verified, How?Other (specify in comments) Suspension Date:3/19/2022 #321-623 Tubing:233 IA:74 OA:26 Operator:Hilcorp North Slope, LLC Operator Rep:Ryan Holt Date AOGCC Notified:8/5/2022 Type of Inspection:Initial Well Name:PRUDHOE BAY UNIT 02-31A Permit Number:1990150 Wellhead Condition Wellhead clean and free of any visual issues. Surrounding Surface Condition Surrounding area clean of any debris. Condition of Cellar No cellar box. Comments Location verified with Pad Map. Supervisor Comments Photos (3) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, September 2, 2022 9 9 9 9 9 9 9 9 2022-0806_Suspend_PBU_02-31A_photos_llPage 1 of 2Suspended Well Inspection – PBU 02-31APTD 1990150AOGCC Inspection # susLOL220806125157Photos by AOGCC Inspector L. Laubenstein8/6/2022 2022-0806_Suspend_PBU_02-31A_photos_llPage 2 of 2 By Anne Prysunka at 10:05 am, Sep 02, 2022 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Prod. Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" WELD 118 9-5/8" J-55 3495 7" L-80 8415 5" FL45 8708 2-7/8" L-80 8944 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 4/16/1999 4/5/1999 ADL 0028308 74-017 ~1900 (Approx.) 9074' / 8708'N/A None 11215 / 8946 MWD, Mem CNL , GR Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Oil-Bbl: 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 N/A 20 Bbls Class G Cement Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing 94.5# 36# 118 37 8735 Gas-Oil Ratio:Choke Size: 7003' Per 20 AAC 25.283 (i)(2) attach electronic information 26# 9074 37 8175 DEPTH SET (MD) 8199 , 8311 / 7954 , 8051 PACKER SET (MD/TVD) 8322 38 CASING WT. PER FT.GRADE 15# 689759 688462 TOP SETTING DEPTH MD 38 SETTING DEPTH TVD 5951856 BOTTOM TOP 8-1/2" 38 12-1/4" HOLE SIZE AMOUNT PULLED 50-029-22227-01-00 PBU 02-31A 688426 5950629 210' FNl, 2252' FEL, Sec. 36, T11N, R14E, UM CEMENTING RECORD 5951045 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 3/19/2022 589' FNL, 3596' FEL, Sec. 36, T11N, R14E, UM 4646' FNL, 3528' FEL, Sec. 25, T11N, R14E, UM 199-015 / 321-623 Prudhoe Bay Field , Prudhoe Bay Oil Pool 68 7003' / 6916 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC WAG Gas 30" 6.5# 38 3499 1920 cu ft CSIII, 348 cu ft Glass G 3-5/8" 280 Sx Class G 11151 983 cu ft Glass G 8060 8454 84394-1/2" SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 189 cu ft Class G6" TUBING RECORD 27 bbls 15.8 ppg LARC y Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 12:57 pm, Apr 13, 2022 Suspended 3/19/2022 MDG RBDMS 4/13/2022 MDG xGDSR-4/14/22DLB 04-26-2022MGR17JULY2023 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 8785'8457' 8668'8358' 8718'8400' 8785'8457' 9390'8898' Top of Zone 1B 9390' 8898' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Dave Bjork Contact Email:David.Bjork@hilcorp.com Authorized Contact Phone: (907) 564 - 4672 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). 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. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS 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. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Top of Zone 1B Top of Sag River Sand If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Bo York Authorized Title: Operations Manager Top of Sadlerochit Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Formation at total depth: Top of Shublik FORMATION TESTS Permafrost - Top This form and the required attachments provide a complete and concise record for each well drilled 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. 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. Summary of Work, Wellbore Schematic Signature w/Date: Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2022.04.13 12:07:52 -08'00' Bo York (1248) ACTIVITYDATE SUMMARY 3/1/2022 ***WELL S/I UPON ARRIVAL*** (Suspend/Re-enter Suspended) RAN 2.25" CENT, 2 7/8" X-CHECK TO XX-PLUG @ 8,223' MD (pressure loss) ***CONT WSR ON 3/2/22*** 3/2/2022 ***CONT WSR FROM 3/1/22*** (Suspend/Re-enter Suspended) PULLED 2 7/8" XX-PLUG FROM NIPPLE REDUCER @ 8,223' MD PULLED 4 1/2" X 2 7/8" NIPPLE REDUCER FROM 8,223' MD (covered in hard paraffin) B&F W/ 4 1/2" BRUSH, 3.50" GAUGE RING TO 3,000' SLM (lrs pumped 50bbls 180* crude) ***JOB COMPLETE, WELL SECURE*** 3/2/2022 T/I/O=246/360/22 Assist SL B&F (Stuck) Pump 2 bbls 60/40 'down tbg Pump 50 bbls 180* crude down tbg. final WHP's 330/695/41 SL on well at departure 3/8/2022 (Suspend/Re-enter Suspended) Assisted cement with cement plug. Pumped 5 bbls 60/40 followed by 200 bbls 2% SKL to establish injection rate. After cement pumped cement pill pumped 2 bbls 60/40 followed by 103 bbls diesel. FWHP's = 2908/138/17 Tag hung on master 3/8/2022 HES pump unit + LRS pump truck Reservoir P&A. MIRU. Pump well kill with 200 bbls 2%SKL + 5bbl 60/40. See log for injection pressures (tight). Pumped 20bbls of 15.8 class G, displaced with 60 deg diesel. Once cement hit pers, whp rose to 3000psi and held ~2880psi. Cement top ~7203'. FP surface/circulate through choke out to tanks. RDMO. ***Job Complete*** 3/19/2022 T/I/O= 84/VAC/VAC TEMP= S/I (LRS UNIT 76) ** (Suspend/Re-enter Suspended)Suspend RESERVOIR AOGCC MIT-T to 2500 PSI ( 2750 PSI MAX APPLIED) ( WITNESSED BY AOGCC BOB NOBLE ) MIT-IA to 2500 PSI ( 2750 MAX APPLIED) PUMPED 2 BBLS 10* CRUDE DOWN TBG TO REACH TEST PRESSURE.** PASS** BLED BACK TO 75 PSI (~ 2 BBLS) ( SEE LOG FOR DETAILS ) PUMED 2.5 BBLS 10* CRUDE DOWN IA TO REACH TEST PRESSURE. **PASS** BLED BACK TO 0PSI ( ~2.5 BBLS) (SEE LOG FOR DETAILS) . TAG HUNG ON MV & IA VALVE. DSO NOTIFIED OF POSSIBLE THERMAL EXPANSION. FWHP'S= 150/0/VAC 3/19/2022 ***WELL S/I ON ARRIVAL*** (Suspend/Re-enter Suspended) LRS PERFORMED PASSING STATE WITNESSED MIT-T TAGGED TOP OF CEMENT @ 6,990' SLM RECOVERED GOOD CEMENT SAMPLE (BOTH WITNESSED BY BOB NOBLE) ***JOB COMPLETE, LRS PERFORMING MIT-IA ON DEPARTURE*** Daily Report of Well Operations PBU 02-31A Superceded (inaccurate) From: Rixse, Melvin G (0GC) To: AOGCC Records (CED sponsored) Subject: 20220413 1151 Tag and Pressure test update PTD 199-015 02-31A reservoir suspension Date: Wednesday, April 13, 2022 4:01:06 PM From: David Bjork <David.Bjork@hilcorp.com> Sent: Wednesday, April 13, 2022 11:50 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD 199-015 02-31A reservoir suspension CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Mel, As requested in the sundry, I am sending you a note to confirm the top of cement is above 8,100'MD. The top of cement was tagged on slickline (3/19) 6,990ft SLM. Witnessed by Bob Noble, a good sample was recovered. A passing MIT-T to 2,500-psi was also performed and witnessed the same day. During the injectivity test the reservoir was very tight. Our injection rate settled out at 1.7BPM 2,800-psi. While displacing the 20bbls of cement, it basically locked up when cement hit the perfs. We went up to 3,000-psi in an attempt to squeeze cement away, it held 2,880-psi for 10 minutes. Thanks, Dave Bjork FS1 OE 564-4672o 440-0331c The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. SFD 12/13/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED By Samantha Carlisle at 8:11 am, Dec 13, 2021 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ■ • Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: Hilcorp North Slope, LLC 4, Current Well Class: 5. Permit to Drill Number: 199-015 Exploratory ❑ Development ■ Stratigraphic ❑ Service❑ 3. Address: 3800 Centerpolnt Dr, Suite 1400, 6. API Number: 50-029-22227-01-00 Anchorage, AK 99503 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in thes pool? N/A PBU 02-31 A - Will planned perforations require a spacing exception? Yes ❑ No ■ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 0028308 �PRLJDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 215 y12-2er 8947 8830 8495 2500 8830 9470 2021 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 38 - 118 38 - 118 1530 520 Surface 3461 9-5/8" 38 - 3499 38 - 3495 3520 2020 Intermediate 8699 7" 37 - 8735 37 - 8415 7240 5410 Liner 620 5-1/2" 8454 - 9074 8175 - 8708 7000 4490 Liner 2829 2-7/8" 8322 - 11151 8060 - 8944 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8790 - 11000 8461 - 8950 4-1 /2" 12.6# 13cr80, L80 35 - 8439 Packers and SSSV Type: 4-1/2" Baker S3 Packers Packers and SSSV MD (ft) and TVD (ft): 8199, 7953 No SSSV Installed 8311, 8051 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strastigraphic ❑ Development ■ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/20/2021 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ■ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Digitally signed by Bo York Contact Name: David Bjork cn=Bo York, SUS, North o p Authorized Name and Alaska LLC, ou=Alaska North B o YorkSlope, Slope, email=.10 14:: 2:00p.com Digital Signature with Date: Bo York Date: 2ort.t2.io ta:az:oo-os'oo' Contact Email: Davld.Bjork@hllCorp.COm Contact Phone:907.564.4672 Authorized Title: Sr. Area Operations Manager AOGCC USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 321-623 Plug Integrity E( BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: State to witness cement plug integrity. MIT-T and MIT -IA to 2500 psi. Cement tag with slickline, TOC —8100' MD. Post Initial Injection MIT Req'd? Yes ❑ No ❑ 10-407 3/22/2022 Spacing Exception Required? Yes ❑ No M Subsequent Form Required: '48%0M MDG RBDMS HEW 12/17/2021 DigitP"ually signed by Jeremy APPROVED BY 12/16/21 Jeremy Price Date:2821.12.1613:3839 Approved By: -Oslo"' COMMISSIONER THE AOGCC Date: Comm.dts 12/16/20211 CommJLC 12/16/20211 Sr Pet EngMGR15DEc21 ISrPetGeo SFD 12/13/2021 I Sr Res Eng DSR-12/15/21 Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. From: Guhl, Meredith D (OGC) To: Rixse, Melvin G (OGC); Carrie Janowski Cc: Carlisle, Samantha J (OGC) Subject: RE: Subsequent form Required Question on 02-31A (PTD 321-623) 10-403 Sundry Date: Tuesday, March 22, 2022 7:09:00 AM Attachments: 199-015 sundry 321-623 pagelonly.pdf Carrie & Mel, Yes, you are correct, a 10-407 is required. I've updated page 1 of the 321-623 sundry to reflect that, attached, and will include the email chain in the well history file. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhlC@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl(@alaska.gov. From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, March 21, 2022 2:56 PM To: Carrie Janowski <Carrie.Janowski@hilcorp.com> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: Subsequent form Required Question on 02-31A (PTD 321-623) 10-403 Sundry Carrie, I find AOGCC's'Suspension' process confusing. You are correct. It should be a 10-407 per 20 AAC 25.010 (c) - even though this is under the title "Re-entry of a suspended well" Attached it the guidance bulletin from our website. So additionally: 20 AAC 25.110 (e ) and (f) Hilcorp has a year to perform a well site inspection then 30 days to fill out a 10-404 for the 'inspection'. I will copy Merdith Guhl here at AOGCC. She handles the 10-407 process. She will let us know if I am wrong. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (MeIVIn.Rixse(@alaska.Rov). cc. Meredith Guhl From: Carrie Janowski <Carrie.Janowski(@hilcorp.com> Sent: Monday, March 21, 2022 1:53 PM To: Rixse, Melvin G (OGC) <melvin.rixse(@alaska.gov> Cc: David Bjork <David.Bjork(@hilcorp.com> Subject: Subsequent form Required Question on 02-31A (PTD 321-623) 10-403 Sundry CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello Mel, When you have a moment, please review the "Subsequent Form Required" section of the 10-403 Sundry for Suspension of 02-31A. Attached for your reference. It appears a subsequent 10-404 form was listed as a requirement, instead of a 10-407. If you agree, please let me know your preferred method for handling this. I apologize for not catching this sooner! Thanks! Carrie Carrie Janowski Regulatory Tech, Prudhoe Bay East Team Hilcorp North Slope (907) 564-5179 office (907) 575-7336 cell The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE 'ALASKA GOVLRNOR MIKE DUNLRAVY August 17, 2021 Industry Guidance Bulletin 21-002 Suspended Well Guidance Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Introduction: Suspension of a well or the renewal of the suspension of a well may be approved as outlined in 20 AAC 25.110. This guidance bulletin clarifies the requirements for initial suspension, suspension renewal and well -site inspections as well as timing. Initial Suspension. 1. Application for Sundry Approval (Form 10-403) must be approved before operations to suspend a well commence. 2. Well site inspection is required within 12 months following the initial suspension. 3. Initial suspension is valid for 10 years from the date of approval unless a different expiration date is specified by the AOGCC. Suspension Renewal. 1. Application for Sundry Approval (Form 10-403) must be approved before renewal is effective. 2. Submit a renewal application at least 60 days before the expiration of an existing suspension. 3. A well -site inspection must be completed within 24 months before expiration of the current suspension approval. Suspended Well Inspection. 1. Suspended well inspections must be performed when the well and surrounding area are free of snow and ice. Operator shall provide the AOGCC notice of at least 10 days before any inspection using the web notice form (http://aogweb.state.ak.us/TestWitnessNotification/). 3. Operator shall provide the opportunity for AOGCC inspectors to accompany the operator on the inspection tour. 4. Initial suspended well inspection is required within 12 months after initial suspension. 5. Subsequent well site inspection: a. Within 24 months before September 30 of every calendar year ending in 0 or 5. This well site inspection is not required if the initial inspection occurred within the prior 24-month period. b. Within 24 months before the submission of a request for suspension renewal. Industry Guidance Bulletin 21-002 Suspended Well Guidance Page 2 of 2 6. Report of Sundry Well Operations (Form 10-404) required within 30 days after any suspended well inspection. Well site Inspection Guidance. 1. Operator representative must be present for the AOGCC suspended well inspection. 2. Measure and record well pressures.1,2 Photos taken during the well site inspection must include: a. Well sign b. Wellhead from all four sides c. Down into the cellar d. Any gauges that are installed, permanently or temporarily, on the wellhead to show readings e. Pictures from the wellhead in all directions to show any debris 4. If the well site is in a remote location (not accessible by AOGCC-operated vehicle), it is the responsibility of the operator to provide transportation for the AOGCC inspector. 5. Inspecting wells annually is a good practice. Please share this Guidance Bulletin with appropriate members of your organizations. Questions regarding this guidance should be directed to Victoria Loepp at (907) 793-1247 or victoria.loepp@alaska.gov. Sincerely, Jeremy Digitally signed by Y Jeremy Price Price Date: 2021.08.17 11:55:18-08'00' Jeremy M. Price Chair i Wells wrapped must be uncovered to check for pressures. Water and snow must be removed. z The operator must have a procedure for managing water in the cellar, especially before freezing conditions occur. Instances have occurred where ice in the well cellar of suspended wells has damaged an annulus outlet and the equipment attached (valves, valve handles, gauges, flanges). Diesel and other annuli fluids have been released and leached into the adjacent well pad SFD 12/13/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED By Samantha Carlisle at 8:11 am, Dec 13, 2021 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ■ • Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: Hllcorp North Slope, LLC 4. Current Well Class: 5. Permit to Drill Number: 199-015 ' Exploratory ❑ Development ■ Stratigraphic ❑ Service❑ 3. Address: 3800 Centerpoint Dr, Suite 1400, 6. API Number: 50-029-22227-01-00 ' Anchorage, AK 99503 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in thes pool? N/A PBU 02-31A ' Will planned perforations require a spacing exception? Yes ❑ No ■ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 0028308 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): ,215 1122& 8947 8830 8495 2500 8830 9470 2021 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 38 - 118 38 - 118 1530 520 Surface 3461 9-5/8" 38 - 3499 38 - 3495 3520 2020 Intermediate 8699 7" 37 - 8735 37 - 8415 7240 5410 Liner 620 5-1/2" 8454 - 9074 8175 - 8708 7000 4490 Liner 2829 2-7/8" 8322 - 11151 8060 - 8944 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8790 - 11000 8461 - 8950 4-1/2" 12.6# 13cr80, L80 35 - 8439 Packers and SSSV Type: 4-1/2" Baker S3 Packers Packers and SSSV MD (ft) and TVD (ft): 8199, 7953 No SSSV Installed 8311, 8051 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strastigraphic ❑ Development ■ Service ❑ 14. Estimated Date for 12/20/2021 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ■ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Digitally signed by Bo York Contact Name: David Bjork cn=Bo York, c=US, North o p Authorized Name and Alaska LLC, ou=PJaska North B o YorkSlope, hilcorp.com Slope, email=.10 14: Digital Signature with Date: Bo York Date: zoz1.1z.�o �a:az:oo-os'oo' Contact Email: David.Bjork@hilcorp.com Contact Phone:907.564.4672 Authorized Title: Sr. Area Operations Manager AOGCC USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 321-623 Plug Integrity 2( BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: State to witness cement plug integrity. MIT-T and MIT -IA to 2500 psi. Cement tag with slickline, TOC --8100' MD. Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: 10-404 RBDMS HEW 12/17/2021 Digitally signed byleremy APPROVED BY 12/16/21 Jeremy Price Date: 2021.12.1613:3839 Approved By: 090"' COMMISSIONER THE AOGCC Date: Comm.dts 12/16/20211 CommJLC 12/16/20211 Sr Pet EnCIAGR15DEc21 Sr Pet Geo SFD 12/13/2021 sr Res Eng DSR-12/15/21 Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 02-31A PTD: 199-015 Well Name: 02-31A API Number: 50-029-22227-01-00 Current Status: Shut -In Rig: SL/FB Estimated Start Date: 12/20/21 Estimated Duration: 2 Reg.Approval Req'std? 10-403, 404 Date Reg. Approval Rec'vd: N/A Regulatory Contact: Carrie Janowski Permit to Drill Number: 1990150 First Call Engineer: Dave Bjork 907-564-4672 907-440-0331 Second Call Engineer: Ryan Thompson 907-564-5280 907-301-1240 Current Bottom Hole Pressure: 3,380 psi @ 8,800' TVD 7.4 PPGE I Calc from shut in WHP Max. Anticipated Surface Pressure: 2,500 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHIP: 2,500 psi (Taken on 09/06/21) Min ID: 2.38" ID CT liner crossover @ 8,326' MD Max Angle: 97 Deg @ 11,007' Brief Well Summary: 02-31 was drilled in December 1991 and worked over in 1995 and 2008. It was coil sidetracked to a new BHL in 1999. In September 2021, a subsidence drift set down at 371ft. A MIT and CMIT both passed on 9/21 after securing the well with a nipple reducer and plug. The well has been offline since 2020 due to high GOR. Objective: Pull plug and nipple reducer. Suspend reservoir with fullbore cement job. MIT-T to 2,500-psi, AOGCC to witness. Tag cement top with slickline, AOGCC to witness. A variance to the provisions of 20 AAC 25.110 (c) (2) is requested under 20 AAC 25.112 (i). 8,223 Slickline: 1. Pull 2-7/8" PX plug from 8,223'. Pull nipple reducer from 8-,P-r3ft. Fullbore: 1. Pump injectivity test, bullhead into reservoir. i. 10 bbls McOH ii. 200 bbls 1% KCL / SW iii. Freeze Protect as required iv. Max pressure 2500 psi 2. Pump Reservoir Abandonment Plug, TOC will be at -8,100' MD inside the 4-1/2" tubing. Bullhead into the reservoir as follows: i. 10 bbls McOH ii. 10 bbls fresh water / iii. 20 bbls Class G Cement as per desig. May have to squeeze away up to 15bbls. v iv. 5 bbls freshwater v. Foam Ball / vi. 118 bbls diesel (@ 70-80 deg F) J vii. Max pressure 2500 psi. 02-31A PTD: 199-015 Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab +/- 0.1 can be batch job) Slurry Temperature: between 800 and 110°F Fluid Loss: 20-100cc/30 min Compressive Strength: 1000 psi in 48 hrs. Thickening Time: Minimum 5 hours 3. MIT-Tto 2500 psi. —AOGCC Witnessed MIT -IA to 2500 psi. State to witness. Slickline: 1. Drift and tag to TOC inside the 4-1/2" tubing. — AOGCC Witnessed Notify AOGCC office if TOC above 8100' MD or deeper than 8311' MD. 02-31A PTD: 199-015 Wellbore Schematic TIC= Cw Yd31FEAD= FMC ACILJATOR= BAKFRC OKB.ELLV 88' BF. ELLV KOP= Max Angle = Datum MD = DatumTVD= 59w, 97' @ 11007' 9331' 8800'SS ID=8.921- Minimum 10 = 2.38" 4p 8326' 3-912' X 2-718- XD PIN TBG, 1260,13CR-80 VAM TOP, 8285' >pt, D = 3.958' 4-11Z-TBGSTUB 401nIMB] &292' I TOP OF 2-718" LW ID = 2.441" I 4-112' TBG, 12.69, L-W NSCT, 8439' A 152 bpf, D = 3.950" TOP OF 5" LNR 8454- 7' CSG, Z6tl, L$0, ID = fi�7� $738' TOP OF 1MiPSTOCK 5- LW IW,13OR RAS, .0189 tip1, ID= 4.408" 9525 PERFORATION SUMMARY REF LOG: CNL ON 04118/99 ANGLE AT TOP PERF' 32' Q 8790' Nate, Refer to Production 09 for Wtodcal pert data SIZE SPF INTERVAL Op(Sga SHOT I S02 1,60" 6 a790.0515 0 12M7114 2- 4 9600 - 9740 C D9102199 2- 4 �10450-1100D C 04MSMD SAFETY NOTES: WELL ANGLES 70-@ UM', 0 2 31 A '""CHROME TBG & LNR m H4-IrZ HES XNIP, 1)=3.813- GAS LIFT MANDRBS [D=&938'] D DEN I TYPE VLV LATCH POF * 2 1 KBMG I DMY I BK 0 9 1 KBMG DMY BK 0 41/2" HES X NIP, 0 - 3.813" $1 W -17 X 4-1 Q" BKR S-3 PKR, la - 3Z75" 022W 4-1F1" HES X NIP. IB = 3.913- 6223' 4-12- x 2 71a- NIP REDUCER [09126121 ] 8223' 2-718' F'% PLUG [08128fi1 j R301 • 7• x 4-112' LN30UEOV9ffiFiOT 831-r 7- X 4-1l2- BKR S-3 PKF D - 3.a75" 1 5322' H3-112. 5KRDELOY SLV, D=3.00- 832T 3-I/2- X 2-718- XO PIN, ® E LMDTTLOGG®07111998 8454 T x 5" Tw LNR HGR D - 7 -j2-718' BKRCIBP(11124114) MIILOUT WIDOW [02-31A] 9074' -9080' 947$• SLM RSH - w- SLF FROM BKR 2-718' CBP RB ED DH 1012411IM 1 2-716- LNR 6. FBp, L-aO, .0358Ipf, ID-2.441- H 1IWWI- DATE REV BY COMMENTS OATS I REV BY CONNEMS 12J91 AUDI3 OPoGINAL COMPLETION 08/28/74 GTVWJMUFISH LEFT DH V2Zl4 06/22195 DIG 04119199 CORI RM SIDETRACK 02-31A 11124n4 DLIYPJC PUSH FISH OW SET CISP 12/07/14 MGBIPJCADPERF 0112261a8 D14 RWO 09/29721 JKCIJMD SET NIP RED & PLUG E 02R0114 CJN'JMD D7/16M4 DWIJMD PULL PXN /SET R SCRN (07JI7114) PALED ROCK SCREEN 07/18/14 1210221 ABNMD CSG DEPTH CORRECTIOP I PRUDHOE BAY UNIT IIII WELL 02-31A PERMIT No' 1990150 API No: 50-029 22227-01 21 SEC 36 T11N RI4E 592' FNL & 1684' FWL Falcorp North Slope, LLC 02-31A PTD: 199-015 Proposed Wellbore Schematic TREE= CIW WELLHEAD= FMC ACTUATOR = BAKER C OKB. ELEV = 6B' BF. EiEV = KOP= 5900' Max Angla = 97' @ 11007' Datum MD = 9331' Datum TVD = 8800' SS 02-31 A proposed 9�18' CBG, 38#, JI5 BTC, D = 8.921' Proposed Top of Cement 8,100ft Minimum ID = 2.38" @ 8326' 3-1►2" X 2-718" XO PIN 4-lr2" TBG, 12194',13CR-80 VAM TOP, 828F .0152 bpf, 0= 3,958' 4-11W TBG STUB (01121108) 8292' - D = 2441' H 832W 4-112" TOG, 12.6#, L-80 NSCT, .0152 bpf, D = 3.958" TOP OF 5"LhR "-�8454' T CSG, 269, L-80, ID = 6.276' 873w TOPOFWFIP"TOCK 5" LW 15#, 131133t FL4S, 0189 bpf, ID = 4 40B" 9625' PERFORATION SUMMARY REF LOG: CNL ON 04118199 ANGLE AT TOP PERF: 32` @ 8790' Note: Refer to Production DB for historical erl' data SIZEISPF1 INTERVAL O n15 z SHOT SOZ 1.58' 6 8790 - 8815 O 12/07/14 2" 4 9600-9740 C 0=2199 2" 4 10450 -11000 C 04/19/99 2-718" LW 6.16#, L-80, SAFEfY NOTES: W91 ANGLE> 70" 9455'. '"'CHROMETBG & LNR- 2102' -� 4-112' HFS X NIP, ID=3813" GAS LIFT MANDRELS (I13-3.938') F1 MITVDIDEVI TYPE VLV IATCH P—r SATE 3509 3506 2 1 KBMG I DIVY BK 1 0 12130/09 5508 5504 1 KBMG DM7' BK 0 12/30/09 817V 4-1f2- HES X NIP. 0 = 3.813' X 4-112" BKR S3 PKR, ID = 3-875" .1P2' HES X NIP, III =3.913" 17'X4-1t2"BKRS-3PKK0=3.875' 1 832Z -13-1f2- BKR DEPLOY SLV, D = 3.00- 83� 3-12"X2-78'XOFiRD=2.3ir 843W I--`4-112" VMLEG tiI-Wq, 0= 3.95W BND TT LOGGED 07710198 8464 I 7' X 5- TMV LNR HGIR D = 7 B830' H2-718" BKRCIBP(11124114) MLLOI rr WINDOW (02.31A) 9074' - 9080' 9470- SUM HSH - ix i" SUP FROM BKR 2-71W CJBP PUSHH3DH 1(1124114) 111147 1 1121T DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: 0231A PERMT ND: 1990150 API ND: 50-029-22227-01 36, T11 N, R74E, 592' FNL & 1684' FWL Hicorp North Slope, LLC 12191 AUD13 ORIGINAL COMPLETION 08/26/14 11TWUME FISH LEFT DH IUM14 06=95 D16 RWO 11/24/14 DLH'PJC PUSH FISH DW SET CIBP "M9199 CDRt SIDETRACK 02.31A 12/07114 MGB/PJC ADPERF 01126109 014 RWO 0929121 JKCIJMD SET NIP RED & PLUG (9126f21)SEC 02/20/14 CJNIJMD PULL PXN 1SET R SCRN 02117/14 12/0221 ABIJMD CSG DEPTH CORRECTIO 07116114 DWIJMD PULLED ROCK SCREEN 07/16114 Hilcorp North Slope, LLC Hilcorp North Slope, LLC Changes to Approved Work Over Sundry Procedure Date: December 10, 2021 Subject: Changes to Approved Sundry Procedure for Well 02-31A Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the workover (WO) "first call" engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved B Initials AOGCC Written Approval Received Person and Date Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date STATE OF ALASKA A CA OIL AND GAS CONSERVATION COMM DN REPORT OF SUNDRY WELL OPERATIONS RE�EIVED DE� 30 2014 1. Operations Abandon Repair Well LJ Plug Perforations 2 Perforate0 Other Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver❑ L Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended W❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work: Development 0 Exploratory ❑ Stratigraphic ❑ Service ❑ 5. Permit to Drill Number: 199-015-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-22227-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028308 PBU 02-31A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11220 feet Plugs measured 8830 feet true vertical 8946.63 feet Junk measured 9470 feet Effective Depth measured 8830 feet Packer measured See Attachment feet true vertical 8494.85 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None; None None None Conductor 80 20" 94# H-40 38.3 - 1'18.3 38.3 - 118.3 1530 520 Surface 3460.86 9-5/8" 36# J-55 37.8 - 3498.66 37.8 - 3495.35 3520 2020 Intermediate 8698.67 7" 26# L-80 36.66 - 8735.33 36.66 - 8414.67 7240 5410 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 8790 - 8815 feet 9600 - 9740 feet 10450 - 11000 feet True Vertical depth 8460.88 - 8482.08 feet 8950.73 - 8944.14 feet 8953.08 - 8950.48 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JAN 1 2 2015 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 369 29807 11 400 1212 Subsequent to operation: 779 36587 24 60 890 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas ❑ WDSP❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUiO 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry. Catron((_BP.Com Printed Name Garry Catron Title PDC PE SignatureJL_4�Phone 564-4424 Date 12/29/2014 Form 10-404 Revised 10/2012 Su Original Only RMM JAN - 4 2015 I Packers and SSV's Attachment I L0028308 SW Name Type MD TVD Depscription 02-31A PACKER 8201.61 7955.67 4-1/2" Baker S-3 Perm Packer 02-31A PACKER 8322.02 8060.49 4-1/2" Baker S-3 Perm Packer Casing / Tubing Attachment ADL0028308 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 38 - 118 38.3 - 118.3 1530 520 INTERMEDIATE 8699 7" 26# L-80 37 - 8735 36.66 - 8414.67 7240 5410 LINER 2829 2-7/8" 6.16# L-80 8322 - 11151 8060.47 - 8944.07 13450 13890 LINER 620 5" 15# L-80 8454 - 9074 8174.62 - 8708.03 8290 7250 SURFACE 3461 9-5/8" 36# J-55 38 - 3499 37.8 - 3495.35 3520 2020 TUBING 8269 4-1/2" 12.6# 13Cr80 34 - 8303 F 34.1 - 1 8044.021 8430 7500 TUBING 155 4-1/2" 12.6# L-80 8295 - 8450 1 8036.69 - 8171.18 8430 7500 Daily Report of Well Operations ADL0028308 ACTIVITYDATE ***WELL S/I ON ARRIVAL*** (Profile modification) PULL COMPLETE 4-1/2" x 26' BAKER SLIM-PAK ROCK SCREEN FROM 8,197, SLM / 8,223, MD. DRIFT TO DEVIATION AT 9,445' SLM W/ 2.25" CENT, 1.56" x 20' DUMMY GUN, S-BLR (No sample or issues). 7/15/2014 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** ***WELL SI ON ARRIVAL*** (SLB E-LINE TO SET CIBP WITH BAKER/LRS ASSIST) INITIAL T/I/O = 2350/0/0 LRS PERFORMED L&K AFTER L&K THE SSV DOESN'T STROKE COMPLETELY CLOSED. GREASE CREW UNABLE TO SERVICE ACTUATOR. MASTER VALVE CLOSED TO GET OFF WELL ***WILL RETURN AT LATER DATE TO SET CIBP/PERF AFTER SSV REPAIRED*** WELL LEFT SHUT IN -- NOTIFIED PAD OP OF WELL STATUS FINAIL T/I/O = 0/0/0 8/17/2014 ***JOB DELAYED*** T/I/O - 2375/0/25 Assist E-Line MIT T to 2500 psi. Loaded tubing with 5 bbls of meth and 200 bbls of crude. SSV failed to close for E-line. Job postponed Final WHP - 100/0/20. E-Line 8/17/2014 on well at departure. T/1/0=58/Vac/20, Temp=S/I, Assist E-line (Assist) Pumped 5 bbls meth spear followed by 50 bbls crude to load tubing. Pumped 6 bbls of 100* crude down tubing while attempting to pump E-line 8/21/2014 down hole. E-line unable to set plug. FWHP's= Vac/Vav/18 IA,OA=OTG ***WELL SI ON ARRIVAL, MASTER ALSO SI*** (SLB E-LINE TO SET PLUG IN 2-7/8" LNR WITH BAKER, LRS ASSIST) INITIAL T/l/O = 0/0/0 SLB: MIRU, PT. LRS: MIRU, PT, PUMP 55 BBLS, R/D. SLB: RIH, SET DOWN ON SLV AT 8322'. LRS: R/U, PT, UNSUCCESSFUL PUMPING DOWN AT MIN RATE. POOH, LAY EQUIPMENT DOWN TO RETURN TOMORROW TO COMPLETE THE JOB. FINAL T/l/O = 0/0/0 8/21/2014 ***WELL SI ON DEPARTURE*** T/I/O=10/Vac/20, Temp=S/1, Assist e line (Pre perf) Pumped 5.5 bbls of 100* crude down Tbg for E- 8/22/2014 line. E-line unable to set plug. FWHP's= 140/vac/20 IA,OA=OTG T/I/0 = 0+/VAC/20. Temp = Sl. TBG pressure (E-line request). 8/22/2014 SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 0400. T/1/0=400/vac/40 Temp=Sl Assist ASRC testers F-protect F-Line Pumped 14 bbls of 60/40 meth H2o down F-line shut IGV & psi up to 1500 psi with 2.6 bbls of 60/40 meth H2o Wing shut swab shut 11/10/2014 ssv shut master shut & locked casing valves open to gauges Final Whp"s=400/vac/40 Daily Report of Well Operations ADL0028308 T/1/0= 1400/600/300. Torqued up tree cap, test to LP 300 & HP 5000 Pass. RDMO ***JOB 11/11/2014 COMPLETE*** ***WELL S/I ON ARRIVAL***(profile-mod) MADE TWO RUNS W/ 3.75" CENT & 3.47" MAGNET TO BKR DEPLOYMENT SLV @ 8,322' MD. *** RECOVERED 1 SLIP FROM CIBP *** 11/19/2014 ***WELL S/I UPON DEPARTURE, BEGIN WEATHER STBY*** ***WELL S/I ON ARRIVAL*** (profile modification) DRIFTED TO DEVIATION W/ 2.30" CENT, 1.85" MAGNET @ 9,453' SLM (recovered 2 slips and misc piece of metal) TAGGED CLEAN DEPLOYMENT SLEEVE W/ 3.75" CENT, 3.50" LIB @ 8,294' SLM 11/22/2014 ***CONT WSR ON 11/23/14*** ***CONT WSR FROM 11/22/14*** (profile modification) LRS LOADED TUBING W/ 200bbls OF CRUDE ATTEMP TO SET BKR 2-7/8 CIBP W/ DPU, UNABLE TO PASS TOP OF DEPLOYMENT SLEEVE MADE 4 RUNS W/ 1.85 MAGNET & 2.30" CENT, RECOVERED 2 ADDT'L SLIPS & 1 MISC PIECE OF METAL RAN 11' x 2.0" DUMMY GUN, XO, 2.30" CENT, 2.25" CENT, 1.75" LIB DOWN TO 8,900' SLM TAGGED CLEAN DEPLOYMENT SLEEVE W/ 3.75" CENT, 3.50" LIB @ 8,294' SLM 11/23/2014 ***CONT WSR ON 11/24/14*** T/1/0= 2452/vac/12 Temp= SI, Assist Slickline with Load & Test. (SET CIBP & PERF) Pumped 5 bbls meth spear followed by 200 bbls, 115*, crude down TBG to load. 11/23/2014 ***WSR Continued on 11-24-14*** ***WSR Continued from 11-23-14*** Assist Slickline with Load & Test. (SET CIBP & PERF) MIT-T 2500 psi ***PASSED*** Pumped 5 bbls, 35*, crude down TBG to reach test pressure of 2500 psi. Test results follow; 1 st 15 min TBG lost 103 psi. 2nd 15 min TBG lost 36 psi for a total loss of 139 psi in 30 min test. Bled back TBG to 80 psi, returned — 3 bbls. Casing valves= OTG's. MIT tag hung 11/24/2014 on MV. Slickline on well upon LRS departure. FWHP's= 80/vac/15 ***CONT WSR FROM 11/23/14*** (profile modification) SET BKR 2-7/8" CIBP W/ HALLIBURTON DPU @ 8,801' SLM (8,830' MD) LRS MIT-T to 2500# - PASS 11/24/2014 ***WELL LEFT S/I ON DEPARTURE*** Daily Report of Well Operations ADL0028308 'WELL SHUT-IN ON ARRIVAL' SSV CLOSED ON ARRIVAL, INITIAL T/I/O = 200/0/0, SSV 4.25" STROKE SHOT 25' - 1.56" HSD 6 SPF 60 DEGREE PHASED PJ 1606 GUNS FROM 8790'-8815, DEPTH CORRECTED TO SLB MEMORY CNL LOG DATED 18-APR-99. CONFIRMED ALL SHOTS FIRED. TAGGED PLUG AT 8828'. LEFT WELL SHUT-IN AND SECURE, HAND -OVER WITH DSO PRIOR TO DEPARTURE. FINAL T/I/O = 100/0/0 12/7/2014 ""'JOB COMPLETE' TREE = C!W WELLHEAD = FMC ACTLJA TOR = BAKER C OKB. E-EV = 68' BF. 8-EV = KOP= 5900' Max Angie = 97- @ 11007' Datum M) = 9331' Datum TVD = 8800' SS 9-5/8' CSG, 36#, J-55 BTC, D = 8.921" 1-� 3515' Minimum ID = 2.38" a@ 8326'� 3-1/2" X 2-7/8" XO PIN 41/2" TBG, 12.6#, 13CR 80 VAM TOP, 0152 bpf, D = 3.958" 41/2" TBG STUB (01/21/08) 8292' - TOP OF 2-7/8" LNR D = 2.441 1— _ 8328' 4-1/2" TBG, 12.6#, L-80 NSCT, -� 8439' .0152 bpf, D = 3.958" TOP OF 5" LNR 0,2 -31 A 7• CSG, 26#, L-80, D = 6.276" I 8748' TOP OF WHIPSTOCK 906V j` 5' LNR, 15#, 13CR FL4S, .0189 bpf, D = 4.408" 9525' PERFORATION SUMMARY REF LOG: CNL ON 04/18/99 ANGLE AT TOP PE2F: 32` @ 8790' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OprdSgz SHOT SOZ 1.56" 6 8790 - 8815 O 12/07/14 2" 4 9600 - 9740 C 09/02/99 2" 4 10450 - 11000 C 04/19/99 SA NOTES: WELL ANGLE>7�"55'. —CHROME TBG & LNR — 2102' --� 4-1 /2- HES X NP, ID = 3. 813" GAS LIFT MANDRELS (D = 3.938") ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3509 5508 3506 5504 2 1 KBMG KBMG DMY DMY BK BK 0 0 12/30/09 12/30/09 8178' 41 /2" HES X NP, D = 3.813" 81"'-17 X 4-1/2" BKR S-3 RKR, D= 3.875" 8223' 41/2' FES X NP, D = 3.813" 8301' J-17" X 41/2" UNIQUE OVERSHOT 831 V 7" X 4-1/2" BKR S-3 PKR, D = 3.875" 8322' 3-1/2" BKR DEPLOY SLV, D = 3.00" 8327' 3-112" X 2-7/8" XO PN, JD = 2.38" 8417' 4-1/2" CAM DB-6 NP (9-CM, ID = 3.5" $439' 4-1l2" WLEG (9-CR), D = 3.958" F-845X -4 ELMD TT LOGGED 07/10/98 7' X 5" TIW LNR WP D = ? 84547 8830•-12-7/8" BKRCBP(11/24/14) MLLOUT WINDOW (02-31A) 9074' - 90 9470' SLM FISH - 1 x 1' SLIP FROM BKR 2-7/8" CIBP �, 7 1 PUSHED DH 1(1124/ 14 ) FBTD 11114_Y 2-7/8" LNR, 6.16#, L-80, .0058 bpf, D = 2.441" 1115V DATE REV BY COMMENTS DATE REV BY COMMENTS 12/91 ALU 3 ORIGINAL COMPLETION 08/26/14 GTW/JIW FISH LEFT DH (08/22/14) 06/22195 D16 RIND 11/24/14 DLWP.JC PUSH RSH DH SET CBP 04119/99 CDR1 SIDETRACK(02-31A) 12/07/14 MG&P.1C ADPERF 01/26108 D14 R WO 02/20/14 CJNJMD FULL PXN /SET R SCRN (02/17/14) 07/161141 DW/JMD I PULLED ROCK SCREEN (07/16114) TO 1121V PRUDHOE BAY UNIT WELL: 02-31A P94AT No: '1990150 API No 50-029-22227-01 SEC 36, T11N, R14E, 597 FNL & 1684' FWL BP Exploration (Alaska) I� U ri U BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 22, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 I lrc4l�/ '? 