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Home My WebLink About181-1021a. 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 10/2/1981 50-029-20625-00-00 PBU 14-14 181-102 12277' / 9413' PRUDHOE BAY, PRUDHOE OIL ADL 0028311 , 0028312 77-04312327' / 9454' N/Aapprox ~1900' N/A 0 4/2/2023 N/A 10/21/81 ASP-4 ASP-4 ASP-4 5939060 5937989 5937697 675429 681657 682021 DIL/SP/BHCS/GR,FDL/CNL/GR/Cal. GR/Cal. GR/CBL, CBL/VDL/GR/CCL 2804' FNL 5048 FEL Sec.11, T10N, R14E, UM 2503' FNL 125' FEL Sec.10, T10N, R 14E, UM 1285' FNL 1044 FEL Sec.9, T10N, R14E, UM 20"94#H-40 Surface 110'Surface 110'32"300sx Permafrost 13-3/8"72#L-80 Surface 2632'Surface 2620'17-1/2" 2500 sx Fondu & 400 sx ASII 9-5/8"47#L-80 Surface 11358'Surface 8668' 12-1/4"500sx Class G 7" 29#L-80 11085'12322'8448'9450'8-1/2"350sx Class G 5-1/2" 17# L-80 11095'11073 , 11730 / 8439 , 8968 See attachment 26. 11512' - 11552' 8793' - 8825' 11557' - 11567' 8829' - 8837' 11570' - 11588' 8839' - 8854' 11602' - 11640' 8865' - 8895' 11650' - 11670' 8903' - 8919' 11680' - 11690' 8927' - 8936' 11690' - 11710' 8936' - 8952' 11752' - 11770' 8986' - 9000' 11774' - 11802' 9003' - 9025' 11806' - 11834' 9029' - 9051' N/A N/A surface 71' 322-240 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 3:20 pm, Apr 25, 2023 Abandoned 4/2/23 JSb RBDMS JSB 051623 xGMGR08AUG2023DSR-5/22/23 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 4/20/2023 Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 Top Sadlerochit Base Sadlerochit 11509' 12237' 8790' 9379' Ivishak Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.04.21 08:57:06 -08'00' FULL ABANDONMENT - ALL CSG STRINGS AND CONDUCTOR CEMENTED TO SURFACE AND CUT 6' BELOW TUNDRA ELEVATION (04/01/23) WELL NAME: 14-14 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used Surface -Control Line Pump 2.5 gallons of FINECEM to 2500 psi Surface -Balance Line Pump 2.5 gallons of FINECEM to 700 psi ~11203' - 11730' Pump 42bbls of 14ppg Class G 10911' AOGCC witnessed Tag TOC Tubing punches 10943' - 10946' Tbg / IA Pump 515 bbls of14.0 ppg Class G cement 9728' AOGCC witnessed Tag TOC Tbg / IA punches 2622' - 2632' Tbg / IA punches 1800' - 1810' ~1800' Tbg /IA Pump 187 bbls of 15.8 ppg Class G 1259'- Surface CTU Lay in 36 bbls of 15.8 ppg Class G OA Pump 4.5 bbls of 15.6 ppg perma-frost blend to 1000 psi OA top job ACTIVITYDATE SUMMARY 8/25/2022 ***WELL S/I ON ARRIVAL*** RAN 2 1/2'' GR WITHOUT GS DOGS TO TOP OF PLUG @11119'SLM EQALIZE PLUG GOOD RING ON PRONG *** CONTINUE ON 8-26-22 WSR*** 8/26/2022 *** CONTINUE FROM 8-25-22 WSR*** RAN 2 1/2'' GS TO 11119'SLM PULLED XX-PLUG RAN 2.0 CENT W/ 1.75 SAMPLE BAILER TAG @ 11786'SLM, 11844'MD, HAD 3 CUPS OF FILL *** WELL LEFT SHUT IN ON DEPARTURE, DSO NOTIFIED OF STATUS*** 8/29/2022 T/I/O = SSV/0/0. Temp = SI. Injectivity test on C& B lines (pre cement). Pumped 2.5 gallons down control line @ 4800 psi, bled to 0 psi. Pumped 2.5 gallons down balance line @ 4250 psi, bled to 0 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 9/8/2022 T/I/O = SSV/10/30. Temp = SI. Cement C & B lines (P&A). Pumped 2.5 gallons of FINECEM cement down control line @ 2500 psi. Pumped 2.5 gallons of FINECEM cement down balance line @ 700 psi. Tags hung on both lines. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:00 9/15/2022 T/I/O = SSV/10/30. Temp = SI. MIT C&B lines (P&A). Pressured BL to 2500 psi w/ hyd. Pressure held 2500 psi after second attempt. Bled to 0 psi. Pressured CL to 2500 psi w/ hyd. Bled to 0 psi. FWHP's = SSV/10/30. SV, WV, SSV = C. MV = O. IA & OA = OTG. 14:30. 9/24/2022 T/I/O = 1480/6/24 (P&A) Injection Test 5 bpm at 720 psi, Loaded Tbg with 5 bbl 60/40, 401 bbls SW and 58 bbls Diesel for FP. FWHP's = vac/vac/400 10/18/2022 T/I/O= 1500/0/0 (PLUG AND ABANDONMENT) Reservoir Plug. Pumped 1 bbl 60/40 to tank, Pumped 10 bbls 60/40 Down TBG.Cement Wet @ 11:15am. 10bbl FW ahead. Pumped 42bbls of 14ppg class G, 5bbl FW behind and launch 5" foam ball, displace with 254 bbls diesel. Est TOC~11203'. RDMO **Job complete** 11/1/2022 ***WELL S/I ON ARRIVAL*** (plug & abandonment) TAGGED TOC @ 10896' SLM (10911' MD) w/ 1.91" CENT & 1.75" SAMPLE BAILER (good cement sample in bailer, state witnessed) DRIFT TBG TO SSSV NIP @ 2114 SLM (2129' MD per caliper report) w/ 4.65" G- RING FOR CORRECTION ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 11/3/2022 ***WELL SHUT IN ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP TS= 1 7/16" CHD (1" FN), 2" WEIGHT, 1 11/16" WEIGHT, CCL, DE-CENTRALIZER, MAGNET, PUNCHER LOADED 3' (19 SHOTS) CORRELATE DOWN PASS TO TUBING TALLY DATED 1/4/1992 CORRELATE UP PASS TO COLLARS ON DOWN PASS. TBG PUNCH 10,943'- 10,946' (2' BELOW COLLAR @ 10,941') CCL OFFSET=6.8', PUNCH DEPTH=10,943'-10,946', CCL STOP DEPTH=10,936.2' TBG PRESSURE INCREASED FROM 400PSI TO 1000PSI AFTER FIRING. GOOD INDICATION OF TxIA COMMUNICATION. ***JOB COMPLETE / FULLBORE UP NEXT*** Daily Report of Well Operations PBU 14-14 TBG PUNCH 10,943'- 10,946' (2' BELOW COLLAR @ 10,941 Pumped 2.5 gallons of FINECEM cement down control line @ 2500 psi. (g TAGGED TOC @ 10896' SLM (10911' MD) w/ state witnessed () @ Pumped 42bbls of 14ppg class G, 5bbl FW behind and launch 5" foam ball,g displace with 254 bbls diesel. Est TOC~11203'. RDMO Daily Report of Well Operations PBU 14-14 11/13/2022 T/I/O= 916/0/0 P and A (Injectivity test) Pumped 16 bbls Diesel down TBG w/returns up IA to open top. Established an injection rate of 5 bpm @ 1370 psi. Notify DSO. 11/14/2022 T/I/O = 961/100/0 (P&A) Assist HES Cement. Pumped 0.5 bbls 60/40 to fluid pack HES lines. Spear into TBG with 7 bbls 60/40. *** Job continued to 11-15-2022 *** 11/14/2022 Scope -Fullbore P&A Cement- Cement Tbg & IA. Spot cement pump truck and bulk silos. Spot Vac trucks and RU hardline. PJSM with HES and support crews. Pressure test lines. Pump cement job per approved progam. Pump 515 bbls of 14.0 ppg Class G cement. Displaced with 198 bbls of Water & 9.8 NACL brine follwed by 4 bbls of 60/40, Total 227 bbls of displacement. Estimeated 20 bbls of 13.0 ppg class G to surface Shut down & shut in well. Close Casing Valve with Flag & Tag. Close SSV acum blocked at panel. Tbg FP with 9.8 ppg brine and 4 bbls of 60/40. Final SITP 1760 psi. Line up surface lines for cement clean up. Freeze protect remaining surface lines with 60/40. Estimated top of cement in Tbg at 9,779'. End Job 11/15/2022 *** Job continued from 11-14-2022 *** Assist Cement. Pumped 4 bbls 60/40 into surface lines for Freeze Protect. Pumped 9 bbls 60/40 to FP choke skid and all surface lines to both Open top tanks. Cementers incontrol of well upon departure. FWHP's = 1760/100/0 11/22/2022 T/I/O= 0/0/0 Temp= SI MIT T Pumped 3.5 bbls DSL down TBG to reach test pressure of 2750/0/0 1st 15 min TBG lost 50 psi 2nd 15 min TBG lost 0 psi for a ***PASSING*** MIT T Tags Hung DSO notified of well status upon departure 11/26/2022 T/I/O= 45/0/0. LRS 72 Assist Slickline (PLUG AND ABANDONMENT) AOGCC (Kam St John) MIT-T to 2500 psi PASSED at 2585 psi (2730 psi max applied pressure). TBG lost 108 psi during the firsr 15 minutes and 37 psi during the second 15 minutes. TBG lost 145 psi during the 30 minute test. Pumped 1.9 bbls of 87*F diesel to achieve test pressure. Bled back 1.9 bbls to Final T/I/O= 47/0/0. 11/26/2022 ***WELL S/I ON ARRIVAL*** DRIFT TUBING TO SSSV NIP @ 2111'SLM (2129'MD per calliper report) W/ 4.65'' G- RING FOR CORRECTION (+18' correction) LRS PERFORMED PASSING STATE WITNESSED MIT-T (see lrs log) TAGGED TOC @ 9710'SLM/9728'MD W/ 2-1/2'' SAMPLE BAILER (good cement sample, state witnessed) ***WELL LEFT S/I ON DEPARTURE*** JOB COMPLETE 11/29/2022 ***WELL SHUT IN ON ARRIVAL*** PRESSURE TEST PCE 200#LP-3,000#HP RIH W/ 1 7/16" CHD (1" FN), 3 1/8" CCL, 3 3/8" PERF GUN (LOADED W/10' 22.7 GRAM SUPER DEEP PENENTRATING CHARGES, 6 SPF, 60 DEG PHASING) CCL OFFSET=4.3', PERF DEPTH=2,622'-2,632', CCL STOP DEPTH=2,617.7' PUMPING DOWN TBG W/ TRIPLEX FOR 5 MIN WITH PUMP PRESSURE AT 1,300 PSI & T/I/0=600/0/0, SWAP OVER TO PUMP DOWN OA, PUMP 5 MIN W/ PUMP PRESSURE AT 900 PSI, T/I/O=250/0/0, START TO SEE INCREASE ON OA, PUMP 5 MIN W/ PUMP PRESSURE AT 1,300 PSI, T/I/O=250/0/500 ***WELL LEFT SHUT IN*** TAGGED TOC @ 9710' MIT T Pumped 3.5 bbls DSL down TBG to reach test pressure of 2750/0/0 1st 15 min TBG lost 50 psi 2nd 15 min TBG lost 0 psi for a ***PASSING*** MIT T Tags ()( MIT-T to 2500 psi PASSED at 2585 psi (2730 psi max applied pressure). ERF DEPTH=2,622'-2,632', Pump 515 bbls of 14.0 ppg Classjg g G cement. Displaced with 198 bbls of Water & 9.8 NACL brine follwed by 4 bbls of 60/40, Total 227 bbls of displacement. 0, START TO SEE INCREASE ON OA, Daily Report of Well Operations PBU 14-14 12/11/2022 T/I/O= VAC/0/603 Prove TxOA communication ( P & A ) Pump 4.5 bbls 60/40 down tbg to catch pressure. Pumped add'l 5.5 bbls @ 1.2 bpm @ 860 psi. OA showed no communication. Pumped 0.75 bbls 60/40 down OA. OA pressured up to 1005 psi & fell off to 998 psi in 5 mins FWHPs=30/0/603 12/20/2022 ***WELL S/I ON ARRIVAL*** CORRELATE TO TUBING TALLY DATED: 4-JAN-1992. PUNCH HOLES FROM 1800-1810' MD WITH 22.7 GRAM BASIX, 6 SPF, 60 DEGREE PHASED. CCL STOP DEPTH=1792.2' MD, CCL TO TS=7.8', PUNCH INTERVAL=1800-1810' MD. LRS ESTABLISHES GOOD CIRCULATION DOWN TUBING AND UP OA TO FLOWBACK TANK.(see lrs report) ***WELL LEFT S/I, DSO NOTIFIED*** 12/20/2022 Assist E-Line. Pump 45 bbls crude downTBG taking returns up the OA to tanks to establish injectivity rate. (See Log) 12/29/2022 T/I/O= 0/0/0. LRS 72 Assist P&A-In Progress (PLUG AND ABANDONMENT). Pumped 8 bbls of 60/40 MeOH into the TBG to get OA returns to OTT. Pumped 25 bbls of 140*F diesel at 2 bpm into the TBG with OA returns. Pumped 160 bbls of 9.8 Brine at 4.8 bpm into the TBG with 4.4 bpm OA returns to OTT. Pumped 187 bbls of 15.8ppg class G cement and did not get clean cement to surface (40bbls over total volume). Decision made to displace cement in tubing with hopes of getting clean cement to surface and having future options to complete P&A. After ~18bbls of 60/40 pumped into the tubing, cement returns were observed. Continued to pump 60/40 down TBG for 30 bbls. Clean cement was observed from OA. TOC in TBG ~1293'. TOC in OA=surface. RDMO. 1/2/2023 T/I/O = SSV/0/0. Temp = SI. Strap OA cement (P&A). Flowlines & S riser disconected. Strapped top of cement @ 52'. Final WHP's = SSV/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 1/9/2023 T/I/O=0/0/0. P&A. RD 5x7 calico upper tree assembly and installed 5x7 crown valve as dryhole tree. Torqued flanges to spce. ***Job Complete*** Final WHP's 0/0/0. 