1 ?'rJ !tD py&G4C' 4 Subject: Corrosion Inhibitor Treatments of GPB DS-02 lqq—o t 5 Dear Mr. Maunder, 0,�, — -3 / A Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659-5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS-02 Date: 07/21 /2011 Well Name PTD # API # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na qal 02-01 B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02-02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02-03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02-04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02-05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02-06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02-07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02-08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02-09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02-10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02-11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02-12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02-13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02-14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02-15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02-16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02-17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02-18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02-19 1811860 1500292069300 Sealed NA Sealed N/A NA NA 02-20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02-21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02-22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02-23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02-24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02-25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02-26C 2050190 1500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02-27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02-28A 2041640 500292201201 Sealed Sealed N/A NA NA 02-29C 2040510 500292201103 65' Top Plate N/A NA NA 02-30B 2001260 500292220202 Sealed NA NA N/A NA NA 02-31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02-32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02-33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02-34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02-35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02-36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02-37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02-38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02-39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 0240 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 Schtemherger iska Data & Consulting Services ?5 Gambell Street, Suite 400 chorage, AK 99503-2838 TN: Beth Well Job S NO. 5385 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 02-31A 17-09 12-30 17-09 13-27A JX-02A MPJ-19A L-103 W-217 12-05AL1 V-224 D-14A 11-27 3-27/M-33 8148-00087 B3SO-00042 B9RH-00003 AWJB-00047 BALL-00009 AWJI-00065 AP30-00075 BALL-0001- AYKP-00056 B2NJ-00025 AYKP-00069 AWJI-00060 AP30-00068 B81(5-00012 SCMT — j TBG. CUTIFLOW DETECTION _ LDL MEM LDL USIT MEM LDL — USIT — 1 RST/WFL — C CH EDIT PDC USIT _ MCNL ( CH EDIT PDC USI MCNL C RST 19 RST 12/24/09 01/05/10 12/26/09 01/03/10 12/31/09 12/29/09 12/29/09 01/0606/10 11//10 09 09/29/09 12/14/09 11/15/09 11/06/09 11/18/09 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ASE ACKNOWLEDGE RECEIPT BY SIGNING Amn QPTI IQIJIMf- nurc nnov ewnu r.,. Aechical (Alaska) Inc. Alaska Data & Consulting Services technical Data Center LR2 1 E. Benson Blvd. 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 'NE&FEB 2010 • schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description 2 2000 NO. 5436 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD MPC-04 AXBD-00061 MEMORY-GLS - 11/17/09 1 1 NK-38A AWJI-00057 MEM PROD PROFILE L - 11/04/09 1 1 14-12 B3S0-00033 PRODUCTION PROFILE 11/13/09 1 1 13-35 B14B-00084 INJECTION PROFILE () 11/10/09 1 1 06-08A B14B-00082 PLUGBACK SET W/X-FLO C ECK - 11/08/09 1 1 H-30 AVIIH-00031 PRODUCTION PROFILE 11/14/09 1 1 18-11 A B2NJ-00038 MEM CNL & SCMT Qb 111/06/09 1 1 Y-238 AYKP-00055 GLS - ff4q a 11/22/09 1 1 N-24 AYS4-00109 PRODUCTION PROFILE- 11/08/09 1 1 02-31A AYKP-00053 PRODUCTION PROFILE 11/15/09 1 1 03-01 BBK5-00014 PRODUCTION PROFILE - 11/24/09 1 1 L-213 B581-00017 INJ PROFILE W/WFL 11/19/09 1 1 W-209 AYKP-00064 [NJ PROFILE W/WFL - 11/17/09 1 1 X-05 AP30-00072 PRODUCTION PROFILE 11/29/09 1 1 X-07 AYS4-00111 PRODUCTION PROFILE Q 11/27/09 1 1 .-.v •�,. V� ,•GV G•• • V • �a•V•�••�V N•�V •iG 1 VI11Y11YV VIYC liVr-i CHl.rl 1 V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 0 101 STATE OF ALASKA - � �a RECEIVED ALASKA OIL AND GAS CONSERVATION COMM SSION REPORT OF SUNDRY WELL OPERATIONS FEB 2 2 2008 1. Operations Performed: un & sas ccntk, commiss i ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re-EnteAd Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension -- 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory ❑ Service ❑ Stratigraphic 199-015 , 3. Address: 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22227-01-00 ' 7. KB Elevation (ft): 68 9. Well Name and Number: PBU 02-31A ' 8. Property Designation: 10. Field / Pool(s): _ ADL 28308 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11215 feet true vertical 8946 - feet Plugs (measured) N/A Effective depth: measured 11114 feet Junk (measured) N/A true vertical 8944 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 118' 20" 118' 118' 1530 520 Surface 3515' 9-5/8" 3515' 3512' 3520 2020 Intermediate Production 8748' 7" 8748' 8425' 7240 5410 Liner 620' 5" 8454' - 9074' 8175' - 8708' 8290 7250 Liner 2829' 2-7/8" 8322' - 11151' 8060' - 8944' 13450 13890 Perforation Depth MD (ft): 9600' - 11000' Perforation Depth TVD (ft): 8951' - 8950' 4-1/2", 12.6# 13Cr80 / L-80 8285' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker S-3 Packers 8199' & 831 V 12. Stimulation or cement squeeze summary: Intervals treated (measured): SGANNED MAR 1 7 2008 Treatment description including volumes used and final pressure: 13. Representative D ilv Avera a Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl casing Pressure Tubinq Pressure Prior to well operation: 208 13590 1 940 950 Subsequent to operation: 335 21144 2 1320 212 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: El Exploratory ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ® Oil ❑ Gas ❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 N/A Printed Name Sondra Stewman Title Drilling Technologist F Prepared By Name/Number: Sig tune Phone 564-4750 DateMi)I-DR Sondra Stewman, 564-4750 on Form 10-404 Revised 04/2006 �." / Submit Original Only S S�� FEB 2 8 2006 �S TREE =41/16" 5M FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 68' BF. ELEV = KOP = 5900, Max Angle = 97 @ 11007' Datum MD = 9331' Datum TV D = 8800' SS 191 ztl�Til 9-5/8" CSG, 36#, J-55, ID = 8.921" 3515' Minimum ID = 2.38" @ 8326' XO AT TOP OF 2-7/8" LINER 1 4-1/2" TBG: 12.6#. 13Cr-80..0152 bpf, ID = 3.958" 1—I 8285' TOP OF 2-7/8" LNR, ID = 2.441" 8328' TOP OF 5" LNR 8454' 7" CSG, 26#, L-80, ID = 6.276" 1-1 8748' 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 5" LNR, 15#, 13-CR, .0188 bpf, ID = 4.408" 1 9074' TOP OF WHIPSTOCK --T 9068' TOP OF CEMENT 1-1 9134' PERFORATION SUMMARY REF LOG: CNL ON 04/18/99 ANGLE AT TOP PERF: 83 @ 9600' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9600 - 9740 0 09/02/99 2" 4 10450 - 11000 0 04/19/99 S NOTES: HORIZONTAL WELL - 70° @ 94 ' "5-1/2" CHROME LNR & 4-1/2" CHROME 0 22® TBG'' 2101' -14-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ND = 3,938") 8178' 4-1/2" HES X NIP, ID = 3.813" 8199' 7" x 4-1/2" BAKER S-3 PKR, ID = 3.875" 82 4-1 /2" HES X NIP, ID = 3.813" 8300' UNIQUE MACHINE OVERSHOT 8311' 7" X 4-1/2" S-3 PKR 832Z 3.60" BKR DEPLOY SLV, ID = 3.00" 3325' 1-13.60" X 2-7/8" XO, ID = 2.38" 1 841T 1 4-1/2" CAM DB-6 NIP, ID = 3.635" 81 439' 1-14-1/2" WLEG1 8453' ELMD TT LOGGED 07/10198, MILLOUT WINDOW (02-31A) 9074' - 9080' PBTD 11114' 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" —r DATE REV BY COMMENTS DATE REV BY COMMENTS 12/91 ORIGINAL COMPLETION 02/15/08 KSB/TLH GLV C/O (2/10/08) 04/19/99 SIDETRACK 02/02/02 RN/TP CORRECTIONS 01/26/08 D14 RWO 01/27/08 /TLH I CORRECTIONS 02/11/08 SCG/PJC I GVL CORRECTIONS TD I —I 11215' PRUDHOE BAY UNIT WELL: 02-31A PERMIT No: 1990150 API No: 50-029-22227-01 SEC 36, T11 N, R14E, 3527.91' FEL & 4645.95' FNL BP Exploration (Alaska) 1 0 0 BP EXF Legal Well Name: 02-31 Common Well Name: 02-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 1 1 1 1 1 1 1/11/2008 12:00 - 20:00 8.00 RIGD P 20:00 - 00:00 4.00 MOB P 1/12/2008 00:00 - 10:00 10.00 MOB P 10:00 - 12:00 2.00 MOB P 12:00 - 13:30 1.50 RIGU P 13:30 - 14:00 0.50 RIGU P 14:00 - 16:00 2.00 RIGU P 16:00 - 18:30 2.50 DHB P 18:30 - 20:30 1 2.001 DHB I P 20:30 - 23:30 1 3.001 CLEAN I P 23:30 - 00:00 0.50 EVAL P 1/13/2008 00:00 - 03:30 3.50 WHSUR P 03:30 - 04:00 0.50 WHSUR P 04:00 - 04:30 0.50 WHSUR P 04:30 - 05:30 1.00 WHSUR P 05:30 - 06:30 1.00 WHSUR P 06:30 - 08:30 2.00 WHSUR P 08:30 - 11:00 2.50 WHSUR P Spud Date: 12/1 /1991 Start: 1 /11 /2008 End: 2/26/2008 Rig Release: 1/26/2008 Rig Number: PRE Prepare for Rig Move -Waiting on Well prep for DS2-31 (Weather -35 to -40) PRE R/D, prepare for Rig move. -Skid Rig floor back. PRE Move Rig off well 2-10. -Move to corner of Pad. -Sit down & wait on Pad prep. -No equipment available due to weather (-35 to -42). -Lay mats around 2-31. PRE Move rig and spot over well. PRE Shim around Rig. PRE Skid Rig floor to drilling position. -Berm & Spot Rockwasher - RU same. -Accept rig at 1400 hrs. PRE R/U Rig floor, Steam lines, Hydraulics & Air lines. -Berm & spot slop tank. -R/U hardline w/ inline choke manifold. DECOMP R/U to fill Tree with diesel. -R/U Lubricator & test to 500 psi - OK. -Attempt to pull BPV. Steam wellhead. -Retrieve BPV. -R/U Ts valves & hoses. -Take on 580 bbls of 8.5 ppg 140 degree Seawater. DECOMP PJSM: -On hooking up Hardline, Slop tank & Choke. -Presure test hardline to 3,500 psi - OK. DECOMP PJSM: R/U to reverse circulate. -Reverse circulate 55 bbls @ 126 gpm / 180 psi. -Blow down lines. -R/U to circulate down Tbg. -Pump 140 bbls @ 126 gpm / 400 psi. -Shut down & blow down. -Let diesel migrate for 30 minutes. -Pump 40 bbis of additional Seawater. -Pump @ 126 gpm / 240 psi. -Shut down & blow down to slop tank. DECOMP PJSM on P/U & R/U SLB E-line. DECOMP R/U SLB w/ full pressure control. -Test to 1,000 psi / 10 minutes - OK. DECOMP Prepare & RIH w/ SLB Gauge ring /junk basket. -Tag up on Ice plug just below Master valve. DECOMP Apply steam to Tree. -Circulate down Tbg up IA. -Noticed diesel in returns. Shut down. DECOMP Re -Rig up to Hardline, Choke & Slop tank. -Circulate an additional 100 bbls out to Slop tank. DECOMP RIH w/ SLB E-line Gauge ring / Junk basket. -Tag collapse at 3,588' md._ -Locate collar at 3,556' and - POH. DECOMP R/D Gauge Ring / Junk Basket. -PJSM - R/U Power Jet cutter. DECOMP RIH w/ cutter -Locate collar at 3,555' md. Printed: 2/4/2008 11:21:23 AM 1 0 0 BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: 02-31 Common Well Name: 02-31 Spud Date: 12/1/1991 Event Name: WORKOVER Start: 1/11/2008 End: 2/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 1/26/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/13/2008 08:30 - 11:00 2.50 WHSUR P DECOMP -Spot cutter at 3,560' and - Fire cutter - Good indication -POH w/ cutter. -PJSM - L/D cutter (fired). 11:00 - 12:00 1.00 WHSUR P DECOMP R/D SLB lubricator, W.L & BOP and equipment. -Clear floor. 12:00 - 12:30 0.50 WHSUR P DECOMP R/U to circulate down tubing. 12:30 - 14:00 1.50 WHSUR P DECOMP Break circulation - Pump 37 bbls before returns are observed. -Circ hole clean w/ 3 bpm, 270 psi. -Observe well - Static 14:00 - 14:30 0.50 WHSUR P DECOMP DSM dry rod in TWC. 14:30 - 16:00 1.50 WHSUR P DECOMP R/U and test TWC from top. -Test w/ 3,500 psi f/ 30 minutes on chart. -Pump 13 bbls down annulus to fill. -Test TWC from below. -Pump for injection rate. -Pump @ 1.5 bpm / 1,000 psi f/ 30 minutes on chart. 16:00 - 18:30 2.50 WHSUR P DECOMP R/D circulating equipment. -FMC - terminated control lines. -N/D Tree and Adaptor flange. -Confirm threads in top of Tbg hanger (4 1/2" TDS). 18:30 - 00:00 5.50 WHSUR P DECOMP N/U BOP stack, Adaptor flange, Choke line & Riser. -R/U Turn buckles, Flow line, Hole fill line & Bleed off line. Total Seawater losses to hole for the day= 110 bbls. 1/14/2008 00:00 - 01:30 1.50 WHSUR P DECOMP N/U Choke hose & Flow line. 01:30 - 02:00 0.50 WHSUR P DECOMP R/U BOP test equipment. 02:00 - 07:00 5.00 BOPSUF P DECOMP Test BOPs: -Test pressures= 250 psi low & 3,500 psi high pressure. -Hold each test for 5 min. -Chart each test. -Test witnessed by WSL & Tourpusher. .-AOGCC witness Bob Noble on location. .Top Drive IBOP & Kill line HCR did not test. 07:00 - 07:30 0.50 BOPSUF P DECOMP R/D BOP test equipment. -Clear Rig Floor. 07:30 - 10:30 3.00 BOPSUP P DECOMP PJSM - C/O Top Drive IBOP & HCR Kill. -Sim Ops: Change IBOP on Rig Floor & Change HCR Kill in Cellar. 10:30 - 12:00 1.50 BOPSUF P DECOMP R/U test equipment. -Test TD IBOP & HCR Kill w/ 4 1/2" Test Joint. -250 psi low, 3500 psi high for 5 min each. Chart tests. -Good test. 12:00 - 13:00 1.00 BOPSUF P DECOMP R/D test equipment. -M/U Safety valve. -Blow Down Top Drive, Choke & Kill lines. -install Bails & Elevators. 13:00 - 16:00 3.00 WHSUR P DECOMP_ R/U DSM Lubricator. -C/O pup jt for Lub. extension. -Test @ 500 psi for 10 min. -Good test. -Pull TWC. -R/D Lubricator. 16:00 - 17:00 1.00 PULL P DECOMP WU 1 jt 4" DP & 2 XOs to Hanger & Top Drive. -Pull Tubing Hanger to Rig Floor. 17:00 - 18:30 1.50 PULL P DECOMP Pump 20 bbl Safe Surf-O & 20 bbl Safe Scav down tubing. Printed: 2/4/2008 11:21:23 AM 1 0 0 BP EXPLORATIONPage 3 of Operations Summary Report Legal Well Name: 02-31 Common Well Name: 02-31 Spud Date: 12/1/1991 Event Name: WORKOVER Start: 1/11/2008 End: 2/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 1/26/2008 Rig Name: DOYON 14 Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 1/14/2008 17:00 - 18:30 1.50 PULL P DECOMP -Circulate hole clean. 18:30 - 19:00 0.50 PULL P DECOMP PJSM - L/D 4 1/2" Tubing. -L/D XOs, 1 jt 4" DP & Tubing Hanger. -R/U Csg Tongs & Elevators. 19:00 - 00:00 5.00 PULL P DECOMP PJSM - Spooling Control Line. -R/U Schlumberger Control Line Spooler. -L/D 30 jts 4 1/2" 12.6# L-80 NSCT Tubing. -Noted 15-20K overpull on Jts 13 & 19. -50K overpull on Jt #31. -Indication of Control line "birds nest" w/ 11 bands recovered. -Work Jt #32 back down. -P/U Jt #31 & RIH keeping tension on Control Line. -Jt #31 hung up. Worked jt & Control Line. -Spool Control Line when slack available. -Total Seawater Losses for Today: 134 bbl. -Total Seawater Losses for Well: 244 bbl. 1/15/2008 00:00 - 02:00 2.00 PULL P DECOMP Continue working Jt #32. -Pulling Control Line w/ Super Tugger. -Second Control Line came free. -Spool up free Control Line. -Fill Hole w/ 34 bbls. 02:00 - 07:00 5.00 PULL P DECOMP L/D Jt #32. -Work Jt #33. -Hanging up w/ Control Line ("Bird's Nest") -Break circulation w/ 10 bpm 1380 psi - Work free spot (approx. 7') - Rotate w/ 30-100 rpm 3-5k torque -LD jt #33 07:00 - 10:00 3.00 PULL P DECOMP LD 20 jts dragging 20k-40k over -Joint # 54 & 55 large "nest" of control line and S.S. bands Remove "nest" from joints 10:00 - 11:00 1.00 PULL P DECOMP -LD SSSV - RD control line spool - LD same -Clear floor NOTE: recovered 35 SS bands out of 67 11:00 - 14:00 3.00 PULL P DECOMP Continue LD 4 1/2" tbg to cut -Recovered total 89 joints + cut it (5.55') - Jet cut OD 5.25" 14:00 - 15:30 1.50 PULL P DECOMP Clean tubing handling equipment and clear rig floor. Install roughneck track 15:30 - 18:00 2.50 FISH P DECOMP MU BHA w/ rope spear. When making up intensifier @+/- 217' pipe slacked off. POOH and check marks on stop sub. 18:00 - 21:30 3.50 FISH P DECOMP Finish MU BHA and RIH to 3,545', rotating pipe every 5 stands. Screw into top drive, check parameters. Rotate down to top of cut @ 3,568' and enter V w/ rope spear inside fish to 3,569'. UW1�. 107k / SOW: 107k 21:30 - 23:00 1.50 FISH P DECOMP POH f/ top of cut to BHA 23:00 - 00:00 1.00 FISH P DECOMP LD intensifier and rack back DCs. Pull rope spear. Rope spear brought 4 short pieces of control line, ran in f/ 2" to 12" in len D. Service break and LD rope spear and stop sub. MU RCJB. RIH DCs stands slowly due to flow back through pipe. 1/16/2008 00:00 - 02:30 2.50 FISH P DECOMP RIH w/ RCJB to 3,546'. Run slowly to prevent flow back through pipe. 02:30 - 03:30 1.00 FISH P DECOMP Screw into top drive. Break circulation 8 bpm @ 825 psi. Run down without rotation tagging at 3,567'. PU and drop ball. Establish circulation 6.5 bpm @ 1,240 psi and rotation @ 60 Printed: 2/4/2008 11:21:23 AM • • Legal Well Name: 02-31 Common Well Name: 02-31 Spud Date: 12/1/1991 Event Name: WORKOVER Start: 1/11/2008 End: 2/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 1/26/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/16/2008 02:30 - 03:30 1.00 FISH P DECOMP RPM. Wash down to 3,568' and tagged lightly on top of fish. Work on top of fish with circulation and rotation. PUW: 100k / SOW: 100k / ROTW: 105k - Torque 3-5k 03:30 - 05:30 2.00 FISH P DECOMP Blow down top drive. POOH w/ RCJB. 05:30 - 07:00 1.50 FISH P DECOMP Stand back DC's - Clean RCJB - LD same -Recovered several piece§ of control line and S.S. banding 07:00 - 07:30 0.50 FISH P DECOMP MU Dressoff BHA 07:30 - 09:00 1.50 FISH P DECOMP Clear / Clean floor -Service blocks, Top Drive, Crown -Install wear ring 09:00 - 10:30 1.50 FISH P DECOMP RIH to 3,550' 10:30 - 11:30 1.00 FISH P DECOMP Screw in T.D. - Obtain parameters - PUW 106k - SOW 106k - ROTW -Break circ. w/ 8 bpm 850 psi -Rotate w/ 60 rpm 1-2k tq -Tag T.O. F. at 3,568' - Dress off top w/ 2-3k wt and rotate down -Tag T.O.F. w/ internal mill - Rotate on top to open ID -Work over top several times 11:30 - 13:30 2.00 FISH P DECOMP Monitor well - POH 13:30 - 14:00 0.50 FISH P DECOMP LD acc. jar - Stand back DC's - LD dressoff assembly 14:00 - 15:00 1.00 FISH P DECOMP Mobilize BHA to Rig floor -MU 5 7/8" overshot w/ 4 1/2" basket grapple and MCP 15:00 - 16:30 1.50 FISH P DECOMP RIH to 3,546' 16:30 - 17:00 0.50 FISH P DECOMP Screw in T.D. - Obtain parameters - PUW 106K, SOW 106K, ROTW 106k w/ 1-2k tq -Wash down w/ 4.8 bpm 240 psi -Engage fish at 3,568' - Observe press. increase - Stop pumps -Swallow 6' and bottom out - PU 15k over and bleed jars -PU to 10k over -Set torque limit to 5k - Turn left 1 turn, 1/4 turn back - Turn left 1 turn, got 1 turn back -Turn 5 more turns left w/ 5k overpull- Rotary stalled at 5k - Increase torque to 6k and weight fell off -PU w/ no overpull - Slack off and tag at same spot - PU w/ no overpull 17:00 - 18:30 1.50 FISH P DECOMP Blow down T.D. - POH f/ 3,568' to BHA 18:30 - 20:30 2.00 FISH P DECOMP LD intensifier - Rack back 2 stands DCs - Pull overshot to floor. Recover 28.13' of collapsed 4-1/2" tubing it f/ cut off to collapse section. Joint twisted and broke on collapsed section when attempting backoff - Remove fish f/ overshot - LD overshot and pump out sub. 20:30 - 22:00 1.50 FISH P DECOMP Mobilize next BHA to rig floor - MU Flat Bottom Mill, 2 junk baskets, stabilizer, Bumper sub, jars and DCs. 22:00 - 23:00 1.00 FISH P DECOMP RIH on 4" DP to +/- 1,200' 23:00 - 00:00 1.00 FISH P DECOMP Slip and cut drilling line. Service top drive 1/17/2008 00:00 - 00:30 0.50 FISH P DECOMP Finish servicing top drive 00:30 - 01:30 1.00 FISH P DECOMP Cont. RIH w/ milling BHA on 4" DP f/ 1,200' to 3,539' 01:30 - 05:30 4.00 FISH P DECOMP Screw into top drive - Obtain parameters PUW: 100k / SOW: 100k / ROTW: 103k. Establish circulation @ 8 bpm / 850 psi - Wash down and tag top of fish @ 3,598'. Begin milling @ 120 rpm / 1 k torque. Increase rot. to 130 rpm / 2-4k torque. WOB 7k. Mill 13' to 3,611'. Printed: 2/4/2008 11:21:23 AM 4J t '.. L/"I :L V I ITl I I t i Operations summary Legal Well Name: 02-31 Common Well Name: 02-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 1 1 1 1 1 1/17/2008 05:30 - 06:00 0.50 FISH P 06:00 - 07:00 1.00 FISH P 07:00 - 08:00 1.00 FISH P 08:00 - 09:00 1.00 FISH P 09:00 - 13:30 4.50 FISH P 13:30 - 18:00 4.50 FISH P 18:00 - 21:00 3.00 FISH P 21:00 - 22:00 1.00 FISH P 22:00 - 23:00 1.00 FISH P 23:00 - 00:00 1.00 FISH P 1/18/2008 00:00 - 01:00 1.00 FISH P 01:00 - 02:00 1.00 FISH P 02:00 - 03:00 1.00 FISH P 03:00 - 03:30 0.50 FISH P 03:30 - 04:30 1.00 FISH P 04:30 - 06:30 2.00 FISH P 06:30 - 17:00 1 10.501 FISH I P 17:00 - 19:00 2.00 FISH P 19:00 - 00:00 5.00 FISH P 1/19/2008 00:00 02:00 2.00 FISH P Start: 1 /11 /2008 Rig Release: 1 /26/2008 Rig Number: PT I F DECOMP Circulate Hi-vis sweep surface -surface 8 bpm / 725 psi. Blow down top drive. Observe well. DECOMP POOH to BHA DECOMP Stand back DCs. LD junk mill, junk baskets and stabilizer DECOMP ND riser, flow line and bell nipple. NU shooting flange DECOMP Service rig while waiting on slick line unit DECOMP PJSM - RU slick line and pressure control: lubricator extension - pump in sub - SL BOP - lubricator. Test to 500 psi x 5 min on chart. DECOMP RIH w/ 3.65" gauge on slick line to 3,609' SLM (top of fish).. Attempt to enter stump several times without success. POOH and change configuration: add 2 centralizers and locate a 3.5" gauge on bottom, a 3.65" gauge in the middle and a 3.2" gauge on top. DECOMP RIH w/ new gauge assy. on slick line and tag @ 3,609' SLM (top of fish). Attempt to enter stump without success. POOH DECOMP RD slick line and pressure control. ND shooting flange. NU riser, bell nipple and flow line. DECOMP MU dress off BHA DECOMP RIH w/ dress off BHA on 4" DP to 3,540' DECOMP Screw into top drive. Obtain parameters PUW: 100k / SOW: 100k. Run down and tag fish @ 3,611'. Establish circulation 8 bpm / 800 psi. Rotate down and swallow 11' w/ washpipe extension. Dress off top of fish with dress off mill, working several times. DECOMP Blow down top drive. Check well. POOH to BHA. DECOMP Stand back DCs. LID dress off assy. DECOMP ND flow line, riser and bell nipple. NU shooting flange DECOMP RU slick line and pressure control: lubricator extension, pump in sub, SL BOP and lubricator. Test to 500 psi x 5 min on chart DECOMP Make the following runs on slick line: 1.