2/1/2023 LRS CTU #2 - 1.50" Blue Coil Job Objective: P&A MIRU CTU. Perform Weekly BOP test. ***Continue on 2/2/23*** 2/2/2023 LRS CTU #2 - 1.50" Blue Coil Job Objective: P&A Complete BOP test. Make up LRS 2.25" BDJSN BHA & RIH. Tag TOC at 1259' ctm. Pump & lay in 36bbls of 15.8ppg class 'G' from 1259' to surface. Pump 4.5bbls of 15.6ppg perma-frost blend cement into OA and pessure up to 1000psi. Notified DSO of well status. RDMO. ***Job Complete*** 3/24/2023 ***P&A In Progress*** Pad Elevation = 45'. Tundra Elevation = 36'. Excavation Depth = 4'. Dig excavation to approximately 8'. LDFN. 3/25/2023 ***P&A In Progress*** Pad Elevation = 45'. Tundra Elevation = 36'. Excavation Depth = 8'. Dig excavation to approximately 10'. Pin on the arm of the excavator broke, unable to repair onsite. Cover excavation with rig mates and LDFN. 3/28/2023 ***P&A In Progress*** Pad Elevation = 45'. Tundra Elevation = 36'. Excavation Depth = 10'. Dig excavation to approximately 15'. LDFN. 3/29/2023 ***P&A In Progress*** Pad Elevation = 45'. Tundra Elevation = 36'. Excavation Depth = 15'. Dig excavation to approximately 16'. Clean out hole and install shoring box. LDFN. GOOD CIRCULATION DOWN TUBING AND UP OA j BOP test. Make up LRS 2.25" BDJSN BHA & RIH. Tag TOC at 1259' ctm.g Pump & lay in 36bbls of 15.8ppg class 'G' from 1259' to surface. Pump 4.5bbls ofyg 15.6ppg perma-frost blend cement into OA and pessure up to 1000psi. Notified DSOg of well status. RDMO. Daily Report of Well Operations PBU 14-14 3/30/2023 ***P&A In Progress*** Pad Elevation = 45'. Tundra Elevation = 36'. Excavation Depth = 16'. Conduct confined space permit meeting. Set Goliath saw. Cut well head 6' below tundra eleveation. LDFN. 3/31/2023 ***P&A In Progress*** Pad Elevation = 45'. Tundra Elevation = 36'. Excavation Depth = 16'. Clean up cut to make level for welders. Put heater on to thaw ice in conductor to prep for top job on conductor and IA void. AOGCC notified for inspection. LDFN. 4/1/2023 ***P&A In Progress*** Pad Elevation = 45'. Tundra Elevation = 36'. Excavation Depth = 16'. Perfrom top job on 26" deep void in conductor, and3"x3"x 26" deep void in IA void. Inspected by AOGCC (passed) LDFN. 4/2/2023 Pad Elevation = 45'. Tundra Elevation = 36'. Excavation Depth = 16'. Weld on top plate, pull shoring box, back fill and deliniate hole. ***JOB COMPLETE*** 2023-0401_Surface_Abandon_PBU_14-14_bn Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 4/5/2023 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector PBU 14-14 Hilcorp North Slope, LLC PTD 1811020; Sundry 322-240 4/1/2023: I traveled to Hilcorp’s PBU 14-14 for surface abandonment inspection. I met with Hilcorp representative Cody Applehans. We looked at the well and found the top of the pipe cut off at 6 feet below tundra level, with all strings having cement. The 20-inch conductor had been topped off with cement that needed more time to harden. I told Cody I would look at it in the early morning on my way to another job and let him know if I approved. The outer most pipe string is 20-inch and the marker plate is 20 inches by ¼-inch thick. I verified the marker plate had all the correct marking from the Sundry. 4/2/2023: I stopped at PBU 14-14 on my way to another inspection and found all cement was good and hard. I told Cody Applehans ok to weld the marker plate on and back fill. Attachments: Photos (2)     2023-0401_Surface_Abandon_PBU_14-14_bn Page 2 of 2 Surface Abandonment – PBU 14-14 (PTD 1811020) Photos by AOGCC Inspector B. Noble 4/1/2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 9 Township: 10N Range: 14E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 12322 ft MD Lease No.: ADL0028311 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 13-3/8" O.D. Shoe@ 2632 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 9-5/8" O.D. Shoe@ 11358 Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 12322 Feet Csg Cut@ Feet Tubing: 5-1/2" X 4-1/2" O.D. Tail@ 11740 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 10911 ft 9728 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2730 2622 2855 IA 0 0 0 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Jerry Culpepper Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Had a good tag at 9728 ft MD and got a good sample. MIT held good. 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Price Digitally signed by Jeremy M. Price Date: 2022.05.02 11:58:49 -08'00' RBDMS SJC 050422 WΘ ϭϰͲϭϰ Wd͗ϭϴϭͲϭϬϮ tĞůůEĂŵĞ͗ϭϰͲϭϰ W/EƵŵďĞƌ͗ϱϬϬϮϵϮϬϲϮϱϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ŚƵƚ/Ŷ ZŝŐ͗/ŶƚĞƌǀĞŶƚŝŽŶƐ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϲͲϭͲϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϳĂǇƐ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌƌŝĞ:ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϭͲϭϬϮ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶdŚŽŵƉƐŽŶ ϵϬϳͲϱϲϰͲϱϮϴϬͬϵϬϳͲϯϬϭͲϭϮϰϬ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ ϵϬϳͲϱϲϰͲϰϲϳϮͬϵϬϳͲϰϰϬͲϬϯϯϭ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϯϯϳϲƉƐŝΛϴ͕ϴϬϬ͛dsϳ͘ϰWW'ͮ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ϮϰϵϲƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚ͘ŐĂƐŐƌĂĚŝĞŶƚͿ >ĂƐƚ^/t,W͗ϬƉƐŝ ;dĂŬĞŶŽŶϯͬϯϭͬϭϬͿ DŝŶ/͗Ϯ͘ϯϭ͟/Λϭϭϭϳϳ͛ DĂǆŶŐůĞ͗ϱϯΣĞŐΛϲϰϬϬ͛D ,d͗ϭϴϬΣ& ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ ϭϰͲϭϰŝƐĂWt/ǁĞůůĚƌŝůůĞĚŝŶϭϵϴϭĂŶĚůĂƐƚŝŶũĞĐƚĞĚŝŶϮϬϬϲ͘dŚĞǁĞůůĐƵƌƌĞŶƚůǇŚĂƐďŽƚŚĂWůĞĂŬĂŶĚŚŽůĞƐŝŶ ƚŚĞƚƵďŝŶŐΘŚŽůĚƐůŝƚƚůĞǀĂůƵĞĨŽƌŝŶũĞĐƚŝŽŶĂƚ&^ϯ͘dŚĞǁĞůůŝƐĐƵƌƌĞŶƚůǇĐůĂƐƐŝĨŝĞĚĂƐŶŽƚʹŽƉĞƌĂďůĞ͘dŚĞWůĞĂŬ ǁĂƐŝĚĞŶƚŝĨŝĞĚΛϵϵϬϯ͛ďǇĂϮϬϭϬ>>͘DƵůƚŝƉůĞƚƵďŝŶŐůĞĂŬƐŝĚĞŶƚŝĨŝĞĚŝŶϮϬϭϬ;ϰϵϬ͛ΘϭϭϬϬϮ͛Ϳ͘ƵƌŝŶŐĚƌŝůůŝŶŐ ƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐǁĂƐĐĞŵĞŶƚĞĚƚŽƐƵƌĨĂĐĞǁͬϮϬϬйĐĞŵĞŶƚǀŽůƵŵĞ͘ĂůĐƵůĂƚĞĚƚŽƉŽĨĐĞŵĞŶƚďĞŚŝŶĚƚŚĞϵ ϱͬϴ͟ƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐŝƐϵ͕ϱϯϬ͛D͘ KďũĞĐƚŝǀĞ͗ dŚĞŝŶƚĞŶƚŽĨƚŚŝƐƉƌŽŐƌĂŵŝƐƚŽƉĞƌĨŽƌŵĂĨƵůůWΘŽĨƚŚĞǁĞůů ƉĞƌϮϬϮϱ͘ϭϭϮ͘tĞǁŝůůĞǆĐĂǀĂƚĞĂŶĚĐƵƚ ĐĂƐŝŶŐƐϯ͛ďĞůŽǁƚŚĞŽƌŝŐŝŶĂůƚƵŶĚƌĂůĞǀĞůĂŶĚŝŶƐƚĂůůĂŵĂƌŬĞƌƉůĂƚĞ͘ ŽƉĞƌĨŽƌŵĂĨƵůůWΘŽĨƚŚĞǁĞůů WΘ ϭϰͲϭϰ Wd͗ϭϴϭͲϭϬϮ ϭ͘ ^ůŝĐŬůŝŶĞ Ă͘ WƵůůϮϳͬϴ͟yyƉůƵŐΛϭϭϭϳϳ͛ ď͘ ƌŝĨƚƚŽWd Ϯ͘ ^ƉĞĐŝĂůWƌŽũĞĐƚƐ Ă͘ ĞŵĞŶƚĐŽŶƚƌŽůͬďĂůĂŶĐĞůŝŶĞƐƚŽƐƵƌĨĂĐĞ͘ ϯ͘ , Ă͘ tĂŝƚŽŶĐĞŵĞŶƚϯĚĂǇƐ͕D/dĐŽŶƚƌŽůĂŶĚďĂůĂŶĐĞůŝŶĞƐƚŽϮϱϬϬƉƐŝ͘ ď͘ WĞƌĨŽƌŵ/&>ƐŚŽƚ͘ ϰ͘ &ƵůůďŽƌĞ Ă͘ WƵŵƉ/ŶũĞĐƚŝǀŝƚǇdĞƐƚ͕ƵůůŚĞĂĚŝŶƚŽƌĞƐĞƌǀŽŝƌ͘ x ϱďďůƐDĞK, x ϰϭϱďďůƐϭй<>Žƌ^t x &ƌĞĞǌĞƉƌŽƚĞĐƚǁͬϱϴďďůƐĚŝĞƐĞů x DĂǆƉƌĞƐƐƵƌĞϮϱϬϬƉƐŝ ΎΎΎEŽƚĞǁŝƚŚƚŚĞϱЪ͟ƉĂƚĐŚĂϳ͟ďĂůůƐŚŽƵůĚǁŽƌŬďƵƚĐŽŶƐŝĚĞƌƵƐŝŶŐĂϱ͟ďĂůůŝĨƚŚĞϮ͘ϴϭϯ͟ƉĂƚĐŚƌĞƐƚƌŝĐƚŝŽŶŝƐ ŽĨĐŽŶĐĞƌŶΎΎΎ ď͘ WƵŵƉZĞƐĞƌǀŽŝƌďĂŶĚŽŶŵĞŶƚƉůƵŐ͕dKŝƐƉůĂŶŶĞĚĂƚΕϭϭ͕ϮϬϬ͛DũƵƐƚďĞůŽǁƚŚĞϰЪ͟ƚƵďŝŶŐƚĂŝů͘ ƵůůŚĞĂĚŝŶƚŽƚŚĞƌĞƐĞƌǀŽŝƌĂƐĨŽůůŽǁƐ͗ x ϱďďůƐDĞK, x ϭϬďďůƐĨƌĞƐŚǁĂƚĞƌ x ϰϮďďůƐϭϰƉƉŐĐůĂƐƐ'ĐĞŵĞŶƚ x ϱďďůƐĨƌĞƐŚǁĂƚĞƌ x &ŽĂŵĂůů x ϮϱϰďďůƐĚŝĞƐĞůĚŝƐƉůĂĐĞŵĞŶƚ x DĂǆƉƌĞƐƐƵƌĞϮϱϬϬƉƐŝ ΎΎΎEŽƚĞǁĞǁŝůůďĞƵŶĂďůĞƚŽƉƌĞƐƐƵƌĞƚĞƐƚƚŚĞƌĞƐĞƌǀŽŝƌĂďĂŶĚŽŶŵĞŶƚƉůƵŐĚƵĞƚŽƚŚĞƚƵďŝŶŐŚŽůĞƐĂŶĚƚŚĞ ŬŶŽǁŶWůĞĂŬ͘D/d͛ƐŚĂǀĞĨĂŝůĞĚƐŝŶĐĞϮϬϭϬ͘ ϱ͘^ůŝĐŬůŝŶĞ Ă͘ tĂŝƚŽŶĐĞŵĞŶƚϯĚĂǇƐ͘ƌŝĨƚĂŶĚƚĂŐƚŽdKΕϭϭ͕ϮϬϬ͛ʹK'tŝƚŶĞƐƐĞĚ ď͘ WƵŶĐŚƚƵďŝŶŐǁŝƚŚϱĨƚŽĨƚƵďŝŶŐƉƵŶĐŚĞƐΛΕϭϭ͕Ϭϱϱ͛ŽƌϳϱĨƚĂďŽǀĞdKŝŶƐŝĚĞƚŚĞϱͲϭͬϮ͟ƚƵďŝŶŐ͕ ǁŚŝĐŚĞǀĞƌŝƐŚŝŐŚĞƌ͘ ϲ͘ &ƵůůďŽƌĞ Ă͘ ZŝŐƵƉƚŽďĞĂďůĞƚŽƉƵŵƉĚŽǁŶƚŚĞƚƵďŝŶŐĂŶĚƚĂŬĞƌĞƚƵƌŶƐĨƌ ŽŵƚŚĞ/͘ ď͘ WƵŵƉƚŚĞĨŽůůŽǁŝŶŐƚŽǀĞƌŝĨǇdΘ/ĐŽŵŵƵŶŝĐĂƚŝŽŶ x ϱďďůƐDĞK, x ϱϬďďůƐĚŝĞƐĞů x DĂǆƉƌĞƐƐƵƌĞǁŚŝůĞƉƵŵƉŝŶŐϮϱϬϬƉƐŝ͘ WΘ ϭϰͲϭϰ Wd͗ϭϴϭͲϭϬϮ Đ͘ WƵŵƉƚŚĞĨŽůůŽǁŝŶŐĐĞŵĞŶƚƉůƵŐ͗ x ϱďďůƐDĞK,;ĂƐƌĞƋƵŝƌĞĚͿ x ϳϱďďůƐŽĨŚŽƚĨƌĞƐŚǁĂƚĞƌ;ΕϭϲϬĚĞŐ&ͿнƐƵƌĨĂĐƚĂŶƚ;ϮŐĂůͬŵŐĂů&ϭϬϯĂŶĚϮŐĂůͬŵŐĂůhKϲϳͿ x ϭϬďďůƐĨƌĞƐŚǁĂƚĞƌ x ϱϯϬďďůƐϭϰƉƉŐůĂƐƐ'ĐĞŵĞŶƚ;ΕϮϮďďůƐŽǀĞƌĐĂůĐƵůĂƚĞĚǀŽůƵŵĞͿ͘ x ϱďďůƐĨƌĞƐŚǁĂƚĞƌ x &ŽĂŵĂůů x ϮϮϳďďůƐϵ͘ϴƉƉŐďƌŝŶĞ x ϱďďůƐϲϬͬϰϬĨŽƌĨƌĞĞǌĞƉƌŽƚĞĐƚ x DĂǆƉƌĞƐƐƵƌĞǁŚŝůĞƉƵŵƉŝŶŐϮϱϬϬƉƐŝ͘ x ŽŶĨŝƌŵĐĞŵĞŶƚĂƚƐƵƌĨĂĐĞŝŶ/͘ x ĞŵĞŶƚƉůƵŐŝŶƚŚĞ/ǁŝůůďĞĨƌŽŵdƵďŝŶŐWƵŶĐŚĞƐƚŽƐƵƌĨĂĐĞ͘ x ĞŵĞŶƚƉůƵŐŝŶƚŚĞƚƵďŝŶŐǁŝůůďĞĨƌŽŵdƵďŝŶŐWƵŶĐŚĞƐƚŽΕϭϬϬϬϬ͛D͘ ϳ͘ &ƵůůďŽƌĞ Ă͘ tĂŝƚŽŶĐĞŵĞŶƚϯĚĂǇƐ͕D/dͲdƚŽϮϱϬϬƉƐŝʹK'tŝƚŶĞƐƐĞĚ ϴ͘^ůŝĐŬůŝŶĞ Ă͘ ƌŝĨƚĂŶĚƚĂŐƚŽdKŝŶƐŝĚĞƚŚĞϰЪ͟ƚƵďŝŶŐ͕ΕϭϬ͕ϬϬϬ͛ĞǆƉĞĐƚĞĚdKʹK'tŝƚŶĞƐƐĞĚ ϵ͘ ůŝŶĞ Ă͘ WĞƌĨŽƌĂƚĞϱЪ͟ƚƵďŝŶŐĂŶĚƚŚĞϵϱͬϴ͟ĐĂƐŝŶŐĂƚΕϮϲϭϮ͛ʹϮϲϯϮ͛DƚŽĞƐƚĂďůŝƐŚĐŝƌĐƵůĂƚŝŽŶƉŽŝŶƚĂŶĚ ƌĞŵŽǀĞŚǇĚƌŽĐĂƌďŽŶƐĨƌŽŵƚŚĞϭϯϯͬϴ͟ǆϵϱͬϴ͟ĂŶŶƵůƵƐĂŶĚĐŝƌĐƵůĂƚĞŝŶĐĞŵĞŶƚƉůƵŐ͘ ϭϬ͘ &ƵůůďŽƌĞ Ă͘ ZŝŐƵƉƚŽĐŝƌĐƵůĂƚĞĚŽǁŶƚŚĞƚƵďŝŶŐĂŶĚƚĂŬĞƌĞƚƵƌŶƐĨƌŽŵƚŚĞϭϯϯͬϴ͟ǆϵϱͬϴ͟ĂŶŶƵůƵƐ;KͿ͘ ď͘ ŝƌĐƵůĂƚĞƚŚĞĨŽůůŽǁŝŶŐƚŽĐůĞĂŶŽƵƚŚǇĚƌŽĐĂƌďŽŶƐĨƌŽŵƚŚĞĂŶ ŶƵůƵƐ͘;ƌĐƚŝĐWĂĐŬŝƐƉƌĞƐĞŶƚͿ x ϱďďůƐDĞK, x ϮϱďďůƐŚŽƚĚŝĞƐĞů;ŵŝŶϭϮϬĚĞŐ&Ϳ x ϱϬďďůƐŽĨŚŽƚĨƌĞƐŚǁĂƚĞƌ;ΕϭϲϬĚĞŐ&ͿнƐƵƌĨĂĐƚĂŶƚ;ϮŐĂůͬŵŐĂů&ϭϬϯĂŶĚϮŐĂůͬŵŐĂůhKϲϳͿ x ϮϯϬďďůƐŽĨϵ͘ϴƉƉŐďƌŝŶĞ;ϴϬͲϭϬϬĚĞŐ&Ϳ Đ͘ ŝƌĐƵůĂƚĞƚŚĞĨŽůůŽǁŝŶŐƚŽĐĞŵĞŶƚƉůƵŐƚŽĐĞŵĞŶƚƚŚĞϭϯϯͬϴ͟ǆϵϱͬϴ͟ĂŶŶƵůƵƐĂŶĚƚƵďŝŶŐƚŽ ƐƵƌĨĂĐĞ͘ x ϱďďůƐDĞK, x ϭϬďďůƐĨƌĞƐŚǁĂƚĞƌ x ϮϯϬďďůƐŽĨϭϱ͘ϴƉƉŐůĂƐƐ'ĐĞŵĞŶƚ;ϭϲďďůƐĞǆĐĞƐƐͿ͘ x DĂǆƉƌĞƐƐƵƌĞϭϱϬϬƉƐŝ ϭϭ͘ , Ă͘ ƐƐŝƐƚ&ƵůůďŽƌĞǁŝƚŚĐĞŵĞŶƚũŽďĂŶĚƉƵŵƉEϮĂĐƌŽƐƐƚŚĞǁĞůůŚĞĂĚƚŽƌĞŵŽǀĞĞǆĐĞƐƐĐĞŵĞŶƚĨƌŽŵ ƚŚĞǀĂůǀĞƐ͘dŚŝƐǁŝůůĂůůŽǁǀĂůǀĞƐƚŽďĞŽƉĞŶĞĚƉƌŝŽƌƚŽƚŚĞǁĞůůŚĞĂĚƌĞŵŽǀĂůƚŽĐŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞ͘ ď͘ ůĞĞĚĂůůǁĞůůŚĞĂĚƉƌĞƐƐƵƌĞƐƚŽϬƉƐŝ͘ Đ͘ DŽŶŝƚŽƌǁĞůůŚĞĂĚƉƌĞƐƐƵƌĞƐϮϰŚŽƵƌƐĂĨƚĞƌƉƌĞƐƐƵƌĞƐǁĞƌĞďůĞĚƚŽϬƉƐŝ͘ ^ƉĞĐŝĂůWƌŽũĞĐƚƐ WΘ ϭϰͲϭϰ Wd͗ϭϴϭͲϭϬϮ Ă͘ ǆĐĂǀĂƚĞĂŶĚƵƚŽĨĨĂůůĐĂƐŝŶŐƐĂŶĚǁĞůůŚĞĂĚϯ͛ďĞůŽǁŽƌŝŐŝŶ ĂůƚƵŶĚƌĂůĞǀĞů͘dŽƉũŽďƚŚĞĐŽŶĚƵĐƚŽƌ ǆϭϯϯͬϴ͟ĂŶŶƵůƵƐ͕ĂůůŽƚŚĞƌĂŶŶƵůŝĂŶĚƚƵďŝŶŐǁŝƚŚĐĞŵĞŶƚĂƐŶ ĞĞĚĞĚ͘WŚŽƚŽĚŽĐƵŵĞŶƚĐĞŵĞŶƚŝŶ ĂůůƚƵďŝŶŐĂŶĚĂůůĐĂƐŝŶŐƐƚƌŝŶŐƐ͘ ď͘K'ǁŝƚŶĞƐƐĐĞŵĞŶƚƚŽƉƐŝŶĂůůĂŶŶƵůŝĂŶĚŝŶƐƚĂůůĂƚŝŽŶŽĨŵĂƌŬĞƌĐĂƉŽŶŽƵƚĞƌŵŽƐƚĐĂƐŝŶŐƐƚƌŝŶŐ͘ WƌŽǀŝĚĞϮϰŚŽƵƌŶŽƚŝĐĞƚŽK'/ŶƐƉĞĐƚŽƌŽĨƚŚĞƚŝŵŝŶŐŽĨƚŚĞǁĞůĚŝŶŐŽĨƚŚĞŵĂƌŬĞƌƉůĂƚĞŽŶƚŽ ƚŚĞĐĂƐŝŶŐƐƚƌŝŶŐ͘WŚŽƚŽĚŽĐƵŵĞŶƚǁĞůĚĞĚŵĂƌŬĞƌƉůĂƚĞ͘ Đ͘ ĞĂĚǁĞůĚŵĂƌŬĞƌĐĂƉŽŶŽƵƚĞƌŵŽƐƚĐĂƐŝŶŐƐƚƌŝŶŐ;ŽŶĚƵĐƚŽƌWŝƉĞͿƚŽƌĞĂĚĂƐĨŽůůŽǁƐ͗ ,ŝůĐŽƌƉEŽƌƚŚ^ůŽƉĞ>> WdηϭϴϭͲϭϬϮ WhϭϰͲϭϰ W/ηϱϬͲϬϮϵͲϮϬϲϮϱͲϬϬ WΘ ϭϰͲϭϰ Wd͗ϭϴϭͲϭϬϮ ƵƌƌĞŶƚ^ĐŚĞŵĂƚŝĐ WΘ ϭϰͲϭϰ Wd͗ϭϴϭͲϭϬϮ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ WΘ ϭϰͲϭϰ Wd͗ϭϴϭͲϭϬϮ sŽůƵŵĞĂůĐƵůĂƚŝŽŶƐ WΘ ϭϰͲϭϰ Wd͗ϭϴϭͲϭϬϮ dƵďŝŶŐdĂůůǇ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 9 Township: 10N Range: 14E Meridian: Umiat Drilling Rig: N/A Rig Elevation: N/A Total Depth: 12322 ft MD Lease No.: ADL0028311 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 13-3/8" O.D. Shoe@ 2632 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 9-5/8" O.D. Shoe@ 11358 Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 12322 Feet Csg Cut@ Feet Tubing: 5-1/2" X 4-1/2" O.D. Tail@ 11740 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bottom 11844 ft 10911 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Pre-existing plug back TD = 12277 ft MD. Procedure called for top of cement (TOC) at 11200 ft MD; tagged 289 ft high with wireline bailer - returned good cement sample (photos). Puts cement above the tubing punch for next cement plug. Hilcorp will determine next step in consult with AOGCC engineer. Did a second run for depth correction check using the known depth of SSSV nipple (2114 ft); uncorrected caliper report shows SSSV nipple at 2129 ft for a 15-foot correction; applied to the TOC tag depth. No MIT on this plug diue to uphole leaks noted in approved procedure. November 1, 2022 Kam StJohn Well Bore Plug & Abandonment PBU 14-14 Hilcorp North Slope PTD 1811020; Sundry 322-240 Photos (2) Test Data: Casing Removal: Matt Ross Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-1101_Plug_Verification_PBU_14-14_ksj 9 9 9 9 9 9 9 9 9 9 9 9 tagged 289 ft high good cement sample p() cement above the tubing punch for next cement plug. gg pp ( ) No MIT on this plug James B. Regg Digitally signed by James B. Regg Date: 2023.04.06 15:15:30 -08'00' BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 ,,, ~4`~~~ ti1Al~ ~; ~Q~ 5 ~1l )~6 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, by a: -. __. ~- L~EC .~ ~ ~Q~19 ~. ~~,~ `~ L~`"~~f Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 n~*e• ~~~n~mo Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-o1A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-06A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-096 1820340 500292053402 Sealed Conductor NA NA 1a-1o 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA t4-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 1a-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20!2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 t4-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA t4-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 t4-4oA 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24!2009 • • ~~ ~ ~~ ~~ ~ ~1 L..~ ~ ~~ LI- ~ ~ SARAH PAL/N, GOVERNOR ~+ oi~ra-78iA OII, Al~TD GA$ 333 W. 7th AVENUE, SUITE 100 CO~-7~RQAilO1` COrIIrIISSIOI~~ ANCHORAGE,ALASfCA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Katrina Cooper East Waterflood Team Leader BP Exploration Alaska, Inc. ~~~ ~ ~ 2~0~ PO Box 196612 ~'{`'=~ ~~' Anchorage, AK 99519-6612 , A . ~`' ~! ...~e»~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, P1~iJ J14-14 Sundry Number: 307-361 Dear Mr. Cooper: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel eamount Commissioner DATED this ~ day of December, 2007 Encl. ~,~, ,~ ~~ ~~ ~ ~a ~~zr~~~3 STATE OF ALASKA ~~ J'C3 ~~~ ~ ~ ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRO '~~ ~~~ ~ Gay ~:t~s~~;, ~~omm~ssion 20 AAC 25.280 ~~~§'tts~~~~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ^ Othe Alter casing^ Repair well Q Plug Perforations^ Stimulate ^ Time Extension ^ SEAL TITE Change approved program[] Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmeni^ Exploratory ^ 181-1020 ' 3. Address: P.O. Box 196612 Stratigraphic^ Service 0 6. API Number: Anchorage, AK 99519-6612 50-029-20625-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 14-14 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028312 ~ 71 KB PRUDHOE BAY Field / PRUDHOE BAY Pool i l . PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12320 9454 12277 9412.35 11177 NONE Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 30 110 30 110 1530 520 Surface 2603 13-3/8"72# L-80 29 2632 29 2620 4930 2670 Production 11330 9-5/8" 47# L-80 28 11358 28 8668 6870 4760 Liner 1237 7"29# L-80 11085 12322 8448.08 9449 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# L-80 42 - 11095 - - 4-1/2" 12.6# L-80 11095 - 11190 - - 4-1/2" 12.6# 9-CR-80 11730 - 11740 Packers and SSSV Type: 5-1 /2" BAKER D PACKER Packers and SSSV MD (ft): 11073 4-1/2" OTIS TWD Packer 11730 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ~] Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: i2i11/2007 OIL ^ GAS ^ PLUGGED ~ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Katrina Cooper Printed Name Katrina Coo per Title East Waterflood Team Leader / Signature G t,,.~r-z mac-, Phone 564-4212 Date 11/27/2007 COMMISSION USE ONLY ' ~ ~~LJ { Conditions of a roval: Notif ion witn Sund Number Commis o th t a r re ent tive ma . pp y y ry s s a ep s a ess Plug Integrity [~ BOP Test ^ Mechanical Integrity Test ~~ Location Clearance ^ 1 ` 1 Other: NO~~`{~+'^S~e.G~OC- O~-©p~O~l~l~~l 'C~ ~~~.~V~. Qj'C~S~C'~.S W~\\~ S~l~\-`~ `C l v 1S Cv~tit~~, Subsequent Form Required: ~~1,.~ a'? QtF~- ~,~~f ~} c~ p ° 2007 APPROVED BY ~Z~~ Approved by: COMMISSION THE COMMISSION Date: Form 10-403 Revised 06/2006 J ~ ~ ~ 1 ~~ a ~ Submit in Duplicate r w ~ • • 14-14 181-102 Perforations Attachment Perforation Depth MD (ft) Opn/Sqz Perforation Depth TVD (ft) 1 1 51 2-1 1 552 Opn 8792-8824 1 1 557-1 1 567 Opn 8828-8836 1 1 570-1 1 588 Opn 8839-8853 1 1 602-1 1 640 Opn 8865-8895 1 1 650-1 1 670 Opn 8903-8919 1 1 680-1 1 71 0 Opn 8927-8951 1 1 752-1 1 770 Opn 8985-9000 1 1 774-1 1 802 Opn 9003-9026 1 1 806-1 1 834 Opn 9028-9051 by To: C. Olsen / J. Bixby Well Operations Team Leaders From: Katrina Cooper PBU Production Engineer DeWayne R. Schnorr Design Engineer • Date: November 26, 2007 Est. Cost: $100K Cost Code: PBD14WL14-N IOR: 300 Subject: 14-14i: Sealtite Repair - IA x OA communication Type Procedure S Pull TTP, Drift w/ 5-1/2" Dummy Patch, Run Nipple Reducer with TTP. E Punch 5-1/2" tubing. Set 5-1/2" Carbon Steel Weatherford straddle w/ sliding sleeve. F Circulate brine and diesel, pump Sealtite treatment and cycle squeeze. S Pull TTP. Shift sliding sleeve closed (wait 3 days for treatment to cure) F MIT-IA to 2400 psi (Determine LLR if MIT-IA fails) Current Status: PW I -Not Operable, TTP set @ 11177' (08/16/2006) Max Deviation: 53° @ 6400' MD Min ID: 3.725° @ 11738' - 4-1/2" X Nipple, also note - 5-1/2" XN Nipple @ 11049' is 4.45". Last Tag: 08/06/2003 Tagged TD @ 11806', IPPROF survey Last DH Op: 04/29/2007 -Ran TecWeli LDL & found leak at 580' in IA. Latest H2S Value: N/A, water injection well Leak Rate: LLR --- 1.0 gpm (10/01/2006), LLR = 0.3 gpm during TecWel LDL (05/08/07). PROBLEM DESCRIPTION: The objective of this procedure is to restore mechanical integrity to a confirmed leak in the production casing. This will be done by sealing leak (LLR = 0.30 gpm) in 9-5/8" Production Casing at 5~- with Sealtite's sealant. This technique has been performed successfully on two Kuparuk injectors by Conoco Phillips. These two jobs have lasted over one year. If this job is successful, it will open up more candidates for this promising technique and a $3.2 million workover will be avoided. The procedure consists of punching the 5-1/2" tubing (the well does not have GLM's), so that brine can be circulated down 5-1/2" tubing and back up IA. A 5-1/2" Weatherford straddle with sliding sleeve will be set across puncher holes in the 5-1/2" tubing. This will allow the well to be retreated if necessary. A recent caliper indicates the 5-1/2" tubing is in excellent condition. Sealtite sealant will be then be displaced to the leak with diesel, down IA, and then squeezed to seal the leak. After the sealant has cured, the sliding sleeve will be shifted closed and the IA will be pressure tested before bringing the back on water injection. The sliding sleeve has been ordered from Lyle Savage and should be available in a few days. C~ If you have questions or concerns regarding this program, please contact Jennifer Julian at 564- 5663(w), 274-0929(h) or 240-$037(c); or Katrina Cooper at 564-4212(w), 279-2667(h) or 230- 4212(c) with any questions or comments. cc: w/a: Well File • Objective: Run Weatherford straddle with Weathe ord sliding sleeve (well does not have GLM's}, so shallow production casing leak at 4' ELMD can be repaired with Sealtite sealant. ~~ PAC-~~nQ~.r Slickline --- Pull TTP, Run Nipple Reducer w/ TTP 1a~~ 1. MIRU SL. Pull TTP. Note: No restriction found @ 11010', PDS Caliper (10/20/06) 2. Run 5-1/2" Dummy Patch to just above 5-1/2" x 4-1/2" XO. Note: Otis XN Nipple ID = 4.45" @ 11049' MD. 3. Run 2.812" Nipple Reducer w/ TTP installed. Note: ID of 3-1/2" Weatherford sliding sleeve is 2.812". E-line --- Punch tubing and set straddle 4. Tie into (TecWel LDL 04/28/2007 -log attached) and perforate 2' below collar of first full tubing joint above XN Nipple with tubing punchers, loaded 4 spf at 11006'-11008'. 5. Pump with triplex to ensure tubing has been punched. 6. RIH with 5-1/2" Weatherford lower packer and tie into XN Nipple @ 11049'. Set lower packer @ 11012'. 7. RIH with upper packer and slickstick, including Weatherford sliding sleeve, stab into lower packer and set upper packer @ 10097'. From element to element the patch should be 15'. Ensure straddle has been drifted with the TTP that is in the nipple reducer in the well and make sure sliding sleeve is in the open position. Actual depths will be based on length of Weatherford straddle. At this time it is estimated to be about 15'. The tubing caliper indicates that the tubing is in excellent condition, so setting depth is not critical, just want to make sure that tubing punchers holes are covered! Fullbore and SealTite Pumping Operation 8. SealTite Pumping Procedure is attached. Slickline (Post SealTite treatment) 9. Pull TTP. 10. Shift sliding sleeve closed. Slickline may consider adding a knuckle joint in their toolstring to accommodate the fact that part of the tool string will be inside the smaller ID and the upper portion will be inside the 5-1/2" tubing. Fullbore (Post SealTite treatment) 11. MIT-IA to 2400 psi. Establish LLR if patch fails. • Seal-Tite International Advanced Sealant Technology Proposed Procedure BP Alaska, 14-14i Casing Leak Repair November 28, 2007 Seal-Tit® Intematiorr 500 Deer Cross Drive Madisonville, LA 7044i' Telephone: 985-875-129 F acsi m i I e: 985-875-068 http://www. seal-tite. net Objectives Repair IA/OA Communication and restore IA Integrity using Seal-Tite Sealants and Proceures Mechanical Considerations This well has an apparent leak in the 9 5/8" production casing, identified via a TecWel log at +- 579'. The recorded liquid leak rate from previous diagnostics is 0.3 gpm at 2300 psi. - The production casing is 9 5/8" 47 #/ft L80 - The production tubing is 5 %2" 17#/ft, capacity to packer = 255 bbls - IA volume is .0438 bbl/ft, +- 482 bbls to the tubing punch holes at 11,006', +- 485 bbls to the packer. - IA volume to leak location at 580' is 25.4 bbs - IA fluid is assumed to be a mixture of brine and diesel Given the large volume to the leak location, it will be best to circulate the IA volume to brine and then spot the sealant across the leak location. The basic steps of the procedure will be as follows: - Install a sliding sleeve tubing patch just above the packer - Circulate the IA to 10 ppg brine (or brine required for freeze protect). - Inject sealant pill into IA - Displace sealant pill to leak location with diesel - Squeeze sealant into leak - Close tubing patch sliding sleeve and return well to service. Repair Procedure 1. Meet with field personnel; travel to location and verify well condition. 2. Perform Job Safety Analysis with all concerned personnel. 3. Take pressure readings as follows: - Tubing - IA - OA 4. Locate the test port for the intermediate casing hanger void area. Rig up pressure relief tool with gauge and bleeder valve to the test port. Record void pressure and compare with • • adjacent casing pressures. Bleed off any trapped pressure to zero. Monitor for pressure build up in the void during the remaining procedure. (Note: Well history shows that the IC hanger was tested OK on 11/8/2006, this is suggested as a precaution only to ensure that no fluid bypass occurs during the procedure.) 5. Place holes in the tubing just above the packer per BP Procedure. 6. Install a sliding sleeve packoff across the tubing punch holes per BP Procedure. 7. RU pump to be able to pump down tubing or IA with choke manifold to take brine returns from tubing back to tank. 8. Circulate down tubing and up IA with inhibited 10.0 ppg CaCl2 per PE manual guidelines so as not to cut out the sliding sleeve. (Note: 10.0 CaCl2 has a rated freeze point of -8 F 9. Continue circulating until entire tubing and annulus are full of 10.0 CaCl2. Capacity of tubing is +/- 255 bbls. Capacity of annulus is +/- 482 bbls. Total capacity +/- 737 bbls. 10. Pressure tubing and IA to 3000 psi. Obtain a base line pressure fall off and confirm estimated leak rate and fluid compression values. 11. Blend 4 bbls Flo-Seal to a weight of 9.5 ppg or +/- 0.5 ppg less than weight of selected brine. 12. RU pump to IA and line up choke manifold to take brine returns from tubing back to tank. 13. Pump sealant into IA, taking returns from tubing 14. Displace sealant down IA with 16.8 bbls diesel, taking returns up tubing. Note: Total displacement to leak @ 580' is 25.4 bbls. Compression of fluid below leak is 1.7 bbls/1000 psi. Compression of fluid in tubing is 0.9 bbls/1000 psi. Compression of diesel above sealant is 0.1 bbl/1000 psi. Therefore the above displacement volume will put the bottom of sealant as follows: - 4.3 bbls above the leak at 0 pressure - 0.7 bbl above the leak at 1500 psi - 3.9 bbl below the leak at 3000 psi (if all compression achieved through IA displacement. 15. Close choke on tubing and continue to pump diesel until the IA is pressured up to 1500 psi. This should put bottom of sealant approximately 0.5 bbls above the leak location. 16. Monitor IA pressure, tubing pressure and OA returns as sealant moves down annulus toward leak. Bump up IA pressure as required to maintain 1500 psi. 17. Once a seal is established at 1500 psi (no further returns on OA), allow to cure for 30 minutes. 18. Increase IA pressure to 2000 psi. Monitor for OA returns. Allow seal to cure for 1 hour. • 19. Increase IA pressure to 2500 psi. Monitor for OA returns. Allow seal to cure for 1 hour. ' 20. R/U pump to tubing. Increase tubing/IA pressure to 3000 psi. Monitor for OA returns. Allow seal to cure for 12 hours. Monitor for OA returns. Allow seal to cure for 12 hours or overnight. Record data for IA integrity test records. 21. Bleed fluid from tubing to reduce IA pressure to 2000 psi and lock in. Allow seal to cure for 3 days. 22. Close sliding sleeve 23. Bleed IA as required to prepare well for operations. 24. Return well to service. DNC 11/28/07 CRAY GEN 2 WELLHEAD = GRAY ACTLIA'OR = AxELSf?N KB. F1EV = T1 BF. Ei B/ KOP = x.30()' N~,x Angie = 53 ,~ 64~J;J o~„f,-,m = tis1~;~ Da1un N U = BBO~ SS Minimum Id ~ 3.725'" ~ 1173' 4112" OTIS XN NIPPLE T~'Of ~' Lt~t 11~ ' TAG, 1711, i-iSO..fl232 i~pf. iD ~ 4.892' 11~ TC3P'Gf 4-ta2 TBG H 11~ 4-ii2" TBG. 12.x, L-8f?..0152Cpf, N~ ~ 3~~i8" 11 9-B~@3' t~G_ 4]#_ L-~'7. i9 ~+ 8 i" i i P1D1'L'-Sc *'"`P'W 19+IJECTiJM ~l.Y"' 2~ip S~1l2" t3i'f1S R43d sS.SV N!P CJ # 4S6° 11073' fi ~-' x 5-i!r SAx~ o PK 1109~i` 5-112° X 4-1>2" XC3 11177` 4-it2' c~'ns x N>~, ~ ~ 3.81• 11177 A-1F2° PX FLLIG {i1B116fD6~ 11t9t1' 4-112" TL~itJG TAl 1116'6° 1~3~TTL 03It7193 PEAT3ON RY REF LQC BtiCSf3t1 1021,131 ANGLEAT T{~ PERP: 3$ 1 i5i 2' NcXe: R~er to Praaiuation DS far tria4oriCSl Pori data S~2E SirF NfERVAI Gprf DATE 3-1.x' 4 11512- 11552 fi 04113.83 3-i.~' 4 tiS57- i 1567 ~; 041i3E33 3-145" 4 11570- 11598 ~ 07112,82 3-i,~E" 4 116132- i 1644) C 4ll/i2+H2 3-1,i5" 4 1165(3- i 167£7 t'. C~7112A62 3-1~" 4 ii680-ii840 C 44113183 3-1 r$" 4 11690- 11710 C 471122 3-3eB" 1 11752- 11770 L i2125J91 NA 2 i i774 - 11&02 t; 12x27191 2 11846- 11834 ~ 12124/91 ~ . ,.. ~ .. ~ ~ - r 11730"` 7" X 4112°' OTiS T1A~ FER3~AkNf3+lT PKR 11736' 4-112" t3T5S 3(N !'; 43 m 3.72" 4-iJ7' fiBG, 126#. 9-tai-~D..0152 C~pF. ~7r ~ 3.$" 11740' 117+40' A-1J2" TLS TAL 1174Z` ~k4.7 TT tt)C,G,tD a311aa93 ~ 7° Ltd. 298, L-8E3, .4371 t>[tf, 50 $ 6.184 {kITE FSEN BY DATE REJ BY S 1426181 I~GYiAL &dr3P'LET30N 10J191E36 „BdGRsAG S~FY NOT£ Et11T 14' Q1182 LAST WOitKAY~t 4331102 t.hUTf' C3NS 4225A7C3 WANE/tSAPEiY NOTE 08d16A6 RGT!°'TLSi PX PLUG SEB 1Qt39~6 SKEJTLH WAIUERSPTY NOTE' i ~ l -- . ! TecWel LDL 04/28/2007 --- Reference Lo 9 _.~ j ~ ~--=~~ -- i __ . - __ .` t ._-. , i F ; - -- --- - - ~ _ _.j___~-. -~ ---~-- - --- ._. t i ~ _ .. _ I , - t ;_a .~ .. j -~ _ - '..-r- _ i ..__ i- ~ i ` , .1 ~ •' ~ ~ ~_ i - - - - -- -------- - 10097' t tooo .._._ . Straddle w/ SS ~ Tubing puncher holes 11006'-11008' , ~ (2' below tubing joint) 11012' _~ --- - 4 ` ~ ~ '~ , - - - i . - ~ _ -+-~---+ ~ r •Z I 1 - 1 ~ ~ ----r--- i ~ -• . } XN Ni le 11049' ~ '~ ~ 4 RTemperoture -- t ~ I D = 4 45" npereture -~- .}~ . ~ -- ------- - - I s~ . - ~l# ~ D~Herentlal Temperature -~-~`--.,, ` - - f ~ _,_,~ i ----- I i _ ~`"~ ~ 1 T5 to t 85 ~ ~ •-~ Temperature Scale Change - ~ -- ~ ~ J 185 to t 95 _ t,__. CCI. ~ I`. . ~ . _ ~-- -~-- - - -' t t t 00 ~ -- ~ --- - - - -- - - - f ..: ... :. tti--- Heed Tension ~ ~, `~°;, : T • , ~ ~ f i -t~ -- - .-;- - ~ _ - - - ~ ' ~'+ ~ i e .1 WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs andjorTubing Inspection(Caliper / MITJ 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 : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AI< 99518 Fax: (907) 245-8952 1) 2) 3) 4] 5] 6] 7] EDE Disk OS. 14-14 Leak Detect - WLD 24-ApNJ7 &~ MAY· 2 2 2.007 U-~j1rI-IOd- #-ISf~ f. ~." .~, _4,~!''''''-'_''---'''' RECErVED Print Name: ~¿i ()/h (\ s+í l4~ I ]/l...~ f4/iI k P 11 MAY 2 1 Z007 Signed: Date,;iiæka Oil &. Gas CaR¡ CQmmissior; i~nC~~ PROACTIVE DIAGNOSTIC SERVICES, INc., 130 W. INTERNATIONAL AIRPORT RD SUITE C. ANCHORAGE, AK 99518 PHoNE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: W1¡WV.MEMORYLOG.COM D:\Master _Copy _ 00 _PDSANC-2OxxIZ_ WordlDistnòution\Transmitt,,'- Sheets\TransrniU:>riginal.doc . . BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 bp RECEIVEO OCT 1 3 2006 October 06, 2006 Alaska Oil & Gas Cons. Commission Anchorage Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: 14-14 (PTD 1811020) Application for Cancellation of Sundry #300-199 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 300-199 for Prudhoe Bay well 14-14. Purpose of this request is to cancel sundry requirements for continued water injection with slow TxlA communication. Recent pressure tests suggest that the source of the failed MIT -IA may be a slow production casing or packer leak. The well will continue to be evaluated. An application for Administrative Approval will be submitted with the results of further diagnostic testing if it is desired to restore the well to injection. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. ;¡::CA- Ilk Anna Dube. Well Integrity Coordinator k.::'CIIi..',"', Me:" 'u nc"'" ~~, fJ 2r}f1~~ ~"n~'tf~~_,,' tJ~, J ~. U....LiU Attachments: Application for Sundry Cancellation form 10-404 1. Operations Performed: -þ.ncnorage I AbandonD Repair WellD Plug PerforationsD Stimulate 0 Other!&] 1 0-403 Cane Alter CasingD Pull TubingO Perforate New PoolO WaiverD Time ExtensionD Change Approved programŒ:) Operation ShutdownO Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 181-102 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceŒ 50-029·20625-00-00 7. KB Elevation (ft): 9. Well Name and Number: 71.00 14-14 8. Property Designation: 10. Field/Pool(s): ADL-028311 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 12327 feet true vertical 9454.0 feet Plugs (measured) 4-1/2" PX Plug set @ 11177 (08/16/2006) Effective Depth measured 12277 feet Junk (measured) None true vertical 9408.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 91.5# H·40 47 · 157 47.0 . 