- 3.2" top cent. + 3.625" middle cent. + 3.5" bottom cent. Run to 3,605'SLM (top of fish) and attempt to enter fish without sucess. 2.- 2.7" top cent. + 2.7" bottom swedge. Run to 3,605' SLM and attempt to enter fish without success. 3.- 4.5" top cent. + 5.85" bottom LIB. LIB hung up @ 617' & 739'. Could not get passed 994' SLM 4.- 2.7" swedge w/ bullnose. Enter fish and run to 8,316' SLM (top of packer) 5.- 3.25" top cent. + 3.625" middle cent. + 2.80" bottom cent. w/ bull nose. Work points at 3,605' and 3,636'. Cont. running inside fish to 8,316' SLM 6.- 3.5 top cen . + . swedge. Work points at 3,612' and 3,636'. Cont. running inside fish to 3,801' SLM (top of GLM). Could not net passed from 3 801' 7.- 3.25" top cent. + 3.625" bottom cent. Work at top of fish and cont. running to 3,650' SLM. POOH DECOMP RD slick line and pressure control DECOMP RU Schlumberger a -line and pressure control to run chemical cutter. DECOMP Finish RU Schlumberger a -line and pressure control. Test to 500 psi x 5 min on chart. PU tbg. punch w/ 2 1/8" rollers Spud Date: 12/1/1991 End: 2/26/2008 Printed: 2/4/2008 11:21:23 AM 1 0 0 Legal Well Name: 02-31 Common Well Name: 02-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From -To Hours Task Code NPT 1/19/2008 02:00 - 19:00 17.00 FISH P 19:00 - 20:00 1.00 FISH P 20:00 - 20:30 0.50 FISH P 20:30 - 23:30 3.00 FISH P 23:30 - 00:00 0.50 FISH P 1/20/2008 00:00 - 02:00 2.00 FISH P 02:00 - 03:00 1.00 FISH P 03:00 - 04:30 1.50 FISH P 04:30 - 06:30 2.00 FISH P 06:30 - 08:30 2.00 FISH P Spud Date: 12/1/1991 Start: 1 /11 /2008 End: 2/26/2008 Rig Release: 1/26/2008 Rig Number: Phase Description of Operations DECOMP Make following runs on a -line 1.- RIH w/ tbg punch on a -line to 3,608' WLM (top of fish). Attemi)t to enter several times without success. POOH. Add 2 knuckle joints and 6 arm centralizer. RIH and enter fish. Cont. running to 8,300' WLM. Position tool and fire tubing punch 8 258'-8 260' WLM. POOH. 2.- RIH w/ string shot. Enter fish and work through top of upper GLM. Cont. running to 8,300' WLM. Position tool and fire string shot 8 272'-8 284' WLM. POOH. 3.- Run chemical cutter down fish and make cut @ 8,282' WLM. After making cut tool got trapped. Work and got tool free. POOH. Check tool, no missing parts. Severing head with marks indicating it got pinched with pipe after cutting. DECOMP RD Schlumberger a -line and pressure control DECOMP ND shooting flange. NU bell nipple, riser and flow line DECOMP MU fishing BHA w/ overshot DECOMP RIH w/ fishing BHA on 4" DP DECOMP RIH w/ fishing BHA on 4" DP to 3,542' DECOMP Screw into top drive. Check parameters PUW: 105k / SOW: 105k. Establish circulation 190 GPM / 200 psi. Run down and tag fish @ 3,612. Engage fish, pump pressure increases to 550 psi. Pull fish free w/ 175k (70k over PUW before engaging fish . PU 10'. Attempt to circulate, pipe pack off. PU 25' w/ max PUW 220k. Work pipe down free and establish circulation slowly @ 200 gpm / 1,000 psi DECOMP Circulate surface - su7ra_c_e7Ml Safe Surf 0 pill & 40 bbl Safe Scav pill through cut, 200 gpm / 1,000 psi DECOMP POOH w/ fish from cut. Pull tight. Pump while pulling 160 gpm / 200 psi DECOMP Work tight spot (end of fish @ +/- 6,900'). Pulled free @ 300k. CBU @ 420 gpm / 750 psi 08:30 - 10:30 2.00 FISH P DECOMP Cont. POOH w/ fish to BHA 10:30 - 11:00 0.50 FISH P DECOMP Stand back DCs. LD intensifier, bumper sub, jars and overshot w/ upper cut jt. 11:00 - 17:00 6.00 PULL P DECOMP LD 4-1/2" tubing and completion equipment. Total LD: 116 jts + 3 GLM assy + top cut jt (33.3') + bottom cut jt (19.04'). Out (chemical) shows two cuts along pipe opposite each other w/ lengths 4.5" and 5". One half of pipe is flared open to 5.5"-6". Other half is slightly rolled to inside. Deformation goes for about 0.5' along pipe from cut. Upper and middle GLM with marks of metal to metal drag. 17:00 - 18:00 1.00 PULL P DECOMP Clear tubing equipment off rig floor. Conduct derrick inspection. Remove overshot from top cut jt. 18:00 - 21:00 3.00 WHSUR P DECOMP Pull wear ring. Run out LDS. Attempt to pull packoff through BOP stack. Pull to 60K, slack off and repeat. Packoff moves 6" and locks. RILDS. Install wear ring 21:00 - 22:00 1.00 FISH P DECOMP MU BHA w/ 6-1/8" flat bottom mill + boot baskets + 6-1/8" stabilizer to condition top of stump @ +/- 8,282' WLM 22:00 - 00:00 2.00 FISH P DECOMP RIH w/ milling BHA on 4" DP 1 x 1 f/ pipe shed to +/- 2,000' 1/21/2008 00:00 - 07:00 7.00 FISH P DECOMP Cont. RIH w/ milling BHA on 4" DP 1 x 1 f/ pipe shed to 4,687'. RIH on 4" DP stands f/ derrick to 8194'. Rotate through tight spots @ 5,021' - 5,148' - 5,275' - 6,141' - 6,278'. Rot 60 RPM, 210 gpm - 300 psi Printed: 2/4/2008 11:21:23 AM 1 0 0 BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: 02-31 Common Well Name: 02-31 Spud Date: 12/1/1991 Event Name: WORKOVER Start: 1/11/2008 End: 2/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 1/26/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/21/2008 07:00 - 08:30 1.50 FISH P DECOMP Screw into top drive. Obtain parameters. Washdownand -tao top of stump @ 8,290'. Mill stump f/ 8,2 to 8,292'. 08:30 - 09:30 1.00 FISH P DECOMP Pump Hi-vis sweep and circulate surface - surface, 336 gpm 1,400 psi 09:30 - 14:00 4.50 FISH P DECOMP POOH f/ 8,292'to BHA. Pull tight @ 6,280'(50k over string weight - 200k total pull) 14:00 - 14:30 0.50 FISH P DECOMP Stand back DCs. ILD milling assy. Clean boot baskets. Clear rig floor. 14:30 - 15:00 0.50 BOPSUF P DECOMP Pull wear ring. RU to test BOP. 15:00 - 18:30 3.50 BOPSUF P DECOMP Test BOP and related equipment as per BP / AOGCC procedures and regulations. Test all components to 250 psi low - 3,500 psi high x 5 min each test on chart. Test to 4" and 4-1/2" (top rams) test joints. Perform koomey test. Test witnessed by WSL and Toolpusher. Chuck Scheve, AOGCC rep, waived witness of test. 18:30 - 19:00 0.50 BOPSUF P DECOMP RD testing equipment. Install wear ring. 19:00 - 20:00 1.00 EVAL P DECOMP ND flow line, riser and bell nipple. NU shooting flange 20:00 - 22:00 2.00 EVAL P DECOMP Service rig while waiting on slick line unit (finishing job in Point McIntyre) 22:00 - 00:00 2.00 EVAL P DECOMP RU slick line and pressure control. 1/22/2008 00:00 - 01:00 1.00 EVAL P DECOMP Cont. RU slick line pressure control. Test to 500 psi x 5 min on chart 01:00 - 05:30 4.50 EVAL P DECOMP RIH w�/ memory caliper on slick line to 8,293'SLM to of stump). POOH taking memory caliper in 7" casing f/ to of stump to surface 05:30 - 06:30 1.00 EVAL P DECOMP RD slick line and pressure control 06:30 - 07:00 0.50 EVAL P DECOMP ND shooting flange. NU bell nipple, pitcher nipple and flow line 07:00 - 08:00 1.00 FISH P DECOMP Mob. BHA tools to rig floor. MU dress off BHA w/ string mill 08:00 - 15:00 7.00 FISH P DECOMP RIH w/ dress off BHA on 4" DP to 8,270'. Rotate through tight spots @ 5,020'- 5,148'- 5,275'- 6,141'- 6,278'. 15:00 - 15:30 0.50 FISH P DECOMP Screw into top drive. Obtain parameters PUW: 168k - SOW: 150k - ROTW: 160k. Wash down and tag top of stump @ 8,292'. Dress off stump, swallowing stump in wash pipe — extension to 8,303'(boftom of dress off shoe). Polish top of stump. 340 gpm / 1,440 - 1,600 psi. 60 RM/ 3k torque. 15:30 - 18:00 2.50 FISH P DECOMP Circulate 40 bbl hi-vis sweep surface - surface 340 gpm / 1,460 psi. Reverse circulate 2nd. 40 bbl hi-vis sweep surface - surface 325 gpm / 1,400 psi 18:00 - 19:30 1.50 FISH P DECOMP Slip and cut drilling line 19:30 - 23:00 3.50 FISH P DECOMP POOH f/ 8,292' to BHA. Max. overpull recorded: 8k over string weight in 6,221' - 6,125' interval. 23:00 - 00:00 1.00 FISH P DECOMP LD BHA 1123/2008 00:00 - 00:30 0.50 FISH P DECOMP Finish LID BHA 00:30 - 01:00 0.50 FISH P DECOMP Clear rig floor of dress off tools. Mobilize RBP. 01:00 - 02:30 1.50 DH13 P DECOMP MU RBP. RIH on 4" DP to 1,500' 02:30 - 07:30 5.00 DH13 N WAIT DECOMP Safety stand down due to high winds and blowing snow. Situation not sate or derrick man. in tends to entangle service loops w/ kelly hose when moving blocks. Visibility in pad very poor. Wind speed 40 mph gusting to 62 mph. NOTE: field in Phase 2 07:30 - 21:00 13.50 DHB N WAIT DECOMP Cont. shut down waiting on weather NOTE: field in Phase 3 21:00 - 00:00 3.00 DH13 N WAIT DECOMP Cont. shut down waiting on weather Printed: 2/412008 11:21:23 AM 1 0 0 Legal Well Name: 02-31 Common Well Name: 02-31 Spud Date: 12/1/1991 Event Name: WORKOVER Start: 1/11/2008 End: 2/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 1/26/2008 Rig Name: DOYON 14 Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 1/23/2008 21:00 - 00:00 3.00 DHB N WAIT DECOMP NOTE: field in Phase 2, and Level 3 on all roads 1/24/2008 00:00 - 04:30 4.50 DHB P DECOMP Weather clear. Resume operations. Cont. RIH w/ RBP on 4" DP to 8,174' Note: field in Phase 2 (main roads) at the moment of resuming operations. Wind slowed down to 16 mph. Good visibility. Loader conditioned pad. 04:30 - 05:30 1.00 DHB P DECOMP Screw into top drive and obtain parameters PUW: 162k - SOW: 150k Run down and set RBP: Top of RBP @ 8,254' - COE 05:30 - 07:00 1.50 DHB P DECOMP RU to test casing and RBP. Test 7" casing and RBP to 3,500 psi x 30 min on chart. RD testing equipment. Blow down lines. 07:00 - 09:30 2.50 DHB P DECOMP POOH f/ 8,174'to 1,820' 09:30 - 10:30 1.00 DHB P DECOMP Mob. RTTS. Break one stand. MU RTTS. RIH and set RTTS 99'. Release and rack stand back 10:30 - 12:00 1.50 DHB P DECOMP RU to test RTTS. Pressure up to 3,500 psi. Pressure bled to 3,000 psi in 25 min and stabilized. Hold 3,000 psi x 30 min. Chart test. RD testing equipment. 12:00 - 13:30 1.50 BOPSUP P DECOMP Blow down lines. Suck out stack. ND BOP 13:30 - 16:00 2.50 WHSUR P DECOMP C/O packoff. Test same to 3,500 psi x 15 min as per FMC NU BOP 16:00 - 17:30 1.50 BOPSUF P DECOMP 17:30 - 18:30 1.00 BOPSUF P DECOMP RU testing equipment. Test BOP breaks to 250 psi low - 3,500 psi high x 5 min each on chart. RD testing equipment. Blow down choke and kill lines. Install wear ring. 18:30 - 19:30 1.00 DHB P DECOMP MU running tool. RIH one stand and screw into RTTS. Retrieve RTTS. Pull to surface and LD 19:30 - 22:30 3.00 DHB P DECOMP RIH to top of RBP @ 8,254' 22:30 - 23:00 0.50 DHB P DECOMP Latch and retrieve RBP. Check well. 23:00 - 00:00 1.00 DHB P DECOMP POOH and LD 4" DP 1 x 1 f/ 8,254' to 7,300' 1/25/2008 00:00 - 06:00 6.00 DHB P DECOMP Cont. POOH and LD 4" DP 1 x 1 f/ 7,300' to surface 06:00 - 07:00 1.00 DHB P DECOMP LD RBP. Clear rig floor. Pull wear ring. 07:00 - 09:00 2.00 RUNCO P RUNCMP RU to run tubing and completion: C/O bales and elevators, install torque turn equipment and compensator. 09:00 - 11:00 2.00 RUNCO P RUNCMP MU and RIH 4-1/2" 12.6# 13Cr Vam Top tubing w/ completion equipment. Torque turn all connections. Bakerlok all connections below packer (tail pipe assy). Total jts run: 193. PUW: 143k / SOW: 133k 11:00 - 00:00 13.00 RUNCO P RUNCMP Rundown and swallow stump w/ overshot. Slack off 1st row of shear pins @ 8,297' (bottom of overshot). Slack off 2nd row of shear pins @ 8,305' (bottom of overshot). Tag No -Go and slack off 15k @ 8,307' bottom of overshot ; top of stump @ 8 292' . Space out. PU and MU tubing hanger. 1/26/2008 00:00 - 01:00 1.00 RUNCO P RUNCMP Land completion on tubing hanger. RILDS Bottom of overshot @ 8,300' - Packer @ 8,199' - GLM #1 Q 5,507' - GLM #2 @ 3,509' - X-Nipple @ 2,101' NOTE: Elevation DOYON-14 to ULDS: 31.70' 01:00 - 04:00 3.00 RUNCO P RUNCMP RU to reverse circulate. Reverse circulate clean seawater w/ corrosion inhibitor, 3 bpm / 760 psi. 04:00 - 06:30 2.50 RUNCO P RUNCMP Drop ball -and -rod to set packer. Pressure up tubing to 3,500 psi. Hold pressure x 30 min. Pressure drops 25 psi in 15 min and a total of 50 psi in 30 min. MIT-T OK. Chart test. Bleed pressure in tubing to 1,500 psi. Pressure up IA to 3,500 psi and hold x 30 min on chart (no pressure drop). MIT -IA OK. Printed: 2/4/2008 11:21:23 AM BP EXPLORATION; Page 9 of 9 Operations Summary Report Legal Well Name: 02-31 Common Well Name: 02-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 1 /26/2008 04:00 - 06:30 1 2.50 06:30 - 09:00 1 2.501 WHSUR I P 09:00 - 11:00 1 2.00 BOPSU P 11:00 - 12:30 1.50 WHSUR P 12:30 - 14:00 1.50 WHSUR P 14:00 15:00 1.00 WHSUR P 15:00 - 16:30 1.501 WHSUR I P 16:30 - 17:30 1.00 1 WHSUR I P 17:30 - 19:00 1 1.501 WHSUR I P 19:00 - 22:00 1 3.001 WHSUR I P Spud Date: 12/1 /1991 Start: 1 /11 /2008 End: 2/26/2008 Rig Release: 1/26/2008 Rig Number: Phase Description of Operations RUNCMP Bleed pressure in tubing and observe DCK-2 valve shear. Bleed off all pressure. Pump down IA through DCK-2 valve 2 bpm / 900 psi. RD testing equipment. LD landing joint RUNCMP Dry rod TWC. Test f/ below to 1,000 psi x 30 min on chart. Test f/ top to 3,500 psi x 5 min on chart. RUNCMP Blow down lines. Suck out stack. ND BOP and choke line RUNCMP NU adapter flange and test to 5,000 psi x 30 min as per FMC RUNCMP NU production tree and test w/ diesel to 5,000 psi x 5 min RUNCMP RU Little Red to pump down IA taking returns out tubing for freeze protect. RUNCMP RU DSM lubricator. Test to 500 psi. Pull TWC. RD lubricator RUNCMP Test lines to 3,500 psi. Little Red pumps 90 bbls diesel for freeze protect down IA taking returns out tubing, 2 bpm / 1,050-1,300 psi. RUNCMP Jump IA to tubing and let freeze protect U-tube. RUNCMP RU lubricator. Install BPV. RD lubricator. Test BPV f/ below to 1,000 psi x 5min. Suck diesel out of all lines. RD Little Red. Secure tree. TBG=0psi/ IA=Opsi/OA=Opsi Release rig @ 22:00 1-26-2008 Printed: 2/4/2008 11:21:23 AM 02-31A (PTD #1990150)R EVALUATION for sustained casi ressure - TxIA c... Page 1 of Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer[NSUADWWellintegrityEngineer@BP.com] Sent: Friday, July 27, 2007 9:04 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T. Subject: 02-31A (PTD #1990150) UNDER EVALUATION for sustained casing pressure - TAA communication Attachments: 02-31 A. pdf All, Well 02-31A (PTD #1990150) has been found to have sustained casing pressure on the IA. The wellhead pressures were 2420/2130/20 psi on 07/25/07. A subsequent TIFL failed on 07/26/07. The well has been classified as Under Evaluation and may be produced under a 28-day clock. Due to the high shut-in pressure (2430 psi) on this well, it will be put back on-line to restrict the IAP to the FTP around 1200 psi. The plan forward for this well is as follows: 1. D: TIFL - FAILED 2. F: MITIA to 3000 psi, LLR if fails 3. WIE: Eval for LDL and secure A wellbore schematic has been included for reference. <<02-31A.pdf>> Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 bt-ANNED JUL 3 12007 7/30/2007 02-31A (PTD# 1990150) UNDER EVALUATION for sustained casin... Subject: 02-31A (PTD# 1990150) UNDER EVALUATION for sustained casing pressure - TxIA Communication From: "Austin, Paul A" <Paul.A.Austin@bp.com> Date: Sat, 16 Jun 2007 10:30:20 -0800 To: "GPB, FS1 DS Ops Lead" <GPBFS1DSOpsLead@BP.com>, "GPB, FS1 OTL" <GPBFS I OTL@BP.com>, "GPB, Area Mgr East (FSI/2/COTU/Seawater)" <GPBAreaMgrEastFS12CS@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "Engel, Harry R" <Harry.Engel@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "GPB, EOC Specialists" <GPBEOCSpecialists@BP.com>, James Regg <jim regg@admin.state.ak.us>, tom_maunder@admin.state.ak.us, Robert Fleckenstein <bob_fleckenstein@admin.state.ak.us>, "NSU, ADW WL & Completion Supervisor" <NSUADW WL&CompletionSupervisor@BP.com> CC: "NSU, ADW Well Integrity Engineer"<NSUADWWelllntegrityEngineer@BP.com>, "Holt, Ryan P (ASRC)" <Ryan.Holt@BP.com>, "Roschinger, Torin T." <Torin.Roschinger@BP.com>, "Dean, James A" <James.Dean@BP.com> All, Well 02-31A (PTD # 1990150) has been found to have sustained casing pressure on the IA. The wellhead pressures were observed at 1053/2400/10 on 06/12/07. On 06/14/07 the well failed a TIFL. The well has been classified as Under Evaluation and may be produced under a 28-day clock. The plan forward is: 1. D: TIFL - FAILED 2. F: MIT -IA to 3000 psi, LLR if fails A Wellbore schematic has been included for reference. <<02-31A.pdf>> Please call with any questions or concerns. Thank you, Paul Austin for Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-6100 x1154 ,5CANNF.D JUN 18 2007 Content -Description: 02-31 A.pdf 02-31A.pdf Content -Type: application/octet-stream Content -Encoding: base64 1 of 1 6/18/2007 9:05 AM TREE= FMC WELLHEAD= FMC ACTUATO = BAKER C KB. ELEV = 68' BF. ELEV = KOP = 5900, Max Angle = 97 @ 11007' Datum MID = 9331' Datum TV D = 88001SS 9-5/8" CSG36#1 J-55, ID = 8.921 • Minimum ID = 2.38" CROSSOVER AT TOP OF 2-7/8" LINER TOP OF 2-7/8" LNR, ID = 2.441 " 1--1 8328' 0 7" CSG, 26#, L-80, ID = 6.276" 1--1 8748- 14-1/2"TBG,12.6#,L-80,.0152bpf,ID=3.958" I 5"LNR, 15#,13-CIR-0188b�,ID=4.�408" -j 9074' --4 TOP OF WHIPSTOCK -966w coin PERFORATION SUMMARY REF LOG: CNL ON 04/18/99 ANGLE AT TOP PERF: 83 @ 9600' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 960 - 0 - - ... 9740 0 05102199 2" 4 10450 - 11000 0 04/19/99 ..gob., Aft Sw NOTES: HORIZONTAL WELL - 70' @ 9455'AND 90-@9624' "SLIMHOLEGLMSID= 3.65" *5-1/2" CHROME LNR* --2202' E4-LVL2CAM BALD SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MID TVD DEV TYPE VLV LATCH PORT DATE 1 3801 3798 1 KBG2LS DMY BK 0 2 6415 6391 21 KBG2LS *DMY BK 0 06/12/06 3 8246179941 29 . KBG2LS DMY BK 0 07/29/05 "t:A I tT4Ut=U HAUKINU ------- I — 8311 -� 7" X 4-1/2' S-3 PKR 3.60" BAKER DEPLOYMENT SLV, ID = 3.00" 8325------3.60--X 2-718" XO, ID = 2.38- 84ir -F4 1 ----] -1; c 2 - - Am DB 6 Nip ID = 3.635" F—w--y--j—rELMD TT LOGGED 07/10/98 IMILLOUT WINDOW 9074'- 9080' If �TD -L_111 14' j 2-7/8" LNR, 6.5#, L-80, ,00579 bpf, ID = 2,441" 1-4 11150- DATE REV BY COMMENTS DATE REV BY COMMENTS r72,911 ORIGINAL COMPLETION 07131/05 JPKITLH GLV C/O &SAFETY NOTE 04/19/99 SIDETRACK 06/12/06 KSB/PJC GLV C/O 02/02102 RN/TP CORRECTIONS 08/17/03 CMO/TLP PERF ANGLE CORRECTION 108/24/03, ATDIKK 2-7/8" LNR ID CORRECTION 12/22/03 JBM/TLP 1 MIN ID, LNR TOP, DEPLOY SLV TD H 11215' PRUDHOE BAY UNIT WELL: 02-31 A PERMIT No: F1 990150 A P1 No: 50-029-22227-01 SEC 36, T1 I N, RI 4E, 3527.91' FEL & 4645.95- FNL BP Exploration (Alaska) UL-.S I A (r 1 U ff l YYV 1 JV) k-LUSJ111Cu aN ri uu1c111 w cu e �' ■ _ _�_ nn A /Ti rT1 _ui nnni rnx TIT-11 7,?"e ! �4 ( From: "NSU, ADW Well Integrity Engineer"<NSUADWWellintegrityEngineer@BP.com> Date: Thu, 08 Jun 2006 21:27:00 -0800 To: "Dean, James A" <James.Dean@BP.com>, "GPB, FS 1 /SIP/STP Area Mgr" <GPBFS 1 TL@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "NSU, ADW Well Operations Supervisor"<NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)" <jim_regg@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)"<wnton_aubert@admin.state.ak.us>, "NSU, ADW WL & Completion Supervisor"<NSUADWWL&CompletionSuperyisor@BP.com>, "GPB, FS 1 DS Ops Lead" <GPBFS 1 DSOpsLead@BP.com> CC: "NSU, ADW Well Integrity Engineer"<NSUADWWelllntegrityEngineer@BP.com>, "Winslow, Jack L." <Lyonsw@BP.com> A ( All, Well 02-31A (PTD #1990150) has the potential to have sustained casing pressure on the IA due to a loss of tubing integrity. The TIO's on 06/06/06 were 2350/260/30 after a TIFL failed. The IA pressure is expected to equalize with the SI tubing pressure. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: DGLV GLM #1 & 2 w/extended packing 3. FB: MITIA to 3000 psi SCANNED JUN 2 7 2006 A wellbore schematic has been included for reference. <<02-31 A. pdf>> The well has been classified as a Problem well. Please call if you have any questions. Thank you, Anna Du6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content -Description: 02-31 A.pdf 02-31A.pdf Content -Type: application/octet-stream Content -Encoding: base64 1 of 1 6/9/2006 10:21 AM TREE = FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 68' KOP = 5900, Max Angle = 97 @ 11007' Datum MD = 9331' Datum TV = 8800' SS 9-5/8" CSG, 36#, J-55, ID = 8.921" i— 3515' (- Minimum ID = 2.38" @ 8326' CROSSOVER AT TOP OF 2-7/8" LINER F. SA` 'NOTES: HOMZOt TAL WELL - 701 @ 9455 AND 90- @ 9624' `SLIMHOLE CLMS ID = 3.65" 2202'--�4-1/2" CAM BALO SSSV NIP; €D = 3.813" W&V RIZAi sjT_>f�1f� 7�T`i. ST MD TVD DE1/ TYPE VLV LATCH:PORT DATE1 3801 3798 1 KBG2LS DMY BK2 6415 6391 21 KBG2LS DMY BK3 8246 7994 29 KBG2LS Dr;1Y BK 07129/05 831 V I-17" X 4-1/2" S-3 PKR 8322' — 3.60" BAKER DEPLOY iv'T SLV . ID = 3.00" TOP OF 2-7/8" LNR, ID = 2.441" 8328' 8325 3.60" X 2-7/8" XO, ID = 2.38" 8417' 4-112" CAM DB-6 NIP, ID = 3.635" TOP OF 5" LNR 1-1 8454' 7" CSG, 26#, L-80. 1D = 6.276" H 8748' 1 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1--1 8439' 5" LNR, 15#, 13-CR, .0188 bpf, ID = 4.408" I 9074' TOP OF WHIPSTOCK 9068' TOP OF CEMENT 1-1 9134' PERFORATION SUMMARY REF LOG: CNL ON 04/18/99 ANGLE AT TOP PERF: 83 @ 9600' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9600 - 9740 O 09/02/99 2" 4 10450 - 11000 O 04/19199 _8439'—j4-1/2" WLEG 8453' ELMD TT LOGGED 07110/98 MILLOUT WINDOW 9074' - 9080, PBTD — 11114' 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" 11150' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/91 ORIGINAL COMPLETION 07/31/05 JPKITLH GLV C/O & SAFETY NOTE 04/19/99 SIDETRACK 02/02/02 RN/TP CORRECTIONS 08/17/03 1 CMO/TLPj PERF ANGLE CORRECTION 08/24/03 ATD/KK 2-7/8" LNR ID CORRECTION 12/22/03 1 JBMrrLP_l MIN ID, LNR TOP, DEPLOY SLV TD 1121 �` PRUDHOE BAY UNIT WELL: 02-31 A PERMIT No: 1990150 API No: 50-029-22227-01 SEC 36, T11 N, R14E, 3527.91' FR & 4645.95' FNL BP Exploration (Alaska) 199-015-0 PRUDHOE BAY UNIT 02-31A 50- 029-22227-01 BP EXPLORATION (ALASKA) INC Roll #1: Start: Stop Roll #2: Start Stop MD 11215 _'TVD 08946 —Completion e: 5/20/99 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D C 9216 1 SCHLUM MCNL CH 5/25/99 6/10/99 C 9343 % 1 SCHLUM MEM GR/CCL CH 10/6/99 10/13/99 C 9728 1 SCHLUM MCNL CH 9/14/00 9/26/00 D 9054 2-10 SPERRY GR OH 9/5/99 10/19/99 D 9055 ' 2-6 SPERRY GR PB 1 OH 9/5/99 10/19/99 L DGR/NGP-MD /.-- AL 9070-11220 OH 10/21/99 10/28/99 L DGR/NGP-MD 1- NAL 9070-9316 PB 1 OH 10/21/99 10/28/99 L DGR/NGP-TVD (/FINAL 8636-8846 PB1 OH 10/21/99 10/28/99 L DGR/NGP-TVD / PN�AL 8636-8879 taINAL OH 10/21/99 10/28/99 L MCNL 8070-11020 4/18/99 CH 2 5/25/99 6/10/99 C L MCNL €Ff1;TAL 8240-9605 CH 2 9/14/00 9/26/00 C L MEM TIE IN/GR AL 8000-10000 8/28/99 CH 5 9/16/99 9/22/99 R SRVY RPT CKrERRY 9000-11220. OH 4/22/99 4/27/99 R SRVY RPT BERRY 9000-9316. PBl OH 4/22/99 4/27/99 Tuesday, May 01, 2001 Page 1 of 1 Iqg-0113' 19V - 103 ) g1.084{ ,100 •01 'f 1 j 4 •OSo Sebtunbergr Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job # NO. 514 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Log Description Date BL Sepia CD MCNL (PDC, oil ■O K1:k.1:1VCV SIGNED: DATE: S EP 2,16 2000 s� ,a Oil & Gas Cons.Com"l010-n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thantrage MAYMN Sperry -sun DRILLING SERVICES WELL LOG TRANSMITTAL To: State of Alaska October 21. 1999 Alaska OR and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs D. S. 2-31 A & 2-31 A PB 1, AK-MW-90105 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Jim Galvin, Sperry -Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 2-31A: 2" x 5" MD Gamma Ray Logs: 50-029-22227-01 2" x 5" TVD Gamma Ray Logs: 50-029-22227-01 DS 2-31A PB1: 2" x 5" MD Gamma Ray Logs: 50-029-22227-70 2" x 5" TVD Gamma Ray Logs: 50-029-22227-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia VI=r! i � 8 19' Gas Cons. OMMi -O t AnM,0 e 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 273-3500 • Fax (907) 273-3535 A Halliburten Cmmnanv Sperry -sun DRILLING SERVICES WELL LOG TRANSM ]PTAL To: State of Alaska September 5, 1999 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. ` Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - D. S. 2-31 A PB 1, AK-MW-90105 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of Tim Galvin, Sperry -Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22227-70. R E 114 "1 " "Y E-w VV E"C") -- 1999 Oil Gas Cons .040MMt n Angora 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 563-3256 * Fax (907) 563-7252 A Division of Dresser Industries, Inc. sperry-sun DRILLING SERVICES WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - D. S. 2-31 A, AK-MW-90105 September 5, 1999 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry -Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22227-01. Antijoe 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 273-3500 • Fax (907) 273-3535 A Halliburton Company 10/6/99 Schlbepgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job # NO. 12840 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Log Description Date BL Sepia CD IVA SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. a�•IU� a•07i? U�D:� 't OI11 -7?.o.),y SchwMherger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job # NO. 12797 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Log Description Date BL Sepia CD D.S. 2-25 STATIC BOTTOM HOLE 990827 1 1 D.S. 2-31A MEM TIE-IN LOG W/GR/CCL 990831 1 1 D.S. 9-22 i L_ INJECTION PROFILE 990827 1 1 D.S. 14-14 c— INJECTION PROFILE W/PSP 990907 1 1 D.S. 15-30 MEM TIE-IN LOG W/GR/CCL 990901 1 1 D.S.2-29A 2. 99312 RST-SIGMA 990801 1 1 1 D.S.3-34A4c( 3 Iq 99321 RST-SIGMA 990807 1 1 1 D.S.5-08 99341 RST-SIGMA 990809 1 1 1 SIGNED. +' '' DATE: r , 1999 Alaska Oii & Gas Cans. Goriimikujull Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank Waage 9/16/99 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development—X Exploratory_ RKB 68 feet 3. Address 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 589' FNL, 3595' FEL, Sec. 36, T11 N, R14E, UM 02-31A At top of productive interval 9. Permit number / approval number 64' FNL, 1942' FEL, Sec. 36, T1 ON, R14E, UM 99-15 At effective depth 10. API number 50-029-22227-01 At total depth 11. Field / Pool 4646' FNL, 3528' FEL, Sec. 25, T11 N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 11215 feet Plugs (measured) Tagged PBTD @ 11020' MD (4/19/1999) true vertical 8946 feet Effective depth: measured 11020 feet Junk (measured) true vertical 8948 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 118' 20" 280 Sx class G 118' 118' Surface 3447' 9-5/8" 1920 cubic ft CS III & 348 cubic ft 3515' 3512' Class G Production 8680' 7" 983 cubic ft Class G 8748' 8425' Liner 620' 5" 189 cubic ft Class G 9074' 8708' Liner 2828' 2-7/8" 27 bbis 15.8 ppg LARC & 17 bbls 11150' 8944' 15.8 ppg Class G Perforation depth: measured 9600' - 9740'; 10450' - 11000'. ORIGINA true vertical 8951' - 8944'; 8953' - 8950'. Tubing (size, grade, and measured depth) 4-1/2', 12.6#, L-80 Tbg 0 8939' MD. Packers & SSSV (type & measured depth) 7" X 4-1/2" S-3 PACKER @ 831Z MD. 4-1/2" CAMCO BALO SSSV NIP @ 2203' MD. = 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 238 5776 11 - 244 Subsequent to operation 1343 3809 56 - 269 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil _X Gas _ Suspended _ Service 17. 1 hereby certifyAthatforegoing=isn ect to the best of my knowledge. Signed Title AAI CTD Supervisor Date PBruce E. Smith, P. E. / Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 - SUBMIT IN DUPLICATE 02-31 A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 8/31/1999 - MIRU ELU & PT'd equipment to 4000 psi. Ran mem tie in log. RIH w/ perforation guns & 9/02/1999: shot 140' of Add Perforations located @: 9600' - 9740' MD (Zone 1 B) Ref Log: CNL 4/18/1999. Used 2" carriers & all shots @ 4 SPF, random orientation, 00 phasing, & balanced pressure. POOH w/ guns. ASF. RD. Returned well to production & obtained a valid welltest. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operators performed: Operation shutdown _ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X (Sqz) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development_X Exploratory_ RKB 68 feet 3. Address 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service_ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 589' FNL, 3595' FEL, Sec. 36, T11N, R14E, UM 02-31A At top of productive interval 9. Permit number / approval number 64' FNL, 1942' FEL, Sec. 36, T1ON, R14E, UM 99-15 At effective depth 10. API number 50-029-22227-01 At total depth 11. Field / Pool 4646' FNL, 3528' FEL, Sec. 25, T11 N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 11215 feet Plugs (measured) Tagged PBTD 0 11020' MD (4/19/1999) true vertical 8946 feet Effective depth: measured 11020 feet Junk (measured) true vertical 8948 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 118' 20" 280 Sx class G 118' 118' Surface 3447' 9-5/8" 1920 cubic ft CS III & 348 cubic ft 3515' 3512' Class G Production 8680' 7" 983 cubic ft Class G 8748' 8425' Liner 620' 5" 189 cubic ft Class G 9074' 8708' Liner 2828' 2-7/8" 27 bbis 15.8 ppg LARC & 17 bbls 11150, 8944' 15.8 ppg Class G Perforation depth: measured 10450' - 11000'. true vertical 8953' - 8950'. Cj Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg 0 8939' MD. Anohoragc--4� 0 R I t i Packers & SSSV (type & measured depth) 7" X 4-1/2" S-3 PACKER @ 8312' MD. 4-1/2" CAMCO BALO SSSV NIP @ 2203' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) Subsequent to operation 2090 20473 0 - 270 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil _X Gas _ Suspended _ Service 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 40'jar Title AAI CTD Supervisor Date -71g��7 % E Bruce E. Smith, P. E. +"' StA "'� Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 • SUBMIT IN DUPLICATE 02-31 A DESCRIPTION OF WORK COMPLETED POST CTD / LINER TOP CEMENT SQUEEZE FOR GSO Date Event Summary 6/10/1999: A liner lap down squeeze was performed as follows: MIRU CTU & PT'd equip to 3500 psi. Killed well w/ 1600 Slick 1 % KCL Water. Performed injection test. RIH & stung into liner top @ 8322' MD. Pressured CTD to 2800 psi & sheared pins to shift the orifice sleeve. Circulation path will cross over f/ coil to the annulus above liner top. Bullheaded 22 bbls of 15.8 ppg Neat Class G Cement out the liner lap sqz tool & down liner lap. Placed 17 bbls of Cement behind pipe @ a max sqz press of 1550 psi. Contaminated Cement w/ Biozan and jetted contaminated Cement f/ wellbore. Cleaned out to 10450' MD. POOH laying in Crude. Left 500 psi on wellhead. RD. Returned well to production & obtained a valid welltest. KA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMi�10N WELL COMPLETION OR RECOMPLETION REPORT AND L� } 1. Status of well Oil Q Gas Suspended Abandoned 0 Service Classification of Service Well �t 2. Name of Operator ARCO Alaska, Inc. 7. Permit Number Gas cons.�4 99-15 Anchorage 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 8. API Number 50-029-22227-01 Location of Mace 592' FNL; 1'684'�F/EL, Sec. 36, T11N, R14E, UM ;ice At Top Producing Interval 64' FNL, 1942' FEL, SEC 36, T11 N, R14E, UM At Total Depth �G 4643' FNL, 3532' FEL, SEC 25, T11 N, R14E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 02-31A 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 5. Elevation in feet (indicate KB, DF, etc.) RKB 68 feet 6. Lease Designation and Serial No. I AD 28308 12. Date Spudded April 5, 1999 13. Date T.D. Reached April 16, 1999 14. Date Comp., Susp. Or Aband. April 20, 1999 15. Water Depth, if offshore N/A feet MSL 16. No. of Completions 1 17. Total Depth (MD + TVD) 11215' MD / 8946' TVD 18. Plug Back Depth (MD + TVD) 11020' MD / 8948' TVD 19. Directional Survey YES Q No 20. Depth where SSSV set 2202' feet MD 21. Thickness of Permafrost 1900' (approx) 2-2. Type Electric or Other Logs Run MWD, Mem CNL, GR 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING TOP DEPTH MD BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.5# WELD Surface 118' 30" 280 Sx Class G 9-5/8" 36# J-55 Surface 3515' 12-1/4" 1920 cubic ft CS lit & 348 cubic ft Class G 7" 26# L-80 Surface 8748' 8-1/2" 983 cubic ft Class G 5" 15# FL45 8454' 9074' 6" 189 cubic ft Class G 2-7/8" 6.16# L-80 8322' 11151, 3-5/8" 27 bbls 15.8 ppg LARC 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 10450' - 11000' MD; 8953' - 8950' TVD; @ 4 SPF 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1 /2" 8439' 8311' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 23, 1999 Flowing OHIGINAL Date of Test 4/23/1999 Hours Tested 3.0 Production for Test Period > OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS -OIL RATIO 59895 Flow Tubing Press. -2315 psi Casing Pressure 124-Hour Calculated Rate > OIL-BBL 694 GAS-MCF 41567 WATER-BBL 0 OIL GRAVITY - API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved March 12, 1999 (Permit #99-15) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29• 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Sag River Sand 8668' 8358' Top of Shublik 8718' 8400' Top of Sadlerochit 8785' 8457' Top of Zone 1 B 9390, 8898' 31. LIST OF ATTACHMENTS Summary of 02-31A CT Sidetrack Drilling Operations + Survey. 32. 1 hereby certify that the following is true and correct to the best of my knowledge. Signed Title AAI Coil Tubing Drilling Supervisor Date Bruce E. Smith, P.E. Prepared by Paul Rauf 263-4990. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in -situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 02-31 A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 4/02/1999 - MIRU. PT'd BOPE. MU BHA. 4/04/1999: 4/05/1999: RIH & milled nipple @ 8403' MD. Tagged Whipstock @ 9068'. Milled on WS for 10 hours w/ 1.5' progress. POOH. 4/06/1999: RIH & milled window f/ 9074' to 9080' MD through the 5" chrome liner. Drilled into FM to 9091'. Pumped Biozan sweep in OH. POOH. 4/07/1999: RIH & conditioned window interval. POOH. RIH & displaced well to new mud. Drilled to 9153' & POOH. RIH & performed LOT to EMW of 9.1 ppg. 4/08/1999: Drilled f/ 9154' to 9222' & POOH. RIH & drilled to 9317' MD. Decision to plugback. 