157.0 1490 470 SURFACE 2586 13·3/8" 72# L·80 46 · 2632 46.0 - 2632.0 4930 2670 PRODUCTION 11313 9-5/8" 47# L-80 45 · 11358 45.0 - 9087.0 6870 4760 LINER 1237 7" 29# L-80 11085 - 12322 8881.0 - 9449.0 8160 7020 Perforation depth: Measured depth: 11512-11552,11557-11567,11570-11588, 11602-11640, 11650-11670, 11680-11710, 11752-11770, 11774-11802,11806-11834 True vertical depth: 8792-8824,8828·8836,8839-8853,8865-8895, 8903-8919, 8927-8951, 8985·9000, 9003-9026, 9028-9051 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 42 · 11095 4·1/2" 12.6# L-80 @ 11095 · 11190 4-1/2" 12.6# 9Cr80 @ 11730 · 11740 Isolation Tubing Assembly Packers & SSSV (type & measured depth): 9·5/8" Baker D packer @ 11073 7" Otis TWD Permanent PKR @ 11730 5-1/2" Otis RQM SSSV Nipple @ 2210 12. Stimulation or cement squeeze summary: Intervals treated (measured): " Treatment descriptions induding volumes used and final pressure: 13 Representative Dailv Average Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -- -- -- .- 20 Subsequent to operation: - - --. -- 47 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒJ Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilD GasD WAG 0 GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Anna Dube 300-199 Printed Name AnnlWDube A Title Well Integrity Coordinator Signature ,.C></AA11 rô &--J..t~ I J) Phone 659·5102 Date 1 0/6/06 .:.. = .~-T~ -.- -n- T Form 10-404 Revised 4/2004 U 1-\ \ tJ \\\J J-\ L RBDMS 8fl OCT 1 7 2006 . RECENED STATE OF ALASKA I' ALASKA Oil AND GAS CONSERVATION COMMI SION OCT 1 3 2006 REPORT OF SUNDRY WELL OPERAIIQ~is Cons. Commission 14-14 (PTD #1811020) Internal Waiver Can¡tion - Trouble Well All, An internal waiver was issued for a slow TxlA communication on well 14-14 (PTD #1811020) on 02/26/03. Recent pressure testing indicates that the failed MITIA may be due to a slow production casing leak or packer leak. The MIT form is attached. The waiver and sundry are being cancelled and the well will remain shut-in. An application for Administrative Approval will be sent with diagnostic testing results if it is desired to return the well to production. «MIT PBU 14-14 10-01-06.xls» The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you, )fnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ,~'.' "',\h~~,~r~"H 'lJ \--;;.\~¿~-¡;,~; .,;:\ ...&-.....-- c ~,~ Content-Description: MIT PBU 14-14 10-01-06.xls PBU 14-14 1 0-01-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 10/1 0/2006 1 :39 PM . . r7 /1 ¿; \ () \ lÙ 1 0 ~ \~~1 '1 Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I DS14 10/01/06 Andrea Hughes Packer Depth Pretest Initial 15Min. 30 Min. We1l114-14 I Type Inj. I N TVD I 8,438' Tubing 1,020 3,000 3,000 3,000 Interval 0 P,T.D.11811020 I Type test I P Test psi 2109.5 Casing 1,075 1,240 1,240 1,240 P/F/ P Notes: MITT for eval TxlA communication. OA 10 10 10 10 We1l114-14 Type Inj. I N TVD I 8,438' Tubing 1,295 1,365 1,320 1,295 Interval 0 p.T.D.11811020 I Typetest I P Test psi 2109.5 Casing 2,570 3,000 2,740 2,580 P/FI F Notes: MITIA for eval TxlA communication. OA 10 10 10 10 Weill I Type Inj. I TVD I Tubing Interval I p.T.D.1 I Type test I I Test psil I Casing P/FI Notes: I OA Weill I Type Inj. TVD Tubing I I Interval p.T.D.1 I Type test I Test psi Casing I I I P/F Notes: OA I I I Weill I Type Ini.1 I TVD I Tubing Interval P.T.D.I I Type test I Test psi Casing I P/F Notes: OAI TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = other (describe in notes) MIT PBU 14-1410-01-06,xls \p%' \Có\ ./ ,// 14-14 (PTD #1811020) MIT Results . Hi Jim, Winton, and Bob, Here is a MIT form for 14-14 recent AOGCC witnessed CMIT-TxIA conducted 08/29/06 and a MIT form for a non-witnessed CMIT-TxIA conducted 08/16/06. As you know, we prefer to pressure test the wells prior to having them witnessed so that we have confirmed results and are not wasting your time. With this particular well, the conflicting test results are confusing. Plans are to repeat the MITs tests using a triplex. The tubing and IA will be tested individually to explore the possibility of a slow PC Leak instead of TxIA communication. These results will be sent to you regardless of results. Depending on test results, plans will continue with having the AOGCC witness the MITs and submitting a request to update the Variance to an AA. As for the concern about possible IAxOA communication, the characterization on the TIO plot is thought to be due to liquid annuli acting independent of each other and not communicating. noted, the OA did not respond when pressure testing the IA. packed As Please let me know if you have any questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 f\ ~" "Zn f\ P $CANNED S EP \) t:' uu,; -----Original Message----- From: J ame s Regg [!!la,g~C?_=_E~~~9.9:.~.?:?mi._0_=_§_!:_~_t.:~.....:_~_=_'cl.~] Sent: Thursday, August 31, 2006 10:49 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: PBU 13-15 and 14-14 MIT Failures Please provide an update of these wells PBU 13-15 failed a witnessed CMIT on 8/4/2006; PBU 14-14 has a TxIA waiver (Sundry 300-199) and failed witnessed MITIA and CMIT TxIA on 8/29/2006; looking at the OA pressure history, it appears there has been a slow tendency to re-pressure, although there was no indication of such during the witnessed MITs. Jim Regg AOGCC MIT PBU 14-14 08-29-06.xls Content-Description: MIT PBU 14-14 08-29-06.xls lof2 9/1/20062:54 PM 14-1~ (PTD #1811020) MIT Results . Content-Type: Content-Encoding: . application/vnd.ms-excel base64 Content-Description: MIT PBU 14-14 08-16-06.xls MIT PBU 14-14 08-16-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 9/1/20062:54 PM MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor -;1 / C)!'-2 ~0C) / <:..";;1.,,,., V 7(..} 'v ) I~-<:t( " G(i ¡I/y,. . t . !. '... 'fr' DATE: Wednesday, August 30,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 14-14 PRUDHOE BAY UNIT 14-14 \Cß\,lor FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .....Tf5?- Comm Well Name: PRUDHOE BAY UNIT 14-14 API Well Number 50-029-20625-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060829194448 Permit Number: 181-102-0 Inspection Date: 8/29/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 14-14 Type Inj. N TVD 8438 IA 450 2950 2790 2650 2450 P.T. 1811020 TypeTest SPT Test psi 2109.5 OA 0 0 0 0 0 Interval REQVAR P/F F /Tubing 80 2950 2890 2850 2810 Notes Well has a waiver for slow T x lA communication. We first attempted an MITlA which failed at a rate of ISO psi per IS minutes. A plug had V V been set in the tubing so a CMIT was attempted with the results recorded above, , .' ·Î ,-k s+- reSLl ii-:;, ì >,,-Ca'lç S~+- WeQt 1$ 'S:L , U " ,It:C¡ So dot'\. e.. £/16!u& j' U..JÌ' '\, D f'€ - v-ì ,.,¡....", fÇ.'> ! ';)6' c~ -~ 4 If âtCL'~ ( <Jí<ê,¡)' , 'f<. '-' '. .C "'-c. NON-CONFIDENTIAL S~ANNED SEP 0 82006 Wednesday, August 30, 2006 Page I of I . . Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / DS14 08/29/06 Anna Dube Chuck Scheve '--! '<6;41 I ¡ Packer Depth Pretest Initial 15Min. 30 Min. We1l114-14 I Type Inj. I N TVD 1 8,438' Tubing 80 80 80 80 Interval I V p.T.D.11811020 I Typetest I P Test psi 1 2109.5 Casing 2,310 2,500 2,350 2,220 PIF F Notes: AOGCC State Witnessed MITIA to 2500 psi for OAO 0 0 0 Sundry Compliance. We1l114-14 I Type Inj. I N TVD I 8,438'1 Tubingl 80 2,950 2,890 2,850 Interval V P.T.D.11811020 I Typetest I P Test psi 2109.51 Casing 2,220 2,950 2,790 2,650 P/FI F Notes: AOGCC State Witnessed CMIT - TxlA to 3000 psi 1 OAIO 0 0 0 for Sundry Compliance. Extended test 15 minutes=2810 12450 1 O. Weill I Type Ini.' I TVD I Tubingl I I Interval I P.T.D.I I Type test I I Test psil Casing I P/FI Notes: OAI I Weill I Type Inj. I TVD ! Tubing Interval I P.T.D.' I Type test I I Test psi I Casing P/F! Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval 1 P.T.D.I I Type test! I Test psil Casing PIFI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M " Annulus Monitoring P = standard Pressure Test R = Internal Radioactive Tracer SUlvey A = Temperature Anomaly SUlvey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T" Test during Workover .__0 = Other (des"ri_ notes) $CANNED SEP 0 g 2006 4,. þ MIT PBU 14-14 08,29,06.xls . I Ci I JÎ¿'Xr~ \ºb \~ \O?-' - . . ,1"'"1 \¿ë1cl lit (¿lo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU 1 DS 14 08/16/06 Anna Dube \ 11'\ - V' 'r' Packer Depth Pretest Initial 15 Min. 30 Min. Weill 14-14 I Type Inj. 1 N TVD 1 8,438' Tubing 100 1001 100 100 Intervall V P.T.D.11811020 1 Typetest 1 P Test psi 1 2109.5 Casing 2,170 2,5001 2,400 2,400 P/FI P Notes: MITIA to 2500 psi for Sundry Compliance. OA 0 0 10 0 We1l114-14 I Type Inj. 1 N I TVD 1 8,438' Tubing 401 2,5001 2,500 2,500 Intervall V PTD.11811020 I Type test 1 P I Test psil 2109.5 Casing 1,9001 2,5001 2,420 2,420 PIFI P Notes: CMIT - TxlA to 2500 psi for Sundry Compliance. OA 0 10 10 0 Weill I Type Inj.1 I TVD I I Tubing I Interval I P.T.D.I I Type test I I Test psi I I Casing I P/FI Notes: I OA I Weill I Type Inj.1 I TVD I Tubing Intervall P.T.D.I I Type testl Test psil Casing PIFI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) S £Y \) \:) ?JJ'iSò ~Cì~~~O MIT PBU 14-14 08·16·06 xis . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test \ ~)( Oép ,....--, "('/'~(~f'; , '¡'-',/,-I . ¡ Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Mau.nder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / 0814 08/05/06 Anna Dube Packer Depth F We1l114-14 I Type Inj. W TVD I 8,438' Tubing P.T.D.11811020 I Type test I P Test psi! 2109.5 Casing Notes: AOGCC declined to Witness by Chuck Scheve. OA 641 MITIA to 2500 psi for Waiver Compliance. We1l114-14 I Type Inj. I W TVD I NA Tubing P.T.D.11811020 I Type test I P Test psil 2500 Casing Notes: MITOA to 2500 psi for waiver compliance. OA 62E Weill I Type Inj.1 I TVD I Tubing P.T.D.I I Type test I I Test psil Casing Notes: OA Weill I Type Inj.1 I TVD I Tubing P.T.D.I I Type test I Test psi! Casing Notes: OA Weill I Type Inj.1 I TVD I Tubing P.T.D. I Type test I Test psi! Casing Notes: OA TYPE INJ Codes o = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUlVey A = Temperature Anomaly SUlVey 0= Differential Temperature Test MIT Report Form BFL 9/1/05 /' I -(\; \ C \£K\-ID~ æANNED AUG 2 ¿12DDo 2006-0804_MIT_PBU_14-14_MITOAxls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MEMORANDUM \ , TO: Jim Regg I< Cot ~ LJ 1(']; t I 'ô -;' P.I. Supervisor (It..