4/09/1999: POOH. RIH & pumped 7 bbls of 17 ppg Class G Cement f/ 9295' - 8865'. Contaminated Cement w/ Biozan & jetted contaminated Cement f/ wellbore to 9100'. POOH. WOC. 4/10/1999: RIH & tagged TOC @ 9115'. Drilled off Cement plug to 9475' MD. 4/11/1999: Drilled to 9051' & POOH. RIH & drilled to 9590'. 4/12/1999: Drilled to 9646' & swapped to new mud. POOH. RIH & drilled horizontal to 9960'. 4/13/1999: Wiper trip to TT. RBIH & drilled ahead to 10375'. 4/14/1999: Drilled to 10383 & POOH. RIH & drilled to 10670'. 4/15/1999: Drilled to 11203'. 4/16/1999: Drilled to TD @ 11215' MD. Freed CT w/ Crude pill. Conditioned OH & POOH. 4/17/1999: RIH & landed 2-7/8" liner @ 11151'. Pumped 27 bbls of 15.8 ppg LARC to cement the liner in place. Contaminated Cement w/ Biozan & C/O to-10208'. POOH. PT'd BOPE. 4/18/1999: RIH w/ logging tools & logged OH. POOH w/ tools. Performed liner lap test to 2000 psi - press bleeds off 300 psi in 20 min. TOL=8322'. BOL=11151'. 4/19/1999: RIH w/ Perf guns to PBTD @ 11020' & shot 550' of Initial Perforations f/: 10450' - 11000' MD (Zone 1 B) Used 2" HSD carriers & shot all perfs @ 4 SPF. POOH w/ guns. ASF. RIH w/ nozzle to 8300' & displaced well to Crude. POOH. 4/20/1999: RDMOL. Placed well 02-31A on initial production & obtained a valid well test. Well gassed out, awaiting a liner top packer installation. Sidetrack Summary Page 1 Sperry-Suri DRILLING SERVICES AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2-31A Dear Lori Taylor: Enclosed are two survey hard copies. Tie -on Survey: Window / Kickoff Survey: Projected Survey: 9,000.00' MD 9,068.00' MD (if applicable) 11,220.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 22-Apr-99 27 1999 Gas COS, Comdvon AnftMV 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 273-3500 • Fax (907) 273-3535 A Halliburton Company Sperry-sur=i DRILLING SERVICES AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2-31APB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie -on Survey: Window / Kickoff Survey Projected Survey: 9,000.00' MD 9,068.00' MD (if applicable) 9,316.00' MD 22-Apr-99 Please call me at 273-3545 if you have any questions or concerns. Regards, �� ----� CVE J ,. William T. Allen Survey Manager Attachment(s) PR 2 71999 Alaska Oil & Gas Cons. Commission Anftap 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 273-3500 • Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 02, Slot 02-31 02-31 - 2-31 A Job No. AKMW90105, Surveyed: 15 April, 1999 SURVEYREPORT 22 April, 1999 0 Re" 1 Li IN� A. L RECE'lVED !'� PR 2 71999 Alaska Oil & Gas Cons. Commission Your Ref: API-500292222701 Anchorage Surface Coordinates: 5950629.36 N, 688425.97 E (700 16' 11.6376" N, 1480 28' 33.8134" W) Kelly Bushing: 68.00ft above Mean Sea Level sp err V-sun DRIL-LING SeRVICES A VIALLIBURMN MWANY Survey Ref: svy8513 SperrymSun DrillingServices Survey Report for 02-31 - 2-31A Your Ref: API-500292222701 Job No. AKMW90105, Surveyed: 15 April, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 02 Measured Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 9000.00 9068.00 28.080 26.730 89.906 90.240 8574.30 8642.30 383.24 N 1451.41 E 5951048.82 N 689867.33 E -1083.63 9097.31 27.750 80.860 8634.66 8660.73 8702.66 8728.73 383.20 N 1482.71 E 5951049.56 N 689898.62 E 1.998 -1111.02 9131.58 38.770 76.230 8689.35 8757.35 384.26 N 388.09 N 1496.04 E 1514.40 E 5951050.95 N 689911.92 E 15.041 -1122.17 9163.78 48.550 71.880 8712.62 8780.62 394.26 N 1535.72 E 5951055.24 N 5951061.95 N 689930.18 E 32.978 -1136.37 689951.34 E 31.758 -1152.03 9191.66 9217.40 57.000 60.880 72.060 64.310 8729.47 8797.47 401.13 N 1556.81 E 5951069.33 N 689972.25 E 30.313 -1167.15 9249.93 59.470 52.680 8742.77 8758.99 8810.77 8826.99 409.34 N 1577.24 E 5951078.05 N 689992.47 E 29.860 -1181.03 9280.23 60.530 39.990 8774.18 8842.18 424.03 N 442.10 N 1601.25 E 1620.16 E 5951093.34 N 690016.10 E 31.303 -1194.91 9313.18 59.910 27.830 8790.59 8858.59 465.77 N 1636.08 E 5951111.88 N 5951135.94 N 690034.56 E 36.419 -1202.69 690049.88 E 32.071 -1205.14 9349.77 9392.56 57.270 64.140 15.670 359.810 8809.71 8830.74 8877.71 494.67 N 1647.66 E 5951165.12 N 690060.73 E 29.247 -1201.26 9414.45 66.430 352.940 8839.90 8898.74 8907.90 531.47 N 551.30 N 1652.49 E 5951202.03 N 690064.64 E 36.036 -1187.64 9454.91 72.230 337.590 8854.25 8922.25 587.73 N 1651.22 E 1641.54 E 5951221.82 N 690062.87 E 30.362 -1176.92 9492.61 77.890 325.980 8864.00 8932.00 619.73 N 1624.31 E 5951258.00 N 5951289.56 N 690052.28 E 38.249 -1150.78 690034.26 E 33.312 -1120.21 9519.34 9551.11 82.820 315.580 8868.49 8936.49 640.10 N 1607.67 E 5951309.50 N 690017.11 E 42.549 -1095.77 9584.61 78.330 79.120 305.190 289.150 8873.70 8880.29 8941.70 8948.29 660.38 N 1583.85 E 5951329.19 N 689992.79 E 35.213 -1065.10 9624.02 88.720 273.640 8884.49 8952.49 675.33 N 682.99 N 1554.72 E 1516.46 E 5951343.40 N 689963.30 E 47.009 -1032.38 9677.07 96.650 270.470 8882.01 8950.01 684.89 N 1463.55 E 5951350.10 N 5951350.68 689924.86 E 46.055 -995.20 N 689871.92 E 16.094 -948.01 9713.91 9745.00 95.070 94.100 270.650 272.590 8878.24 8946.24 685.25 N 1426.91 E 5951350.12 N 689835.27 E 4.316 -915.78 9773.17 92.250 275.050 8875.76 8874.20 8943.76 8942.20 686.13 N 1395.93 E 5951350.22 N 689804.29 E 6.959 -888.27 9810.84 90.130 277.870 8873.42 8941.42 688.00 N 692.24 N 1367.87 E 1330.45 E 5951351.39 N 689776.19 E 10.916 -862.81 9843.79 90.220 280.870 8873.32 8941.32 697.60 N 1297.95 E 5951354.69 N 5951359.24 N 689738.67 E 9.364 -828.03 689706.04 E 9.109 -797.00 22 April, 1999 - 10:54 -2- Comment TIE ON SURVEY WINDOW POINT Continued... DrillQuest SperrymSun Drilling Services Survey Report for 02-31 - 2-31A Your Ref: API-500292222701 Job No. AKMW90105, Surveyed: 15 April, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA IDS 02 Measured Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth (ft) Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 9877.81 9905.00 92.250 92.510 284.390 287.210 8872.58 8940.58 705.04 N 1264.76 E 5951365.84 N 689672.69 E 11.942 -764.38 9932.63 92.250 288.090 8871.45 8870.31 8939.45 8938.31 712.44 N 1238.63 E 5951372.58 N 689646.37 E 10.407 -737.93 9967.66 92.860 290.910 8868.74 8936.74 720.81 N 732.49 N 1212.32 E 1179.33 E 5951380.29 N 689619.86 E 3.318 -710.86 9997.39 92.400 291.550 8867.38 8935.38 743.24 N 1151.65 E 5951391.14 N 5951401.20 N 689586.60 E 8.229 -676.35 689558.65 E 2.649 -646.93 10027.58 10047.80 92.250 91.100 295.140 296.020 8866.15 8934.15 755.19 N 1123.96 E 5951412.45 N 689530.67 E 11.892 -616.91 10080.04 91.100 297.610 8865.56 8864.94 8933.56 8932.94 763.92 N 778.46 N 1105.73 E 5951420.72 N 689512.23 E 7.160 -596.74 10128.56 93.740 303.600 8862.89 8930.89 803.12 N 1076.96 E 1035.26 E 5951434.54 N 689483.11 E 4.931 -564.53 10155.59 90.040 305.720 8862.00 8930.00 818.48 N 1013.05 E 5951458.15 N 5951472.95 N 689440.80 E 13.480 -516.10 689418.21 E 15.773 -489.22 10192.45 10226.85 86.340 85.730 307.480 310.300 8863.17 8931.17 840.44 N 983.47 E 5951494.16 N 689388.10 E 11.114 -452.71 10250.03 84.740 309.990 8865.55 8867.47 8933.55 8935.47 861.99 N 956.77 E 5951515.03 N 689360.86 E 8.368 -418.91 10282.64 84.850 308.890 8870.43 8938.43 876.88 N 897.51 N 939.11 E 914.03 E 5951529.48 N 689342.83 E 4.474 -396.24 10319.13 85.020 308.010 8873.65 8941.65 920.11 N 885.56 E 5951549.47 N 5951571.35 N 689317.24 E 3.376 -364.31 689288.22 E 2.447 -328.45 j 10349.96 10379.89 85.460 86.430 306.240 305.890 8876.21 8944.21 938.66 N 861.07 E 5951589.28 N 689263.27 E 5.897 -298.04 0408.10 84.410 299.900 8878.33 8880.58 8946.33 8948.58 956.23 N 971.50 N 836.93 E 5951606.24 N 689238.70E 3.444 -268.41 10448.56 83.350 298.840 8884.89 8952.89 991.23 N 813.34 E 778.28 E 5951620.91 N 689214.73 E 22.343 -240.37 10478.35 82.970 294.870 8888.44 8956.44 1004.59 N 751.90 E 5951639.76 N 5951652.45 N 689179.19 E 3.694 -200.14 689152.48 E 13.293 -170.59 10521.46 10553.36 82.730 85.250 291.090 8893.81 8961.81 1021.28 N 712.52 E 5951668.16 N 689112.70 E 8.718 -128.06 10577.39 87.710 287.990 286.400 8897.15 8898.63 8965.15 8966.63 1031.89 N 682.63 E 5951678.01 N 689082.55 E 12.482 -96.77 10599.07 90.970 286.230 8898.88 8966.88 1038.98 N 1045.07 N 659.72 E 5951684.53 N 689059.47 E 12.182 -73.30 10631.82 91.140 282.890 8898.27 8966.27 1053.30 N 638.92 E 607.23 E 5951690.09 N 689038.53 E 15.057 -52.15 5951697.53 N 689006.64 E 10.210 -20.45 Continued... 22 April, 1999 - 10:54 - 3 - Dr/11Quest Sperry,Sun DrillingServices Survey Report for 02-31 - 2-31A Your Ref: API-500292222701 Job No. AKMW90105, Surveyed. 15 April, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 02 Measured Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) pi 00ft) (ft) 10650.18 91.930 280.600 8897.78 8965.78 1057.03 N 589.26 E 5951700.81 N 688988.59 E 13.190 -2.92 10695.64 92.720 275.510 8895.94 8963.94 1063.40 N 544.30 E 5951706.05 N 688943.48 E 11.322 39.49 10728.96 92.280 270.760 8894.48 8962.48 1065.22 N 511.07 E 5951707.04 N 688910.22 E 14.303 69.43 10754.98 93.870 267.770 8893.09 8961.09 1064.88 N 485.10 E 5951706.05 N 688884.26 E 13.000 91.99 10784.37 93.780 269.180 8891.13 8959.13 1064.10 N 455.78 E 5951704.54 N 688854.97 E 4.797 117.25 10824.45 92.900 275.040 8888.79 8956.79 1065.58 N 415.82 E 5951705.01 N 688814.98 E 14.760 152.92 10850.61 91.230 277.790 8887.85 8955.85 1068.50 N 389.84 E 5951707.28 N 688788.94 E 12.293 177.05 10890.30 90.000 282.360 8887.42 8955.42 1075.44 N 350.78 E 5951713.24 N 688749.71 E 11.923 214.59 10942.19 92.900 288.510 8886.11 8954.11 1089.23 N 300.80 E 5951725.78 N 688699.41 E 13.099 264.98 10981.09 93.340 291.680 8883.99 8951.99 1102.58 N 264.33 E 5951738.21 N 688662.62 E 8.215 303.35 11006.89 96.850 295.190 8881.70 8949.70 1112.79 N 240.76 E 5951747.83 N 688638.80 E 19.200 328.92 11042.90 94.480 298.010 8878.14 8946.14 1128.84 N 208.72 E 5951763.07 N 688606.37 E 10.200 364.72 11069.26 92.110 300.290 8876.63 8944.63 1141.65 N 185.74 E 5951775.31 N 688583.07 E 12.466 391.03 11107.59 89.380 302.220 8876.13 8944.13 1161.54 N 152.98 E 5951794.36 N 688549.83 E 8.722 429.32 11143.15 90.700 307.320 8876.10 8944.10 1181.81 N 123.78 E 5951813.90 N 688520.13 E 14.814 464.69 11178.75 87.450 306.970 8876.68 8944.68 1203.30 N 95.41 E 5951834.67 N 688491.23 E 9.182 499.92 11190.36 87.270 307.670 8877.21 8945.21 1210.33 N 86.19 E 5951841.47 N 688481.83 E 6.219 511.40 11220.00 87.270 307.670 8878.62 8946.62 1228.42 N 62.76 E 5951858.97 N 688457.95 E 0.000 540.66 PROJECTED SURVEY All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.8210 (20-Apr-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 299.000' (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11220.00ft., The Bottom Hole Displacement is 1230.03ft., in the Direction of 2.9250 (True). Continued... 22 April, 1999 - 10:54 - 4 - DrlllQuest SDerrvwSun Drillina Services Survey Report for 02-31 - 2-31A Your Ref: API-500292222701 Job No. AKMW90105, Surveyed. 15 April, 1999 Prudhoe Bay Unit Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 9000.00 8642.30 383.24 N 1451.41 E 9068.00 8702.66 383.20 N 1482.71 E 11220.00 8946.62 1228.42 N 62.76 E Comment TIE ON SURVEY WINDOW POINT PROJECTED SURVEY Alaska State Plane Zone 4 PBU_EOA DS 02 A 22 April, 1999 - 10:54 - 5 - DrlllQuest Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 02, Slot 02-31 ,1 ��-- 02-31 - 2-31 A PB 1 C l� Job No. AKMW90105, Surveyed: 8 April, 1999 SURVEYREPORT 0 R 11 G it NIAL RECE"IVED 22 April, 1999 APR p 71999 Your Ref: API-500292222770 Alaska Oil & Gas Cots. Commission Surface Coordinates: 5950629.36 N, 688425.97E (700 16` 11.6376" N, 1480 28' 33.8134" W) An*MF Kelly Bushing: 68.00ft above Mean Sea Level spennV-sun DRIL.L.ING SERVICES Survey Ref:svy8511 A anLLIBURTON conPnm a SperrywSun DrillingServices Survey Report for 02-31 - 2-3 1A PB 1 Your Ref; API-500292222770 Job No. AKMW90105, Surveyed: 8 April, 1999 Alaska State Plane Zone 4 Prudhoe Bay Unit PBU_EOA DS 02 Measured Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 9000.00 28.080 89.906 8574.30 8642.30 383.24 N 1451.41 E 5951048.82 N 689867.33 E -1083.63 TIE ON POINT 9068.00 26.730 90.240 8634.66 8702.66 383.20 N 1482.71 E 5951049.56 N 689898.62 E 1.998 -1111.02 WINDOW POINT 9097.31 27.750 80.860 8660.73 8728.73 384.26 N 1496.04 E 5951050.95 N 689911.92 E 15.041 -1122.17 9124.21 35.330 74.390 8683.65 8751.65 387.35 N 1509.74 E 5951054.39 N 689925.54 E 30.824 -1132.66 9151.46 41.940 69.240 8704.93 8772.93 392.71 N 1525.87 E 5951060.15 N 689941.53 E 26.957 -1144.16 9184.83 33.080 82.580 8731.42 8799.42 397.86 N 1545.40 E 5951065.78 N 689960.92 E 35.897 -1158.75 9221.51 20.620 85.100 8764.08 8832.08 399.71 N 1561.82 E 5951068.04 N 689977.30 E 34.104 -1172.22 9252.16 14.630 34.700 8793.44 8861.44 403.38 N 1569.45 E 5951071.90 N 689984.83 E 51.501 -1177.11 9283.17 32.070 20.780 8821.82 8889.82 414.38 N 1574.64 E 5951083.03 N 689989.75 E 58.619 -1176.32 9316.00 48.760 9.390 8846.76 8914.76 434.88 N 1579.79 E 5951103.66 N 689994.38 E 55.416 -1170.88 PROJECTED SURVEY All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.821 ° (20-Apr-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 299.000' (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9316.00ft., The Bottom Hole Displacement is 1638.56ft., in the Direction of 74.6090 (True). Continued... 22 April, 1999 - 10:26 - 2 - DrillOuest Prudhoe Bay Unit Comments Measured Depth (ft) 9000.00 9068.00 9316.00 SperrywSun DrillingServices Survey Report for 02-31 - 2-3 1A PB 1 Your Ref: API-500292222770 Job No. AKMW90105, Surveyed: 8 April, 1999 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8642.30 383.24 N 1451.41 E 8702.66 383.20 N 1482.71 E 8914.76 434.88 N 1579.79 E Comment TIE ON POINT WINDOW POINT PROJECTED SURVEY Alaska State Plane Zone 4 PBU_EOA DS 02 22 April, 1999 - 10:26 - 3 - Dr111Quest MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson0 DATE: April 9, 1999 Chairman THRU: Blair Wondzell, FILE NO: ae9gdigfDOC P. I. Supervisor 01-IFf y FROM: Lawrence M � SUBJECT: BOP Test Petroleum Inspector CDR 1 PBU DS 2-31 A PTD 99-15 April 9,1999: 1 traveled to ARCO's DS 2 to witness a BOP test on the CDR 1. They tested with their drilling fluid which was a gel based mud. It carried a lot of air and the testing went slower than usual because it took a while to compress the air in the coil. The rig is looking better all the time but it still has a way to go compared to the rest of the rigs on the slope. SUMMARY: Witnessed a BOP test on CDR 1, 4.5 hours, 0 falures. Attachments: ae9gdigf CC" NON -CONFIDENTIAL STATE OF ALASKA� , OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit ROPE Test Report OPERATION: Drlg: X Workover: DATE: 41W99 Drlg Contractor: Trans Ocean/Nabors Rig No. CDR 1 PTD # 99-15 Rig Ph.# Operator: ARCO Rep.: Lamarr Gantt Well Name: DS 2-31A Rig Rep.: Terry Wasyluk Casing Size: 4 112" Set @ 9,449 Location: Sec. 36 T. 11N R. 14E Meridian Umiat Test: Initial Weekly X Other Test Test BOP STACK: Quan. Pressure P/F CHOKE MANIFOLD: Quan. Pressure P/F Coil Tubing Unit: No. Valves 10 35013500 P Pipe/Slip Rams No. Flanges 21 35013500 P Pipe/Slip Rams Manual Chokes 1 Functioned P Blind Rams 1 350/3500 P Hydraulic Chokes 1 Functioned P Reel Isolation Valve 2 350/3500 P — Deployment: ACCUMULATOR SYSTEM: Annular Preventer 1 350/3500 System Pressure 2,900 Pipe Rams Pressure After Closure 2,150 Lower Pipe Rams 1 350/3500 200 psi Attained After Closure minutes 15 sec. Blind Rams 1 350/3500 System Pressure Attained minutes 49 sec. Choke Ln. Valves 3 350/3500 Blind Switch Covers: Master: X Remote: X HCR Valves 1 350/3500 Nitgn. Btl's: 2 !2 2000 Psig. Kill Line Valves 3 350/3500 MUD SYSTEM: Visual Alarm MISC. INSPECTIONS: Trip Tank X X Location Gen.: ok Well Sign X Pit Level Indicators X X Housekeeping: ok DrI. Rig ok Meth Gas Detector X X Permit to drill: X Hazard Sec, X H2S Gas Detector X X -- Standing Order Posted X :.: ... :.: ::: :.::::TB ----------------- ...R St, LT ..................... . .. ......... .-== =_ Number of Failures: 0 .. ,Test Time• 4.5 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. i. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt Fife c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade Form Revised 2120197 L.G. ae9gd1gf.x1s 4111199 TONY KNOWLES, GOVERNOR ALASSA OIL AND GAS CONSERVATION COMNIISSION March 11, 1999 Bruce E. Smith, P.E. AAI Coil Tubing Drilling Supervisor ARCO Alaska, Inc. P 0 Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 02-31A ARCO Alaska, Inc. Permit No: 99-15 Sur Loc: 592'FNL, 1684'FEL, Sec. 36, TI IN, R14E, UM Btmhole Loc. 4721'FNL, 3778'FEL, Sec. 25, T11N, R14E, UM Dear Mr. Smith: 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPS) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Since , Robert N. Christenson, P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA,- ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work: Drill ❑ Redrill ❑ Re-entry ❑ Deepen ❑ 1b. Type of well. Exploratory ❑ Stratigraphic Test ❑ Development Oil ❑ Service Development Gas ❑ Single Zone ❑J Multiple Zone ❑ 2. Name of Operator ARCO Alaska, Inc. 5. Datum elevation (DF or KB) RKB 68 feet 10. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 6. Property Designation AD 028308 4. Location of well at surface 592' FNL, 1684' FEL, SEC. 36, T11 N, R14E, UM At top of productive interval 216' FNL, 2457' FEL, SEC. 36, T11N, R14E, UM At total depth 4721' FNL, 3778' FEL, Sec 25, T11 N, R14E, UM 7. Unit or property Name Prudhoe Bay Unit 11. Type Bond (see 20 AAC 25.0251) Statewide Number #U-630610 Amount $200,000 8. Well number 02-31A 9. Approximate spud date March 20, 1999 12. Distance to nearest property line feet 13. Distance to nearest well No Close Approach feet 14. Number of acres in property 15. Proposed depth (MD and ND) 11370' MD / 894T TVD 16. To be completed for deviated wells Kickoff depth: 9075' MD Maximum hole angle 920 IMaximurnsurfaoe 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) 2500 psig At total depth (TVD) 3400 psig 0 8800' 18. Casing program size Specifications Setting Depth Quantity of Cement Top Bottom Hole Casing F62ht Grade Coupling Length MD TVD MD TVD include stage data 3-7/8" 3-3/16" L-80 TC II 2970' 8400' 8128' 11370' 8948' 16 bbis 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary HH161NAL Total Depth: Effective Depth: Casing Conductor Surface Production Liner Perforation depth: measured 9525 feet Plugs (measured) PBTD tagged @ 9449' MD (1/04/1999) true vertical 9123 feet measured 9449 feet Junk (measured) true vertical 9052 feet Length Size Cemented 118' 20" 280 Sx CS G 3447' 9-5/8" 1920 cubic ft CS III & 348 cubic ft G 8680' 7" 983 cubic ft Class G 1071' 5" 189 cubic ft Class G measured 9348' - 9362'; 9376' - 9390'. Measured depth 118, 3515' 8748' 9525' True Vertical depth 118, 3512' 8425' 9123' true vertical 8958' - 8971'; 8984' - 8997'. (=)�� = e €€� tb ;IE1r Eij; n _9 ifL�lii-7:=] 20. Attachments Filing fee ❑ Property Plat ❑ BOP Sketch ❑ Diverter Sketch ❑ Drilling program ❑ Drilling fluid program Time vs depth plot ❑ Refraction analysis ❑ Seabed report ❑ 20 AAC 25.050 requirements ❑ 21. 1-hereby certifyAq the foregoing i rrect to the best of my knowledge Questions? Call Stephen Ward 0 265-1305.Q Signed Title: AAI Coil Tubing Drilling Supervisor Date /5 — ! Bruce E. Smith. P.E. Prepared by Pau/ Rauf 263-4990 Permit Number API number Approval dat ) See cover letter S 1 50- O Z — Z- Z Z Z--,:> "o /l j for other requirements Conditions of approval Samples required ❑ Yes t@ No Mud log required ❑ Yes Z No Hydrogen sulfide measures 0 Yes ❑ No Directional survey required Yes ❑ No Required working pressure for BOPE ❑ 2M; ❑ 3M; ❑ 5M; ❑ 10M; ❑ 3500 psi for CTU Other. UOSU91SuyO -N ljego8 by order of � MR-03NOIS IVNIONO Commissioner the commission Date ��`) `/ Form 10-401 Rev. 12/1/85 • Submit in triplicate DS2-31A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 3-3/16" cemented liner. Perforate and produce. Intended Procedure: • RU CTD unit and test BOPE. Cement squeeze and plugback the existing completion to - 9045' md. • Mill window in 5" casing at -9075' md. Drill 10' of formation with 8.9 ppg Flopro fluid and perform Leak off test to 9.4 ppg. • Directionally drill 3.875" x 1600' horizontal well to access Lower Romeo reserves. Build angle to -92' and then drop to 90°at TD. • Run and cement 3-3/16" liner to TD. • Perforate selected intervals. • Place well on production. NOTE: Drill cuttings will be disposed of at CC2A and drilling mud will be disposed at Pad 3. February 11, 1999 400 300 NO 100 0 8300 N 8400 Q 8500- QU 0 8600 U 4— L N 8700 N 8800 ..... _ . AR--�,C0 A I a s h: a9 IInc. Structure D.S. 2 Slot 2-31 Field Prudhoe Bay Location : North Slope, Alaska FZ' r�CI �1�CG CCU) 1Ilc�f`llC�� East (feet) —> 100 200 300 400 500 600 700 800 slop 1000 1100 1200 1300 1400 1500 1G00 1700 1800 1400 1300 1200 1100 1000 n 900 Z O 800 (D (D f 700 u 600 500 400 300 8878' 4 — 8864' y 5 ..- 8882' V 8000 2-31 bhs 2-3'1 ihs 2-31 iihs 2--3'1 ehs - T.D. & End of Build/lurn -- 90.26 Inc, 11370.81 Md, 8880.00 Tvd, 717.59 Vs 1200 1100 1000 900 800 700 G00 500 400 300 200 100 0 100 200 300 400 500 600 700 800 900 1000 Vertical Section (feet) —> Azimuth 299.00 with reference 0.00 N, 0.00 E from 2-31 ARCO Alaska, Inc. PROPOSAL LISTING Page 1 D.S. 2,2-31 Your ref 2-31A Version #3 Prudhoe Bay,North Slope, Alaska Last revised ll-Feb-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 9000.00 28.08 89.90 8574.30 383.40N 1451.37E 0.00 -1083.52 689867.32 5951048.47 9025.00 27.58 90.02 8596.40 383.41N 1463.04E 2.00 -1093.72 689878.99 5951048.77 9050.00 27.09 90.14 8618.61 383.40N 1474.52E 2.00 -1103.77 689890.46 5951049.04 9075.00 26.59 90.27 8640.92 383.36N 1485.80E 2.00 -1113.66 689901.75 5951049.28 9087.53 23.00 86.00 8652.29 383.51N 1491.05E 32.00 -1118.17 689906.99 5951049.56 9100.00 24.59 76.92 8663.71 384.27N 1496.01E 32.00 -1122.14 689911.93 5951050.44 9125.00 29.11 62.23 8686.03 388.29N 1506.48E 32.00 -1129.35 689922.29 5951054.72 9150.00 34.81 51.57 8707.25 395.57N 1517.47E 32.00 -1135.43 689933.09 5951062.27 9170.44 40.00 45.00 8723.48 403.85N 1526.69E 32.00 -1139.49 689942.11 5951070.78 9175.00 41.34 44.10 8726.94 405.97N 1528.78E 32.00 -1140.28 689944.14 5951072.95 9200.00 48.77 39.89 8744.60 419.13N 1540.57E 32.00 -1144.22 689955.61 5951086.40 9225.00 56.32 36.56 8759.79 434.72N 1552.82E 32.00 -1147.37 689967.46 5951102.29 9238.46 60.41 35.00 8766.85 444.02N 1559.51E 32.00 -1148.71 689973.92 5951111.75 9250.00 60.00 30.77 8772.59 452.43N 1564.95E 32.00 -1149.39 689979.15 5951120.29 9275.00 59.56 21.52 8785.19 471.79N 1574.46E 32.00 -1148.32 689988.17 5951139.87 9300.00 59.78 12.26 8797.84 492.40N 1580.71E 32.00 -1143.80 689993.91 5951160.64 9325.00 60.65 3.09 8810.27 513.87N 1583.60E 32.00 -1135.92 689996.27 5951182.17 9350.00 62.13 354.13 8822.26 535.78N 1583.06E 32.00 -1124.82 689995.18 5951204.05 9375.00 64.17 345.46 8833.57 557.69N 1579.09E 32.00 -1110.73 689990.68 5951225.87 9400.00 66.70 337.11 8843.98 579.20N 1571.79E 32.00 -1093.92 689982.84 5951247.18 9425.00 69.66 329.10 8853.29 599.86N 1561.29E 32.00 -1074.72 689971.84 5951267.58 9450.00 72.97 321.41 8861.31 619.30N 1547.80E 32.00 -1053.49 689957.86 5951286.67 9475.00 76.55 314.00 8867.88 637.11N 1531.57E 32.00 -1030.67 689941.20 5951304.08 9500.00 80.35 306.81 8872.89 652.97N 1512.93E 32.00 -1006.67 689922.17 5951319.46 9525.00 84.29 299.79 8876.24 666.55N 1492.24E 32.00 -981.99 689901.15 5951332.53 9550.00 88.32 292.86 8877.85 677.60N 1469.89E 32.00 -957.09 689878.54 5951343.02 9560.36 90.00 290.00 8878.00 681.39N 1460.25E 32.00 -946.82 689868.81 5951346.56 9575.00 90.00 285.31 8878.00 685.83N 1446.30E 32.00 -932.47 689854.76 5951350.66 9600.00 90.00 277.31 8878.00 690.73N 1421.81E 32.00 -908.67 689830.15 5951354.95 9622.86 90.00 270.00 8878.00 692.18N 1399.02E 32.00 -888.03 689807.33 5951355.84 9625.00 90.03 270.15 8878.00 692.19N 1396.87E 7.00 -886.15 689805.19 5951355.79 96S0.00 90.35 271.87 8877.92 692.63N 1371.88E 7.00 -864.08 689780.19 5951355.61 9675.00 90.67 273.59 8877.70 693.82N 1346.91E 7.00 -841.66 689755.20 5951356.18 9700.00 90.99 275.31 8877.33 695.76N 1321.99E 7.00 -818.93 689730.24 5951357.50 9725.00 91.31 277.03 8876.83 698.44N 1297.14E 7.00 -795.89 689705.33 5951359.57 9750.00 91.62 278.75 8876.19 701.87N 1272.38E 7.00 -772.58 689680.50 5951362.38 9775.00 91.94 280.47 8875.42 706.05N 1247.75E 7.00 -749.01 689655.77 5951365.94 9800.00 92.25 282.20 8874.50 710.96N 1223.25E 7.00 -725.20 689631.16 5951370.24 9811.66 92.40 283.00 8874.03 713.50N 1211.89E 7.00 -714.03 689619.74 5951372.50 9825.00 92.34 283.93 8873.48 716.60N 1198.92E 7.00 -701.18 689606.70 5951375.28 9850.00 92.22 285.68 8872.48 722.98N 1174.77E 7.00 -676.97 689582.40 5951381.06 9875.00 92.10 287.43 8871.54 730.10N 1150.82E 7.00 -652.57 689558.29 5951387.59 9900.00 91.98 289.18 8870.65 737.95N 1127.11E 7.00 -628.02 689534.38 5951394.84 9925.00 91.86 290.93 8869.81 746.52N 1103.64E 7.00 -603.34 689510.71 5951402.82 9950.00 91.74 292.67 8869.03 755.80N 1080.44E 7.00 -578.55 689487.29 5951411.52 9975.00 91.61 294.42 8868.30 765.78N 1057.53E 7.00 -553.68 689464.14 5951420.93 10000.00 91.48 296.17 8867.62 776.46N 1034.93E 7.00 -528.74 689441.29 5951431.05 10025.00 91.35 297.91 8867.00 787.82N 1012.67E 7.00 -503.76 689418.76 5951441.85 10050.00 91.22 299.66 8866.44 799.85N 990.77E 7.00 -478.77 689396.56 5951453.34 10075.00 91.09 301.41 8865.93 812.55N 969.24E 7.00 -453.79 689374.73 5951465.50 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 2-31 and TVD from rkb - MSL = 68ft. Bottom hole distance is 1164.47 on azimuth 350.96 degrees from wellhead. Vertical section is from wellhead on azimuth 299.00 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. PROPOSAL LISTING Page 2 D.S. 2,2-31 Your ref 2-31A Version #3 Prudhoe Bay,North Slope, Alaska Last revised 11-Feb-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 10100.00 90.96 303.15 8865.49 825.90N 948.11E 7.00 -428.83 689353.27 5951478.32 10125.00 90.83 304.90 8865.10 839.89N 927.40E 7.00 -403.93 689332.22 5951491.79 10150.00 90.69 306.65 8864.77 854.50N 907.11E 7.00 -379.11 689311.58 5951505.89 10175.00 90.56 308.39 8864.49 869.73N 887.29E 7.00 -354.39 689291.38 5951520.62 10200.00 90.42 310.14 8864.28 885.55N 867.93E 7.00 -329.79 689271.64 5951535.95 10225.00 90.29 311.88 8864.12 901.95N 849.07E 7.00 -305.34 689252.38 5951551.88 10250.00 90.15 313.63 8864.03 918.92N 830.72E 7.00 -281.06 689233.61 5951568.39 10275.00 90.02 315.38 8863.99 936.4SN 812.89E 7.00 -256.97 689215.35 5951585.47 10293.56 89.92 316.67 8864.00 949.80N 800.00E 7.00 -239.22 689202.14 5951598.50 10293.68 89.91 316.67 8864.00 949.89N 799.92E 8.00 -239.11 689202.06 5951598.58 10300.00 89.53 316.33 8864.03 954.47N 795.57E 8.00 -233.08 689197.59 5951603.06 10325.00 88.06 314.98 8864.56 972.35N 778.09E 8.00 -209.14 689179.69 5951620.49 10350.00 86.58 313.63 8865.73 989.79N 760.22E 8.00 -185.05 689161.39 5951637.48 10375.00 85.10 312.28 8867.54 1006.78N 741.98E 8.00 -160.85 689142.73 5951654.01 10400.00 83.63 310.92 8870.00 1023.29N 723.37E 8.00 -136.57 689123.72 S9S1670.06 10416.84 82.64 310.00 8872.01 1034.15N 710.65E 8.00 -120.18 689110.73 5951680.60 10425.00 83.02 309.47 8873.03 1039.32N 704.43E 8.00 -112.23 689104.38 5951685.61 10450.00 84.20 307.84 8875.81 1054.84N 685.03E 8.00 -87.74 689084.60 5951700.64 10475.00 85.38 306.22 8878.08 1069.83N 665.15E 8.00 -63.09 689064.37 5951715.14 10500.00 86.57 304.61 8879.84 1084.28N 644.83E 8.00 -38.31 689043.69 5951729.08 10S2S.00 87.76 303.00 8881.08 1098.17N 624.08E 8.00 -13.43 689022.61 5951742.45 10550.00 88.95 301.40 8881.80 1111.49N 602.94E 8.00 11.52 689001.14 5951755.24 10572.06 90.00 299.98 8882.00 1122.75N 583.97E 8.00 33.57 688981.90 5951766.02 10572.17 90.00 299.97 8882.00 1122.80N 583.87E 7.00 33.68 688981.80 5951766.07 10575.00 90.00 299.77 8882.00 1124.21N 581.42E 7.00 36.51 688979.32 5951767.42 10600.00 90.01 298.03 8882.00 1136.29N 559.53E 7.00 61.51 688957.14 5951778.96 10625.00 90.02 296.28 8881.99 1147.70N 537.29E 7.00 86.49 688934.62 5951789.81 10650.00 90.03 294.53 8881.98 1158.43N 514.71E 7.00 111.44 688911.78 5951799.97 10675.00 90.04 292.78 8881.96 1168.45N 491.81E 7.00 136.33 688888.64 5951809.43 10700.00 90.05 291.03 8881.94 1177.78N 468.61E 7.00 161.14 688865.22 5951818.17 10725.00 90.06 289.28 8881.92 1186.39N 445.15E 7.00 185.84 688841.55 5951826.20 10750.00 90.07 287.53 8881.89 1194.29N 421.43E 7.00 210.41 688817.64 5951833.50 10775.00 90.08 285.78 8881.86 1201.45N 397.47E 7.00 234.83 688793.52 5951840.07 10800.00 90.09 284.03 8881.82 1207.88N 373.32E 7.00 259.08 688769.21 5951845.90 10825.00 90.10 282.28 8881.78 1213.57N 348.97E 7.00 283.13 688744.74 5951850.98 10850.00 90.11 280.53 8881.74 1218.51N 324.47E 7.00 306.96 688720.12 5951855.32 10875.00 90.12 278.78 8881.69 1222.71N 299.82E 7.00 330.55 688695.38 5951858.90 10900.00 90.12 277.03 8881.64 1226.1SN 275.06E 7.00 353.87 688670.54 5951861.72 10925.00 90.13 275.28 8881.58 1228.83N 250.21E 7.00 376.91 688645.63 5951863.78 10950.00 90.14 273.53 8881.52 1230.75N 225.28E 7.00 399.64 688620.67 5951865.09 10975.00 90.15 271.79 8881.46 1231.91N 200.31E 7.00 422.05 688595.67 5951865.63 11000.00 90.16 270.04 8881.39 1232.31N 175.32E 7.00 444.10 688570.68 5951865.41 11025.00 90.17 268.29 8881.32 1231.94N 150.32E 7.00 465.79 688545.70 5951864.42 11050.00 90.18 266.54 8881.25 1230.82N 125.35E 7.00 487.08 688520.76 5951862.67 11075.00 90.18 264.79 8881.17 1228.92N 100.42E 7.00 507.97 688495.89 5951860.16 11100.00 90.19 263.04 8881.09 1226.27N 75.56E 7.00 528.42 688471.11 5951856.90 11125.00 90.20 261.29 8881.00 1222.87N 50.80E 7.00 548.43 688446.44 5951852.88 11150.00 90.21 259.54 8880.91 1218.70N 26.15E 7.00 567.97 688421.90 5951848.10 11175.00 90.21 257.79 8880.82 1213.79N 1.63E 7.00 587.03 688397.52 5951842.58 11200.00 90.22 256.04 8880.73 1208.13N 22.72W 7.00 605.58 688373.32 5951836.32 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 2-31 and TVD from rkb - MSL = 68ft. Bottom hole distance is 1164.47 on azimuth 350.96 degrees from wellhead. Vertical section is from wellhead on azimuth 299.00 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. PROPOSAL LISTING Page 3 D.S. 2,2-31 Your ref 2-31A Version #3 Prudhoe Bay,North Slope, Alaska Last revised 11-Feb-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 11225.00 90.23 254.29 8880.63 1201.73N 46.88W 7.00 623.61 688349.32 5951829.33 11250.00 90.23 252.54 8880.53 1194.60N 70.84W 7.00 641.11 688325.55 5951821.60 11275.00 90.24 250.79 8880.42 1186.73N 94.57W 7.00 658.05 688302.02 5951813.15 11300.00 90.25 249.04 8880.32 1178.15N 118.05W 7.00 674.43 688278.76 5951803.99 11325.00 90.25 247.29 8880.21 1168.85N 141.26W 7.00 690.22 688255.80 5951794.12 11350.00 90.26 245.55 8880.09 1158.85N 164.17W 7.00 705.41 688233.14 5951783.56 11370.81 90.26 244.09 8880.00 1150.00N 183.00W 7.00 717.59 688214.54 5951774.24 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 2-31 and TVD from rkb - MSL = 68ft. Bottom hole distance is 1164.47 on azimuth 350.96 degrees from wellhead. Vertical section is from wellhead on azimuth 299.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Nam ki- Rig Ar -Alas Ril G LAYO U Drilling Wellhead Detail Methanol Injection -6 8tis 7" WLA Quick Connect '-- CT Injector Head Stuffing Box (Pack -Off), 10,000 psi Working Pressure — 7" Riser Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange —0 29' (3.5") Cutters or 7-1 /16", 5M Ram Type Dual © Combination Cutter/Blinds Gate BOPE Slip/ Pipe rams Flanged Fire Resistant Kelly Hose to Dual HCR Man al Val e Choke Manifold Manual Valves Drilling spool 7-1/16", 5M O by 7-1/16", 5M Ram Type Dual Gate BOPE 2" Pump -In Hydraulic over Electric 7-1/16" ID with © Fire resistant Kelly Hose to Pipe/Slip Rams Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Manual Master Valve 0.458' (5.5") /Tubing Hanger O 9-5/8" Annulus O ) 1113-3/8" Annulus 4-1 /2" Tubin Packer 8311' 4-1 /2" TT @ 8439' 7" Casing Shoe @ 8748' 5" Casing shoe @ 9525' DS 2-31 A Proposed CT Sidetrack Horizontal 2202' 4-1/2" Bal-O SSSV Nipple ID = 3.813" 4-1 /2" Camco KBG2LS '---GLMs ID = 3.65" 4-1/2" DB-6 Nipple @ 8417' 1 D= 3.50" Top of 3-3/16" Liner in 4-1/2" Tbg. tail. Initial Perfs- 1000' Window cut in 5" at \ T D -9075 - 9080' 11370' 3-3/16" liner 3.875" Open hole Current perforations cement squeezed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abando Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casin Repair well _ Plugging X Time extension _ Stimulate _ Change app , ed program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development-( Exploratory _ RKB 68 feet 3. Address 7. Unit or Property name P. O. Box 100360 Stratigraphic _ Anchorage, AK 99510-0360 Service _ Prudhoe Bay Unit 4. Location of well at surface \ 8. Well number 592' FNL, 1684' FEL, SEC. 36, T11 N, R , EUM 02-31 At top of productive interval 9. Permit number / approval number 216' FNL, 2457' FEL, SEC. 36, T11N, R14E, UM 91-138 At effective depth 10. API number 211' FNL, 1960' FEL, SEC. 36, T11 N, R14E, U 50-029-22227 At total depth 11. Field /Pool 211' FNL, 1933' FEL, SEC. 36, T11 N, R14E, UM �` Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9525� t Plugs (measured) PBTD tagged @ 9449' MD (1/04/1999) true vertical 9123 f Effective depth: measured 9449 feet Junk (measured) true vertical 9052 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 118' 20' 28o Sx CS G 118, 118' Surface 34.47' 9-5/80 G 20 cubic ft C III & 348 cubic ft 3515► 3512' Production 8680' 7' 983 cubic ft Class - 8748' 8425' Liner 1071' S' 189 cubic ft Class G 9525' 9123' Perforation depth: measured 9348' - 9362'; 9376' - 9390'. true vertical 8958' - 8971'; 8984' - 8997'. - ~ Tubing (size, grade, and measured depth 4-1/20, 12.6#, L-80 Tubing @ 8439' MD. --..- Packers & SSSV (type 8 measured depth) 7' x 4-1/2' Baker S-3 Packer 0 8311' MD; 4-1/2' Camco -0 SLVN SSSV ® 2202' MD. 13. Attachments Description summary of proposal -( Detailed operations program -_ BOP sketch _C 14. Estimated date for commencing operation 15. Status of well classification as: March 15, 1999 Oil _C Gas _ Suspended _ 16. If proposal was verbally approved Name of approve Date approved I Service 17. 1 hereby foregoing I and correct to the best of my knowledge. Que 'ons? Call Stephen Ward ® 265-13o5. gcer"11the Title: Date Signed AAI Coil Tubing Drilling Supervisor Bruce E. Smith P.E. repred by Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity , BOP Test _ Location clearance _O Mechanical Integrity Test _ Subsequent form required 1G-- a Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/16/88 • SUBMIT IN TRIPLICATE PAUL RAUF i ARCO ALASKA INC. 015412452359 P- O. BOX 100360 ATO - 1509 ANCHORAGE, AK 99510-0360 bate Jo (! the r of (DFIRWCHICAGO The First National Bank of Chicago Chicago, Minds 60670 For��- ':0 7 10000 131: 90 C 68 5 Ills 1.03 2-ym0 i (Dollars 1)"In{Is In hn ck, NOT VALID FOR OVER $1000.00 0103 WELL PERMIT CHECKLIST COMPANY WELL NAME �',BG� 22-f, 3 PROGRAM: exp dev redrll �_ sery wellbore seg ann. disposal para req FIELD & POOL�s'o INIT CLASS L AREA i g 9� UNIT# ON/OFF SHORE _ yt, ADMINISTRATION 1. Permit fee attached . . . . . . . . . . . . . . . . . . . . . . . Y 2. Lease number appropriate . . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number ... . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool .. . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included .. . . . . . . . . . . . . . Y N 9. Operator only affected party .. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force . . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N R D TE 12. Permit can be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . N ENGINEERI 14. Conductor string provided . . . . . . . . . . . . . . . . . . . N 15. Surface casing protects all known USDWs. . . . . . . . . . . Y N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y_ N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N (D N N 20. Adequate tankage or reserve pit .. . . . . . . . . . . . . . . N _ 21. If a re -drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed .. . . . . . . . . . . . Y N CV N / 23. If diverter required, does it meet regulations . . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate . . . . . (D N 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . N APPR DATE 26. BOPE press rating appropriate; test to _3CC�)0 psig. 27. Choke manifold complies w/API RP-53 (May 84) . . . . . . . . N 00 N 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable .. . . . . . . . . . . . . . . 6a N C N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y N 31. Data presented on potential overpressure zones . . . . . . . Y 32. Seismic analysis of shallow gas zones . . . . . . . . . . . . . N APPR DATE 33. Seabed condition survey (if off -shore) . . . . . . . . . . . . . Y ��7 34. Contact name/phone for weekly progress reports (exploratory ly] Y N-� N ANNULAR DISPOSAL 35. With proper cementing reco s, this plan (A) will contain waste in a itable receiving zone; Y N APPR DATE (B) will not contaminate eshwater; or cause dri ' g waste . .. to surface; Y N (C) will not impair chanical integrity of th ell used for disposal; Y N (D) will not dam producing formation o impair recovery from a Y N ----- �- pool; a (E) will not circumvent 20 AAC 25.252 or 20 AAC .412. Y N GEOL ENGINEERING: UIC/AnnqI66r COMMISSION: RP Go 0 BEWg5,"e f Sk WM DWJ JDH--...- RNC CO; Comments/Instructions: c:\msoffice\wordian\diana\checklist 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. v Sperry -Sun Drilling Services LIS Scan Utility Sat Oct 02 16:45:15 1999 Reel Header Service name.............LISTPE Date .....................99/10/02 Origin...................STS � ��[� Reel Name ................ UNKNOWN - i Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date .....................99/10/02 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 2 AK-MW-90105 S. LATZ DAN KARA MWD RUN 8 AK-MW-90105 D. LABRECQUE LAMAR GANTT Scientific RECOVED r'r` 191999 AlAh Oil & Gas Cons. Commin D.S. 2-31A AnchoMe 500292222701 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 02-OCT-99 MWD RUN 4 AK-MW-90105 S. LATZ DAN KARA MWD RUN 9 AK-MW-90105 D. LABRECQUE LAMAR GANTT 36 11N 014 MWD RUN 7 AK-MW-90105 D. LABRECQUE LAMAR GANTT MWD RUN 10 AK-MW-90105 C. ZAWADZKI ANDY KIRK FNL: 592 FSL: FEL: 1684 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 68.00 DERRICK FLOOR: 68.00 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.625 3515.0 2ND STRING 7.000 8748.0 3RD STRING 5.000 9068.0 PRODUCTION STRING 3.625 11220.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB -SEA TRUE VERTICAL DEPTHS (SSTVD) . 3. MWD RUNS 1-4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR-SOLAR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 1 AND 3 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. MWD RUNS 7-10 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. THE CHANGE FROM DGR TO NGP PROBE OCCURS AT 91051MD, 8667'SSTVD. 5. DIGITAL MWD DATA IS SHIFTED TO THE PDC GR LOG OF 04/18/99 (MCNL) WITH KBE = 68'AMSL. THIS WELL KICKS OFF FROM 2-31A PEI AR 9105'MD, 8667'SSTVD. 6. MWD RUNS 2,4,7-10 REPRESENT WELL 02-31A WITH API#: 50-029-22227-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11220'MD, 8879'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED GAMMA RAY. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9048.5 11195.5 ROP 9070.5 11226.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 9048.5 9048.0 9072.5 9072.0 9078.5 9078.0 9114.0 9114.0 9118.0 9118.5 9129.0 9128.5 9140.0 9140.5 9142.0 9142.5 9274.5 9282.0 9283.0 9291.0 9286.0 9293.5 9289.0 9296.0 9292.5 9300.5 9299.5 9307.0 9309.5 9317.0 9313.5 9320.0 9315.5 9321.0 9329.0 9333.0 9333.0 9337.0 9335.5 9339.0 9345.5 9348.0 9354.5 9357.0 9358.0 9360.0 9360.5 9362.0 9367.5 9368.0 9374.5 9374.0 9378.5 9377.5 9389.5 9389.0 9392.0 9391.0 9398.0 9397.0 9406.5 9410.0 9408.0 9413.5 9411.0 9416.0 9414.0 9418.5 9426.0 9424.0 9431.0 9427.0 9432.5 9429.5 9452.5 9453.5 9455.0 9456.0 9457.5 9458.0 9461.0 9461.5 9465.0 9465.5 9499.5 9501.0 9507.5 9509.0 9512.0 9513.5 9515.5 9516.0 9534.5 9536.5 9539.0 9540.5 9542.5 9545.0 9563.5 9566.0 9567.5 9570.5 9570.5 9574.5 9594.5 9597.0 9597.0 9599.5 9600.0 9602.5 9614.0 9616.0 9619.0 9621.0 9629.0 9630.0 9635.0 9637.0 9640.0 9642.5 9652.0 9654.0 9657.5 9658.0 9661.0 9662.5 9666.0 9667.5 9701.5 9703.0 9736.5 9738.5 9929.5 9930.5 9978.5 9979.5 9991.5 9995.5 10030.0 10033.5 10046.5 10051.5 10073.5 10079.5 10120.5 10128.0 10127.0 10134.5 10149.0 10155.0 10171.0 10176.0 10210.5 10215.0 10212.5 10216.5 10226.5 10230.0 10241.0 10245.0 10256.5 10260.5 10258.5 10261.5 10268.0 10271.5 10271.0 10273.5 10279.5 10283.0 10310.0 10314.0 10326.0 10330.5 10337.5 10341.5 10347.0 10351.0 10355.5 10359.5 10359.5 10364.5 10373.0 10375.0 10378.5 10380.0 10383.5 10384.0 10395.5 10396.5 10404.0 10405.5 10409.0 10411.0 10413.5 10415.0 10422.0 10422.0 10440.0 10439.0 10463.5 10464.5 10467.0 10468.5 10487.0 10487.0 10491.0 10491.0 10500.0 10499.0 10521.5 10523.0 10530.0 10532.0 10536.0 10537.5 10555.0 10556.0 10562.5 10562.5 10620.5 10619.5 10637.0 10636.0 10713.0 10712.5 10750.0 10749.0 10774.5 10774.0 10788.0 10788.0 10799.5 10799.5 10801.5 10802.0 10825.5 10824.5 10828.5 10828.5 10889.5 10887.5 10901.0 10900.5 10905.0 10904.5 10933.0 10929.0 10948.5 10944.5 10956.5 10952.0 10966.5 10960.5 10968.5 10963.0 10970.0 10964.5 10978.0 10973.0 10992.5 10986.0 11226.5 11220.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 9070.0 9091.0 MWD 4 9091.0 9105.0 MWD 7 9105.0 9501.0 MWD 8 9501.0 9647.0 MWD 9 9647.0 10383.0 MWD 10 10383.0 11220.0 REMARKS: MERGED MAIN PASS. # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 .0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 9048.5 11226.5 10137.5 4357 9048.5 11226.5 ROP 0.35 1971.47 70.4327 4313 9070.5 11226.5 GR 10.9 199.53 77.5632 4295 9048.5 11195.5 First Reading For Entire File .......... 9048.5 Last Reading For Entire File ........... 11226.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9048.0 9065.0 ROP 9070.0 9091.0 LOG HEADER DATA DATE LOGGED: 05-APR-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: PCG 5.74, PCD 3.O1E, DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9091.0 TOP LOG INTERVAL (FT): 9070.0 BOTTOM LOG INTERVAL (FT): 9091.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 78653 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.630 DRILLER'S CASING DEPTH (FT): 3.6 BOREHOLE CONDITIONS MUD TYPE: FORMATION WATER MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S) : .0 MUD PH: .0 MUD CHLORIDES (PPM): 12 FLUID LOSS (C3) : .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 138.0 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): .3 EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 9048 9091 9069.5 87 9048 9091 GR 12.56 15.17 14.0731 35 9048 9065 ROP 0.35 672.1 62.8472 43 9070 9091 First Reading For Entire File .......... 9048 Last Reading For Entire File ........... 9091 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9065.5 9105.0 ROP 9091.0 9105.0 LOG HEADER DATA DATE LOGGED: SOFTWARE 06-APR-99 SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: PCG 5.74, PCD 3.O1E, DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9105.0 TOP LOG INTERVAL (FT): 9091.0 BOTTOM LOG INTERVAL (FT): 9105.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 78653 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 3.630 DRILLER'S CASING DEPTH (FT): 3.6 BOREHOLE CONDITIONS MUD TYPE: SF FLO-PRO LITE MUD DENSITY (LB/G) : 8.60 MUD VISCOSITY (S) : .0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 27000 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 120.0 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): .3 EWR FREQUENCY (HZ) : REMARKS: # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 9065.5 9105 9085.25 80 9065.5 9105 GR 10.9 86.05 20.191 80 9065.5 9105 ROP 4.86 50.11 35.8317 29 9091 9105 First Reading For Entire File .......... 9065.5 Last Reading For Entire File ........... 9105 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9105.5 9470.0 ROP 9105.5 9501.0 # LOG HEADER DATA DATE LOGGED: 10-APR-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) REMARKS: PCG 5.74, PCD 3.01E, MEMORY 9501.0 9105.0 9501.0 9131.6 9454.0 TOOL NUMBER PCG 8 3.630 3.6 FLO-PRO 8.70 .0 9.0 22000 7.2 .000 .000 .000 .000 .3 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 133.0 GR MWD 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 9105.5 9501 9303.25 792 9105.5 9501 GR 16.53 134.92 29.3328 730 9105.5 9470 ROP 0.35 235.58 37.6967 792 9105.5 9501 First Reading For Entire File .......... 9105.5 Last Reading For Entire File ........... 9501 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9470.5 9616.0 ROP 9501.5 9647.0 LOG HEADER DATA DATE LOGGED: 11-APR-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: PCG 5.74, PCD 3.O1E, DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MEMORY 9647.0 9501.0 9647.0 77.9 88.7 TOOL NUMBER PCG 72 3.630 3.6 FLO-PRO 8.70 .0 9.0 22000 7.0 .000 .000 .000 .000 .3 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 API 4 1 68 .4 2 138.0 ROP MWD 8 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 9470.5 9647 9558.75 354 9470.5 9647 GR 28.3 185.69 87.6549 292 9470.5 9616 ROP 4.45 211.25 35.5606 292 9501.5 9647 First Reading For Entire File .......... 9470.5 Last Reading For Entire File ........... 9647 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9616.5 10352.0 ROP 9647.5 10383.0 LOG HEADER DATA DATE LOGGED: 13-APR-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: PCG 5.74, PCD 3.O1E, DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS ( C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 10383.0 9647.0 10383.0 84.7 96.7 TOOL NUMBER 3.630 3.6 FLO-PRO 8.60 .0 8.0 14000 7.4 .000 .000 .000 .000 .3 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 API 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 142.0 First Last Name Min Max Mean Nsam Reading Reading DEPT 9616.5 10383 9999.75 1534 9616.5 10383 GR 29.51 171.84 87.5378 1472 9616.5 10352 ROP 3.75 1971.47 85.4312 1472 9647.5 10383 First Reading For Entire File .......... 9616.5 Last Reading For Entire File ........... 10383 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10352.5 11189.0 ROP 10383.5 11220.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE ( MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : 15-APR-99 INSITE 3.2 PCG 5.74, PCD 3.O1E, MEMORY 11220.0 10383.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 11220.0 82.7 96.8 TOOL NUMBER 3.630 3.6 FLO-PRO 8.60 .0 8.3 14000 7.8 .000 .000 .000 .000 .3 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 API 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 154.0 First Last Name Min Max Mean Nsam Reading Reading DEPT 10352.5 11220 10786.2 1736 10352.5 11220 GR 45.66 199.53 91.888 1674 10352.5 11189 ROP 2.69 1340.18 79.8096 1674 10383.5 11220 First Reading For Entire File .......... 10352.5 Last Reading For Entire File ........... 11220 File Trailer Service name.............STSLIB.007 Service Sub Level -Name... version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name.............LISTPE Date .....................99/10/02 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date .....................99/10/02 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry -Sun Drilling Services LIS Scan Utility Sat Oct 02 14:20:05 1999 Reel Header Service name.............LISTPE Date .....................99/10/02 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. Technical Services Tape Header Service name.............LISTPE Date .....................99/10/02 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library. Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 2 AK-MW-90105 S. LATZ DAN KARA MWD RUN 6 AK-MW-90105 S. LATZ DAN KARA 19 9 Scientific Scientific RECEIVED 0 i 17 19 1999 AWft l6 COT!$, GwPM D.S. 2-31A PB1 500292222770 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 02-OCT-99 MWD RUN 4 AK-MW-90105 S. LATZ DAN KARA 36 11N 14E MWD RUN 5 AK-MW-90105 S. LATZ DAN KARA FNL: 592 FSL: FEL: 1684 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 68.00 DERRICK FLOOR: 68.00 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.625 3515.0 2ND STRING 7.000 8748.0 3RD STRING 5.000 9068.0 PRODUCTION STRING 3.625 9316.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR-SOLAR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 1 AND 3 MADE NO FOOTAGE AND ARE NOT PRESENTED. 3. MWD RUNS 5, 6 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP ) UTILIZING A SCINTILLATION DETECTOR. THE CHANGE FROM DGR TO NGP PROBE OCCURS AT 9125'MD, 8684'TVDSS. 4. DIGITAL MWD DATA IS SHIFTED TO THE PDC GR LOG OF 04/18/99 (MCNL) WITH KBE = 68'AMSL. 5. MWD RUNS 2,4,5-6, REPRESENT WELL 02-31APB1 WITH API## : 50-029-22227-70 . THIS WELL REACHED A TOTAL DEPTH (TD) OF 9316'MD, 8846'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED GAMMA RAY. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9048.0 9290.0 ROP 9070.0 9317.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9048.0 9048.0 9056.5 9056.5 9064.0 9064.0 9065.5 9065.5 9072.0 9072.0 9078.5 9078.0 9089.0 9088.5 9092.0 9091.0 9317.5 9316.5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 9070.0 4 9091.0 5 9154.0 6 9222.0 REMARKS: MERGED MAIN PASS. MERGE BASE 9091.0 9154.0 9222.0 9316.0 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 9048 9317.5 9182.75 540 9048 9317.5 ROP 0.35 2082.37 79.5141 496 9070 9317.5 GR 10.9 317.67 30.2699 485 9048 9290 First Reading For Entire File .......... 9048 Last Reading For Entire File ........... 9317.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9048.0 9065.0 ROP 9070.0 9091.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 05-APR-99 INSITE 3.2 PCG 5.74, PCD 3.01E, MEMORY 9091.0 9070.0 9091.0 26.7 26.7 TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 78653 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.630 DRILLER'S CASING DEPTH (FT): 3.6 BOREHOLE CONDITIONS MUD TYPE: FORMATION WATER MUD DENSITY (LB/G) : 8.50 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 12 FLUID LOSS (C3) : .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 152.0 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): .3 EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 9048 9091 9069.5 87 9048 9091 GR 12.56 15.17 14.0731 35 9048 9065 ROP 0.35 672.1 62.8472 43 9070 9091 First Reading For Entire File .......... 9048 Last Reading For Entire File ........... 9091 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9065.5 9124.5 ROP 9091.0 9154.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 06-APR-99 INSITE 3.2 PCG 5.74, PCD 3.O1E, MEMORY 9154.0 9091.0 9154.0 27.8 41.9 TOOL NUMBER SOLAR GM 78653 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 3.630 3.6 SF FLO-PRO LITE 8.60 .0 9.0 27000 8.0 .000 .000 120.0 .000 .000 .3 # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9065.5 9154 9109.75 178 9065.5 GR 10.9 140.21 27.317 119 9065.5 ROP 4.86 235.58 39.5539 127 9091 First Reading For Entire File .......... 9065.5 Last Reading 9154 9124.5 9154 Last Reading For Entire File ........... 9154 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9125.0 9191.0 ROP 9154.5 9221.5 LOG HEADER DATA DATE LOGGED: 07-APR-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: PCG 5.74, PCD 3.01E, DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9222.0 TOP LOG INTERVAL (FT) : 9154.0 BOTTOM LOG INTERVAL (FT): 9222.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 33.1 MAXIMUM ANGLE: 33.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE PCG 8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.630 DRILLER' S CASING DEPTH (FT) : 3.6 BOREHOLE CONDITIONS MUD TYPE: FLO-PRO MUD DENSITY (LB/G) : 8.50 MUD VISCOSITY (S) : .0 MUD PH: 8.5 MUD CHLORIDES (PPM) : 27000 FLUID LOSS (C3): 7.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): .3 EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 130.0 First Last Name Min Max Mean Nsam Reading Reading DEPT 9125 9221.5 9173.25 194 9125 9221.5 GR 16.13 100.92 22.6778 133 9125 9191 ROP 32.42 85.75 61.9129 135 9154.5 9221.5 First Reading For Entire File .......... 9125 Last Reading For Entire File ........... 9221.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9191.5 9289.0 ROP 9223.5 9316.5 LOG HEADER DATA DATE LOGGED: 08-APR-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: PCG 5.74, PCD 3.01E, DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9316.0 TOP LOG INTERVAL (FT): 9222.0 BOTTOM LOG INTERVAL (FT): 9316.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 20.6 MAXIMUM ANGLE: 48.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE PCG 72 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 3.630 DRILLER'S CASING DEPTH (FT): 3.6 BOREHOLE CONDITIONS MUD TYPE: FLO-PRO MUD DENSITY (LB/G) : 8.60 MUD VISCOSITY (S) : .0 MUD PH: 8.5 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): 7.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): .3 EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 133.0 First Last Name Min Max Mean Nsam Reading Reading DEPT 9191.5 9316.5 9254 251 9191.5 9316.5 GR 17.4 317.67 40.2683 196 9191.5 9289 ROP 4.74 2082.37 123.704 187 9223.5 9316.5 First Reading For Entire File .......... 9191.5 Last Reading For Entire File ........... 9316.5 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/02 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name.............LISTPE Date .....................99/10/02 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Technical Services Reel Trailer Service name.............LISTPE Date .....................99/10/02 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Writing Library Technical Services Physical EOF Physical EOF End Of LIS File Scientific Scientific