( I. FROM: John Crisp Petroleum Inspector Well Name: PRUDHOE BAY UNIT 14-14 Insp Num: mitJCr050825070050 Rei Insp Num State of Alask~ ) Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 30, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) lNC 14-14 PRUDHOE BA Y UNIT 14-14 Src: Inspector NON-CONFIDENTIAL \/\07 \~ Reviewed By: P.I. Suprv ..:JB/L. Comm API Well Number 50-029-20625-00-00 Permit Number: 181-102-0 Inspector Name: John Crisp Inspection Date: 8/19/2005 Packer --W-eU- i 14-14 ¡-Type Inj. I w I TVD P.T. I 1811Õ20 !TypeTe;íTš-PT I Test psi ___.....____...... . __.,,__.___._ I _______ Interval ~~~AR P1F._ __ P Pretest Initial 8438 I IA 1'----560 OÁ-'-r 700 I ... _...L.___ Tu b~~~J.__._~~L2~o Notes 06/13/02 MIT IA failed with .7 gpm @ 2500 psi. 4.7 bbl pumped to achieve test pressure for this MIT. 15 Min. 30 Min. 45 Min. 60 Min. 2475 ---,1··-..--·--··---·1--------- .- ..---t.--- .--- 880 I I '1---···---11---·-··-·--- 750 ......-----1....___.. _____._ Tuesday, August 30,2005 Depth 2500 2480 2109.5 880 880 750 ;:~~ C:jii\\N .~\~ 'E t .1 ~¿:. ~~ lOÚ~:~ T' . Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg :K lit z.4D4 P.I. Superviso tttq DATE: Monday, November 08, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 14-14 PRUDHOE BAY UNIT 14-14 ()..,\~ ~i/'ff. , \~ FROM: John Crisp Petroleum Inspector 8rc: Inspector Reviewed By: P.I. Suprv,,}13L- Comm Well Name: PRUDHOE BAY UNIT 14-14 Insp Num: mitJCr0411 04124943 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20625-00-00 Permit Number: 181-102-0 Inspector Name: John Crisp Inspection Date: 11/2/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 14-14 Type Inj. s TVD 8438 IA 2300 2520 2410 2300 P.T. 1811020 TypeTest SPT Test psi 2109.5 OA 500 550 550 550 Interval REQVAR PIF F Tubing 880 880 880 880 Notes: The data provided is the final pressure test performed. The IA was found @ 1100 psi before first test was performed. Four tests attempted before calling test a failure. SCANNE[> <i. /i 20 D It Monday, November 08, 2004 Page 1 of 1 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Beth 08/18/03 NO. 2948 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 9950.1 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D.S. 14-35 ~ ~r~'~ -- j L} [;~ ,~. INJECTION PROFILE 08/15103 W-34A ,,~¢"~i~ '-~ PROD PROFILE/DEFT 07126103 D.S. 14-'14y~.7.~ )'~ ~ ~k- INJECTION PROFILE 08/06/03 D.S. 4-3'1 )/q;~-~ '~ ~ PSP LEAK DETECTION LOG 08/07103 '1 D-06A ~. C~"~ "~"D~ PRODUCTION PROFILE 07/31/03 ,,, ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~.,av ~,,- ~..,. Date Delivered: 2005 ~.~aska Oil & Ga~ Co~s. C0mmis~n Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth q2ompleted MIT Forms Subject: Completed MIT Forms Date: Sat, 12 Jul 2003 14:01:15 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> To: "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein@admin.state.ak.us>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Prudhoe_Bay@admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us> CC: "Engel, Harry R" <EngelHR~BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Rossberg, R Steven" <RossbeRS~BP.com> - A-17 was against a TTP for Sundry compliance, it passed. ~ ~a - 14-14 is injecting under a sundry and a recent MITIA passed, s a repeat test to confirm the prior passing MITIA, but it failed. The annual LLRT will be scheduled for later this year. ~ ~~~A~-~'/,~ - Ail the others passed. ~t ~ t~D ~7 O~ <<MIT GPMA P2-09,28 07-11-03.xls>> <<MIT PBU 14-14 07-11-03.xls>> <<MIT PBU A-17 07-11-03.xls>> <<MIT PBU NGI-05 07-11-03.xls>> Let us know if you have any questions. Joe Joe Anders, P.E. / John Cubbon Well Integrity Coordinator, BP Exploration, Work: (907) 659-5102 Mobile: (907)'943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWellIntegrityEngineer®bp.com (Alaska) Inc. , 1 Name: MIT GPMA P2-09,28 07-11-03.xls T . ~I Type' Microsoft Excel Worksheet ~-~MI GPMA P2-09,28 07-11-03.~ 1 tappncanowvna.ms-excei) .................................................................................................................................................................................................. Name: MIT PBU 14-14 07-11-03.xls ~_)MIT PBU 14-14 07-11-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) I iEncoding: base64 ~__)MIT PBU A-17 07-11-03.xls Name: MIT PBU A- 17 07-11-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) 1 Encoding: base64 i' [ Name: MIT PBU NGI-05 07-11-03.xls IDMIT PBU NGI-05 07-11-03.xlst Type: Microsoft Excel Worksheet (application/w~d.ms-excel) i IEncoding: base64 7/18/2003 4:11 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner.,,~,,.,. THRU: Jim Regg P.I. Supervisor FROM: DATE: July 11,2003 John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX DS- 14 14 PBU Prudhoe Bay Unit Packer Depth Pretest Initial 15 Min. 30 Min. WellI 14-14 ITypelnj. I S I T.V.D. 18438IT b ngl~so i~o i~o I ~ P.T.D.I 1811020 TypetestI ITestpsil 2110 I Casingl 500 I 2490 I 2340I I P/FI E Notes: bbls. Pumped: 4 initial + 1 on the second time = 5 WellI Type Inj. P.T.D.I Notes: Well P.T.D. Notes: Well P.T.D. Notes: P'T'D'I Notes: IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F - FRESH WATER INJ. G = GAS I NJ. S -- SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W- Test during Workover O= Other (describe in notes) Test's Details I traveled to BPX's DS 14 well 14 to witness the annual MIT. A sundry # 300-199 issued on 8-15-00 was written and requires an annual LLRT. I was not aware of this requirement at the time of the MIT. No LLRT was performed at this time. The pretest pressures including the OA (160psi) were monitored and found to be stable. Upon pressuring up the IA, the OA immediatley rose to 600 psi and remained for the duration of the test. The OA did not track the IA but remained stable at 600 psi The IA was pressured up twice with the same results. The IA does not meet the AOGCC criteria for MIT's. failure. M.I.T.'s performed: 1_ Number of Failures: 1_ Total Time during tests: 2 Attachments: cc: MIT report form 5/12/00 L.G. 2003-071 I_M IT_PB U_I 4-14_js.xls 7/18/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanonr-] SuspendC~ Operation Shutdownr--~ Perforater-~ varianceC~ Annuar DisposalS] After Casin~r-] Repair Well[--] Plu.~ Perforations[~ Stimulate[] Time ExtensionD Otherr~ Change Approved Program E~ Pull Tubing [~ Perforate New Pool r-~ Re-enter Suspended Well [~ SCHMOO-B-GONE 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement [~ Exploratoryr~ 181-102 3. Address: P,O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphicr'-~ Service[] 50-029-20625-00-00 7. KB Elevation (ft): 9. Well Name and Number: 71.00 14-14 8. Property Designation: 10. Field/Pool(s): ADL 028311 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12327 feet true vertical 9454 feet Plugs (measured) Effective Depth measured 12277 feet Junk (measured) true vertical 9408 feet Casing Length Size M D TV D B u rst Col lapse Conductor 81' 20" 110' 110' 40K 520 Surface 2603' 13-3/8" 2632' 2632' 80K 2670 Intermediate 11332' 9-5/8" 11358' 9087' 80K 4760 Liner 1243' 7" 11085'-12322' 8881'-9449' 80K 7020 Perforation depth: Measured depth: Open Perfs 11512'-11552', 11557'-11567', 11570'-11588', 11602'-11640', Open Perfs 11650'-11670', 11680'-11710', 11752'-11770', 11774'-11802', Open Perfs 11806'-11834'. True vertical depth: Open Perfs 8792'-8824', 8828'-8836', 8839'-8853', 8865'-8895', 8903'-8919', Open Perfs 8927'-8951', 8985'-9000', 9003'-9026', 9028'-9051'. Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 TBG @ 11095'. 5-1/2" x 4-1/2" XO @ 11095'. 4-1/2" 12.6# L-80 TBG @ 11190'. 4-1/2" TBG Assembly @ 11730'-11740'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker 'D' Packer @ 5-1/2" Otis ROM SSSV Nipple @ 2210'. 12. Stimulation or cement squeeze summary: JUN ! (~ 2003 Intervals treated (measured): Alaska 0ii & Gas Cons. Treatment descriptions including volumes used and final pressure: !13 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 4242 559 Subsequent to operation: 5048 244 14. Attachments: 15. Well Class after proposed work: Exploratory[-] Development[-] Service~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: OilF1 Gas[~ WAG['} GINJr-] WINJ[ WDSPLE-1 Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry,,l~,~ber or N~empt: Contact DeWayne R. Schnorr I N/A Printed Name DeWayne R. Schnorr Title Techical Assistant Signature ~~~.~'" "" "~~/'/~ "Phone 907/564-5174 Date June05,2003 Form 10-404 Revised 2/2003 14-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/31/2003 SCMOO-B-GONE--SBG: SCMOO-B-GONE 06/05/2003 TESTEVENT --- INJECTION PRESSURE, PSI: 244 TYPE: PW VOLUME: 5,048 EVENT SUMMARY 05/31/03 RIGGED UP TO RISER ON MANIFOLD BUILDING. PUMPED 5 BBLS OF METHANOL FOLLOWED BY 308 BBLS OF SCHMOO-B-GONE. DSO TO BACKFLUSH WITH WATER AND BRING BACK ON INJECTION. 06/05/03 TESTEVENT --- INJECTION PRESSURE, PSI: 244 TYPE: PW VOLUME: 5,048 FLUIDS PUMPED BBLS 10 METHANOL 308 SCHMOO-B-GONE 318 TOTAL Page 1 TREE = GRAY GEN 2 ACTUATOR = AXELSON " SAFETY NOTES: CHROME 4-112" TBG. PW! INJI~TION KBi ~ ~ ............................................... 71' ONLY. ***SLOW T X IA COMM. (02/25/03 WAIVER)*** KOP = 2300' i/, Max Angle = 53 @ 6400' Datum MD = 11610' , Datum TVD = 8800' SS I I 13-3,8" CSG, 7L:~, L-80, ID = 12.347" H 2632' I I----I11049' H, 5'1/2"OTISXNNP'ID:4'45"I Minimum ID = 3,725" @ 11738' I 4-1/2" OTIS XN NIPPLE i I5-1/2"TBG, 17#,L-80,0.0232bpf, ID=4.892"H I'---- RERFORATIO N SUMM~ RY RI~ LOG: BH~S ON 10121181 ANGLE AT TOP PERF: 36 @ 11512' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 11512-11552 O 04/13/83 3-1/8" 4 11557-11567 O 04/13/83 3-1/8" 4 11570-11588 O 07/12/82 3-1/8" 4 11602-11640 O 07/12/82 3-1/8" 4 11650-11670 O 07/12/82 3-1/8" 4 11680-11690 O 04/13/83 3-1/8" 4 11690-11710 O 07/12/82 3-3/8" 1 11752-11770 O 12/25/91 NA 2 11774-11802 O 12/27/91 2 11806-11834 O 12/24/91 , I I I= ; I-I4-1'2"OTISXNNP, ID:3.72" I 4-1/2"TBG, 12.6#,O-CR-80,0.0152bpf, ID=3.958"H,,11740' ~"-'-/ ' i ".~o'I--t4-1/2" TUBING TAIL I I 7" LNR, 29#, L-g0, 0.0371 bpf, ID = 6.184"H 12322'I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/26/81 I ORIGINAL COMPLETION 02/25/03~ JIVP/KK WAIV ER SAFETY NOTE WELL: 14-14 '01/08/92 LAST WOF~OVER FERMIT No: 1811020 12/26/001 SIS-OAA CONVERTEDTO CANVAS I APl No: 50-029-20625-00 02/15/01 ~ SIS-MD FHAL SEC 9, T10N, R14E, 5044.91' FEL& 2808.68' FNL 01/07/02 RNfrP CORRECTIONS (~3/31/02 CH/'I'P I CORRECTIONS BP Exploration (Alaska) PERFORATION SUMMA RY REF LOG: BFICS ON 10/21/81 ANGLE AT TOP PERF: 36 @ 11512' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 11512-11552 O 04/13/83 3-1/8" 4 11557-11567 O 04/13/83 3-1/8" 4 11570-11588 O 07/12/82 3-1/8" 4 11602-11640 O 07/12/82 3-1/8" 4 11650-11670 O 07/12/82 3-1/8" 4 11680-11690 O 04/13/83 3-1/8" 4 11690-11710 O 07/12/82 3-3/8" 1 11752-11770 O 12/25/91 NA 2 11774-11802 O 12/27/91 2 11806-11834 O 12/24/91 DATE REV BY COMMENTS DATE REV BY COMMENTS 10/26/81 ORIGINAL COMPLETION 02/25/03 JIVP/KK WAIV ER SAFETY NOTE 01/08/92 LAST WOF~OVER 12/26/001 SIS-OAA CONVERTEDTO CANVAS 02/15/01 SIS-MD FHAL 01/07/02 RNfrP CORRECTIONS (~3/31/02 CH/TP CORRECTIONS bp BP Exploration Alaska Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 July 27, 2000 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: DS 14-14 (PTD 181-102) Sundry Notice Variance Request Dear Mr. Maunder: Attached is an Application for Sundry Approval form 10-403 variance request for well 14-14 (PTD 181-102). The request is for approval to continue produced water injection with known production casing communication. Also attached is a proposed Action Plan and a wellbore schematic. If you require any additional information or clarification, please feel free to contact either Joe Anders or me at (907) 659-5102. Sincerely, Jerry Dethlefs Problem Well Specialist Attachments RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1283' FNL, 1042' FEL, Sec. 9, TION, R14E, UM At top of productive interval 2498' FNL, 129' FEL, SEC. 11, TION, R14E, UM At effective depth At total depth 2809' FNL, 5045' FEL, Sec. 11, T1ON, R14E, UM 5. Type of Well: Development __ Exploratory __ Stratig raphic _ Service __X (asp's 675429, 5939061) (asp's 686930, 5938125) (asp's 682024, 5937692) 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-14i 9. Permit number / approval number 10. APl number 50-029-20625 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measu red true vertical Casing Length Conductor 81' Surface 2561' Production 11287' Liner 1237' 12320 feet Plugs (measured) Tagged PBTD @ 11973' on 8/25/1999. 9448 feet 11973 feet Junk(measured) ORIGINAL 9163 feet Size Cemented Measured Depth True vertical Depth 20" 300 Sx PF 81' 81' 13-3/8" 2e00 Sx Fondu & 400 Sx AS 11 2632' 2620' 9-5/8" 500 Sx C~ass e 1 1358' 8668' 7" 350 sx class e 12322' 9449' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 11512'-11552'; 11557'-11567'; 11570'-11588'; 11602'-11640'; 11650'-11670'; 11680'-11710'; 11752'-11770'; 11774'-11802'; 11806'-11834'. 8792'-8825'; 8829'-8837'; 8839'-8853'; 8865'-8895'; 8903'-8919'; 8927'-8951'; 8985'-9000'; 9003'-9025'; 9028'-9051'. 5-1~",17#,L-8OTbg @ 11095'MD; 4-1~",12.6#,L-80Tbg @ 11190'MD; 4-1~",12.6#,90R-80, Tbg @ 11740'MD. 9-5/8" X 5-1/2" BAKER D PACKER @ 11073' MD; 7"X 4-1/2" OTIS TWD PERMANENT PACKER @ 11730' MD. 5-1/2" OTIS RQM SSSV @ 2210' MD. 13. Attachments Description summary of proposal .__X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation August 1,2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended __ Service WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~'~ ~---' ~--~ ~ Title: BPA Problem Wells Specialist Jerry Dethlef~ Questions? Call Joe Anders/Jerry Dethlefs @ 659-5102 ___Approved by order of the Commission FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approvalno. Plug integrity__ BOP Test__ Location clearance__ I ~;)[It~(~ '"' Mechanical Integrity Test_._~',~t~\ ~.,~,,\"~ SubsequenLform required 10-~~ ~~~~x~ ~ D Taylor Seamount Re~rned Form 10-403 Rev 06/15/88 · Please return to PRE-24 SUBMIT IN TRIPLICATE DS 14-14 Sundry Request SUNDRY DISCUSSION AND PROPOSED ACTION PLAN July 27, 2000 DISCUSSION Prudhoe well DS 14-14 (PTD 181-102) failed an MIT-IA on 7/09/00 due to lack of pressure stabilization while preparing for a 4-year pressure test. A pressure loss of 120/120 psi in 15/30 minutes was observed. A leak rate of 0.62 gpm was established into the IA @ 2440 psi. The leak location is unknown and is too small to locate with normal logging tools. The well is currently injecting produced water at 5,000 BWPD @ 600 psi. The well last passed an MITIA @ 2300 psi on 7/25/96. This Sundry request is to allow continued water (only) injection into well 14-14. Justification for the request: · The slow rate of pressure loss (_--120 psi / 15 minutes) indicates the leak is small; · The leak rate will be monitored and quantified with annual leak rate tests. PROPOSED ACTION PLAN 1. Continue water injection (only) into the well; 2. Monitor wellhead pressures daily; 3. Conduct yearly MIT-IA / LLR test. When leak rate is large enough, run leak detect logs to locate leak point; 4. Perform 4-year CMIT T x IA; 5. Submit monthly report of injection rate and tubing & IA pressures; 6. Shut-in and secure the well should MIT's or wellhead pressures indicate problems and notify the AOGCC. ECEIVED ARCO ALASKA, INC. SSSVNIP Tubing NOGO Casing SEALASY PKR XO Tubing Liner i..(~.: J ~.'.'...(~!S .~..N!PP!.~) ........... NIP TTL Perf Perf Perf Perf PKR Tubing Perf Peri' ................................. ~~ ",r Prudhoe Bay 14-14 14-14 APl: 500292062500 Orig C°mpltn: 10/26/81 Angle @ TD: 35 deg @ 12320 SSSV Type: Last W/O: 1/8/92 Rev Reason: Tag Annular Fluid: 6.8 Diesel/8.5 SW Ref Log Date: 10/21/81 Last Update: 9/28/99 Reference Log: BHCS RKB: 71 ft Last Tag: 11973'SLM TD: 12322ftKB Last Tag Date: 8/25/99 Max Hole 53 deg @ 7200 Angle: Well Type: INJ Angle @ TS: 36 deg @ 11509 Depth Anhotations Depth Comment 11177 11177' MIN ID= 3.813" (4-1/2" Otis × Nipple) 11738 11738' MIN ID= 3.725" (4-1/2" Otis XN Nipple) General N~te$ : : Date Note TTL ELM @ 11742: ELM Tubing Tail (Logged 03/17/93) Daterun: 1981-10-26 TTL ELM @ 11168: ELM Tubing Tail (Logged 03/17/93) Daterun: 1981-10-26 0ther (P!~ ~i~ et~i)~ ~EWE~RY: : : Depth TVD Type Description 2210 2209 SSSVNIP 5-1/2"Otis RQM SSSV Nipple 11049 8419 NOGO 5-1/2" Otis XN Nipple 11072 8438 SEALASY 5-1/2" Baker Locator Seal Assembly 11073 8439 PKR 9-5/8" x 5-1/2" Baker D Packer 11095 8456 XO Crossover 5-1/2" x 4-1/2" 11177 8522 NIP 4-1/2" Otis X Nipple 11190 8533 TTL 4-1/2" Tubing Tail 11730 8967 PKR 7" x 4-1/2" Otis TWD Permanent Packer 11738 8974 NOGO 4-1/2" Otis XN Nipple 11740 8976 TTL 4-1/2" Tubing Tail ID 4.560 4:450 0.000 0.000 0.000 3.810 0.000 0.000 3.720 0.000 Size Weight Grade Top Btm Feet Description 7.000 29.00 L-80 11085 12322 1237 Liner 9.625 47.00 L-80 0 11358 11358 Casing 13.375 72.00 L-80 0 2632 2632 Casing Size Weight Grade Top Btm Feet Description 5.500 17.00 L-80 0 11095 11095 Tubing 4.500 12.60 L-80 11095 11190 95 Tubing 4.500 12.60 9CR-80 11730 11740 10 Tubing Interval TVD Zone Status FeetSPF Date Type 11512 - 11552 8792 - 8824 ZONE 4 O 40 4 4/13/83 APERF 11557-11567 8828-8836 ZONE4 O 10 4 4/13/83 APERF 11570 - 11588 8839 - 8853 ZONE 4 O 18 4 7/12/82 IPERF 11602 - 11640 8865 - 8895 ZONE 4 O 38 4 7/12/82 IPERF 11650 - 11670 8903 - 8919 ZONE 4 O 20 4 7/12/82 IPERF 11680 - 11690 8927 - 8935 ZONE 4 . O 10 4 4/13/83 APERF 11690-11710 8935-8951 ZONE4 O 20 4 7/12/82 IPERF 11752 - 11770 8985 - 9000 ZONE 3 O 18 1 12/25/91 APERF 11774 - 11802 9003 - 9025 ZONE 3 O 28 212/27/91 APERF 11806 - 11834 9028 - 9051 ZONE 3 O 28 2 12/24/91 APERF Comment RECEIVED 14-14 Failed MITIA, PTD 181-102 Subject: 14-14 Failed MITIA, PTD 181-102 Date: Sun, 9 Jul 2000 21:21:51 -0900 From: "PRB Problem Wells" <P1041@ppco.com> To: tom_maunder@admin.state, ak. us CC: jeff_jones@admin.state.ak, us Hello Tom. Injection well 14-14 (PTD 181-102) failed an MIT-IA today due to lack of pressure stabilization. While prepping the well for the AOGCC required 4-~ar MITIA, we pressured the IA to 2500 psi and recorded a pressure loss of 120 psi in 15 minutes. We re-pressured the IA to 2500 psi, lost 120 psi first 15 minutes, total of 240 psi in 30 minutes. Similar results were obtained during a third test. Initial Tubing/INOA = 680/520/50 psi. We plan to run a tubing tail plug, then (z)nduct an MIT-Tubing and MIT-IA to confirm tubing and casing condition. We will inform you of the results of the testing. Please call if you have any questions. Joe Anders, PE Well Integrity Engineer BP Exploration (907) 659-5102 p 1041 @ppco. com 1 of 1 7/10/00 8:35 AM ARCO Alaska, Inc. P.O~3ox 100360 Anchorage, ~~ 99510 DATE: 04--22-93 REFERENCE: 3-13-93 Production Log l~n 1, ~' Sch 3-15-93 Production Log Run 1, ~' Sch 3-14-93 Spin/Temp/Gradio/Press l~m 1, [~, Sch 3-14-93 CBT Color Run 1, [~' Sch 3-14-93 USIT(Cement &.,Corrosion) Color Run 1, IY' Sch 3-16-93 Pe~~ ]~_m 1, [~' Sch 3-14-93 Tubing Cut Record l~_m 1, ~' Sch 3-12-93 Peri Record Run 1, ~' Sch 3-18-93 Perf R~ l~_m 1, ~' Sch 3-18-93 Per~ Record Run 1, [Y' Sch 3-13-93 (~ ~o~o~ Run 1, 2'&i~' Sch 3-14-93 Tubing Cut Record Run 1, [~' Sch 3-12-93 Production Log' Run 1, ~' · Sch 3-15-93 Leak Detect Run 1, 2'&N' Sch 3-19~93 Production Log Run 1, [~' S ch 3-17-93 Tie-In GR/(XIL l~m 1, [~' Sch 3-17-93 Inj Prof/Spin/Temp/Press l~m 1, ~' Sch 3-17-93 Production Log l~m 1, IY' Sch 3-20-93 PITS Run 1, [~' Sch 3-16-93 Production Log Run I, ~' Sch 3-11-93 Peri Record Run 1, ~' Sch 3-12-93 Press/Temp l~m 1, [Y' Sch Please sign and return the attached copy as receipt of data. Have A Nice Day! Sonya Wallace APPROVED__ _.~~ ATO-1529 Trans# 93048 # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL ~ # BPX # STATE OF ALASKA * The correct APl# for 1-5ST is 50-029-20076-00. ARCO .~,l~_sk_~_, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ARCO CASED HOLE FINALS 2-32 ?1-/// 6-21-92 Prod Profile Run 1, 5" 3-10 ??-~/ 6-20-92 Inj Profile ~ 1, 5" 3-26~a~_/~'1 6-28-92 Prod Profile Run 1, 4-14 ?d~' ~ 6-28-92 Temperature Run 1, 5" 5-5 7~-id? 6-22-92 Prod Profile Run 1, 5" 7-5 6-23-92 Prod Profile Run 1, 9-38 6-30-92 Inj Profile Run 1, 5" 9-39 6-30-92 Inj Profile thru 1, 12-17 ~3'--,~' 6-29-92 Leak Detect Run 1, 5' 13-158-1 ~/~'ff'6-27-92 Inj Profile Run 1, 5" 13-29 85-~/~ 6-19-92 Prod Profile Run 1, 5" 13-32~/~$ 6-27-92 Inj Profile Run 1, 5" · 14-14~/-/~:~ 6-26-92 Inj Profile Run 1, 5" 14-36~-/~ 6-26-92 Inj Profile Run 1, 5" 16-7 ~f'~}/ 6-19-92 Prod Profile Run 1, 5" Please sign and return the attached copy as receipt of data. RECEIVED BY .~~_~~_ APPROVED_ _~___1___ Trans# 92150 Have A NiCe Day! Sonya W~ll~ce AT0-1529 C~nco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO Alaska Oil & Gas Cons. Commission REt-'uH SUND NS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate ~ Pull tubing Alter casing Repa r well Other , 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1284' FNL, 1044' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2498' FNL, 129'FEL, Sec. 11, T10N, R14E, UM At effective depth At total depth 2470'FNL, 242' FEL, Sec. 11, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-14 9. Permit number/approval number 81-102/91-385 10. APl number 50 - 029-20625 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12327 feet Plugs(measured) 9454 feet Effective depth: measured ,12277 feet true vertical 9408 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 300 sx Permafrost 110' 110' Surface 2603' 13-3/8" 2600sx Fondu & 400 sx AS II 2632 2632 Production 11332' 9-5/8" 500 sx Class 'G' 11358' 9087' Liner 1243' 7" 350 sx Class 'G' 11085-12322' 8881-9449' Perforation depth: measured 11512'-11552', 11557'-11567', 11570'-11588', 11602'-11640', 11650'-11670', 1 1680'-11710', 11752-11770', 11774-1 1802', 1 1806-11834' true vertical 8789-8824', 8828-8837', 8840-8855', 8868-8901', 8909-8927', 8935-8961', 8998-9014', 9017-9041 ', 9045-9069' Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, w/tail @ 11,190' MD; 4-1/2" 9-CR 11,730-11,740'MD Packers and SSSV (type and measured depth) Baker D Packer @ 11,073'MD; Otis TWD Packer @ 11,730'MD; Otis RQM SSSV @ 2210'MD D C f" I: I i:: r'l 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A Treatment description including volumes used and final pressure JUN 1 9 1992 Alaska 0il & Gas Cons. Comrniss%0t~ · An~hnr~n~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure o 6000 200 10000 - 300 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended .... Service Water Injector 17. I hereby certify that the foreg~,l~l is true and correct to the best of my knowledge. I ! Signed Title Senior Engineer Form 10-404 Rev 06/15/88 JLB c: SW, JWP SUMMARY OF WELL OPERATIONS ARCO Alaska, Inc. perforated DS 14-14i at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 12/24/91 (11752-11770'MD, 11774-11802'MD, 11806-11834'MD Ref Log: BHCS 10/21/81). Seawater was in the wellbore during perforating operations. A short summary of the work is given below. - Began perforating operation on 12/24/91. - RU perforating unit and pressure tested equipment to 3000 psi. - RIH w/ gun # 1, tied-in, and shot # 1: 11814-11834'MD @ 2 spf. - POOH. Ail shots fired. - RIH w/ gun #2, tied-in, and shot #2 11806-11814'MD @ 2 spf. - POOH. All shots fired. - RIH w/ gun #3, tied-in, and shot #3 11774-11802'MD @ 2 spf. - POOH. All shots fired. - RIH w/ gun #4, tied-in, and shot #4 11752-11770'MD @ 1 spf. - POOH. All shots fired. - Secured well. RD. RECEIVED J UN 1 9 1992 Alaska Oil & Gas Cons. Commiss%oa Anchorage JLB 6/19/92 A ,,A OIL AND GAS CONSERVATION COMMIS ,,I REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown Stimulate Plugging Perforate Pull tubing X Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1284' SNL, 1044' WEL, SEC. 9, TION, R14E, UPM At top of productive interval 2498' SNL, 129' EWL, SEC. 11, TION, R14E, UPM At effective depth 2496' NSL, 210' EWL, SEC. 11, TION, R14E, UPM At total depth 2470' SNL, 242'EWL, SEC. 11, TION, R14E, UPM 12. Present well condition summary Total depth: measured 12327 feet true vertical BKB 9454 feet 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) 6. Datum elevation (DF or KB) KBE = 71 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 14-14i 9. Permit number/approval number 81-102~Conservation order 258 10. APl number 50- 029-20625 11. Field/Pool Prudhoe Bay Field~Oil Pool Effective depth: measured 12252 feet true vertical BKB 9366 feet Junk (measured) Top off ill @ 12252'MD (1/92) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True vertical depth RECEIVED JUN - 5 1992 Alaska 0ii & Gas Cons. C0mmis$i0a Anchorage Tubing (size, grade, and measured depth) 5-1/2" 17#, L-80L TC/MOD tubing to 11095'MD, 4-1/2" 12.6~, L-80 BTC/MOD tubing tail 11095:11190'MD, 4-1/2" 12.6,il, 9CR-80 tubing tail 11730:11740'MD Packers and SSSV (type and measured depth) 9-5/8" Baker 'D'packer@ 11073'MD, 7" Otis 'TWD' permanent packer @ 11730'MD, 5-1/2" Otis 'ROM' SSSV @ 2210'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run . Daily Report of Well Operations x 16. Status of well classification as: Oil Gas Suspended Service Water Injector 17. I hereby certify that the foregoing_is true and co.p,ect to the best of my knowledge. S igned.:~._~_~ ~,,~~"---' Title Drillin~iEn~lineerSupervisor Form 10-404 Rev 06/15/88 D at e ..,~'~' ~'./~'-,... SUBMIT IN DUPLICATE ACTIVITY SUMMARY for WE PROJECT 4J0131 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : DS 14-14I Page: 1 DRLG RIG : DOYON 16 WO/COMP RIG: DOYON 16 12/30/91 (2) TD:12310 PB:12277 SUPV:NJS 12/31/91 TD:12310 PB:12277 SUPV:NJS (COMP) KILL: 8.5 OTHER: 5.5 KILL WELL. MW: 8.5 Seawater MOVE RIG. RIG ACCEPTED @ 16:OO HRS, 12/29/91. R/U LUB. PULL BPV. R/D LUB. BULLHD SEAWATER DN TBG. CIRC DN TBG. RETURNS THRU CHOKE. SPOT XCD PILL @ TBG TAIL. OBSERVE WELL. WELL STABLE. INSTALL TWC. (4J0131) DAILY: $ 59,738 CUM: $ 59,738 EFC: $ 1,027,000 (COMP) NU ND: 7.0 PL TBG: 17.0 ( 3) RIH W/OVERSHOT MW: 8.5 Seawater ND TREE, NU BOPE AND TEST TO 3500 PSI ' PULL AND LAY DOWN 5-1/2" TUBING RIH W/OVERSHOT. (4J0131) DAILY: $ 39,752 CUM: $ 99,490 EFC: $ 1,027,000 (COMP) PL TBG: 24.0 01/01/92 i 4) TD:12310 PB:12277 SUPV: NJS RIH W/SPEAR BHA MW: 8.5 Seawater RIH W/OVERSHOT. TAG FISH @ 10962'. POOH~, UNABLE TO LATCH' ONTO FISH. MAKE UP SPEAR ASSY AND RIH~' (4J0131) DAILY: $ 27,427 CUM: $ 126,917 EFC: $ 1,027,000 (COMP) NU ND: 5.0 PL PBR: 8.5 PL PKR: 4.5 PL TBG: 6.0 01/02/92 ~ 5) RI~ W/PRT MILL A~SY -- MW: 8.5 Seawater TD:12310 RIH W/SPEAR AND RETRIEVED FISH. POOH. TEST~BOP'S TO 5000 PB:12277 PSI. RIH W/NEW SPEAR ASSY. SPEAR INTO SLICK STICK AND SUPV:NJS ROTATE OUT K-ANCHOR. L/D SPEAR ASSY. RIH W/PRT ASSY. (4J0131) DAILY: $ 25,577 CUM: $ 152,494 EFC: $ 1,027,000 (COMP) CLN OUT: 10.5 PL PKR: 13.5 01/03/92 (-- 6) POOH--. MW: 8.5 Seawater TD:12310 MILL 9-5/8" PACKER @11015'. CBU.' RIH AND TAG PACKER @ TOL PB:12277 @ 11080' POH AND LAY DOWN PACKER. RIH W/6" BIT TO 11916'. SUPV:NJS CBU. PU~L 10 STDS TO 10957'. CIRCULATE ABOVE TOP OF LINER. RIH TO 11916'. CBU @11916'. POOH. (4J0131) DAILY: $ 35,427 CUM: $ 187,921 EFC: $ 1,027,000 (COMP) CLN OUT: 15.0 OTHER: 1.0 TEST CSG: 8.0 01/04/92 (-- 7) POOH W/RTTS -- MW: 8.5 Seawater TD:12310 POOH. RIH W/7" AND 9-5/8" SCRAPERS. POOH. RIH W/7" RTTS PB:12277 TEST PACKER. SET AT 11350'. TEST LINER LAP AND 9-5/8" CSG SUPV:NJS TO 3500 PSI, LEAK IN VARIABLE RAMS. ALSO LEAK IN HYDRILL. RELEASE PACKER & POH. (4J0131) DAILY: $ 36,466 CUM: $ 224,387 EFC: $ 1,027,000 01/05/92 (-- 8) TD:12310 PB:12277 SUPV:NJS (COMP) OLD PROB: 13.5 RUN COMP: 9.0 TEST CSG: 1.5 R/D ATLAS WIRELINE MW: 8.5 Seawater POOH AND LAY DOWN TEST PACKER. CHANGE OUT HYDRILL, VARIABLE RAMS TO 3-1/2". NU FLOWLINE, TEST BOPE. RU ATLAS WIRELINE. RIH W/8-1/2" GR/JB. SET PACKER @11720' TEST, RAMS LEAKING. CHANGE TOP RAMS, TEST TO 5000 PSI-O~. INSTALL WEAR BUSHING. R/U ATLAS WIRELINE. RIH W/GR/JB TO 11085'. NO RECOVERY OF TEST RUBBER. R/D ATLAS WIRELINE. (4J0131) DAILY: $ 53,297 CUM: $ 277,684 EFC: $ 1,027,000 ACTIVITY SUMMARY for WE PROJECT 4J0131 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : DS 14-14I Page: 2 DRLG RIG : DOYON 16 WO/COMP RIG: DOYON 16 (COMP) OLD PROB: 1.0 01/06/92 (9) TD:12310 PB:12277 SUPV:NJS RUN COMP: 23.0 POOH W/BAKER TEST PACKER MW: 8.5 Seawater RIG DOWN ATLAS. RIH W/9-5/8" PAKER ASSY AND 3-1/2" DRILLPIPE. COULD NOT SEAT BALL. POOH W/PACKER. RIH TO - 11045'. ATTEMPTED TO SET PACKER, UNSUCCESSFUL. POOH W/PKR,,RUNNING TOOL. RIH W/TEST PACKER TO 11035'. TEST 9-5/8 CSG TO 3500 PSI, NO LOSS. POOH W/TEST PACKER. (4J0131) DAILY: $ 27,796 CUM: $ 305,480 EFC: $ 1,027,000 (COMP) RUN COMP: 24.0 01/07/92 (--10) RIH W/5-1/2" COMPLETION MW: 8.5 Seawater TD:12310 POOH. RIH AND STING INTO PACKER @11045'. POOH, LAYING PB:12277 DOWN 3-1/2" DRILLPIPE. CUT AND SLIP DRILL LINE. RIH SUPV:NJS W/5-1/2" COMPLETION. (4J0131) DAILY: $ 27,461 CUM: $ 332,941 EFC: $ 1,027,000 (COMP) NU ND: 4.0 01/08/92 ( 11) TD:12310 PB:12277 SUPV:NJS RUN COMP: 20.0 NU T--REE AND ADAPTER FLANGE MW: 8.5 Seawater RIH W/5-1/2" TUBING, LAND TUBING. TEST 5-1/2" X 9-5/8" ANNULUS TO 3500 PSI. TEST CONTROL LINES TO 5000 PSI. DISPLACE TUBING TO DIESEL. ND BOPE, NU ADAPTER FLANGE & TREE. (4J0131) DAILY: $ 292,852 CUM: $ 625,793 EFC: $ 1,027,000 (COMP) NU ND: 2.0 01/09/92 ( 12) TD:12310 PB:12277 SUPV:NJS RELEASE WELL MW: 8.5 Seawater NU TREE AND ADAPTER FLANGE, TEST TO 5000 PSI, INSTALL BPV. RELEASE RIG @ 0800 HRS 01-08-92. (4J0131) DAILY: $ 8,462 CUM: $ 634,255 EFC: $ 1,027,000 Ri EIVED JUN - 5 3992 Alaska Oil & Gas Cons. Commission Anchorage P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-24-92 REFERENCE: ARCO CASED HOLE FINALS ] ~1 1-13-92 Completion .: Run 1, 5" Sch - 1-13-92 Temp/GR/~ Correlation _Run 1, 5" Sch ~) /- ~~-33 1-12-92 CNL l~un 1, 5" Sch ,NL R~_m 1, 5" c -- ia, 4 1-4-92 CCL (WD Packer Correlation).Run Please sign and return the attached copy as receipt of data Have A Nice Day! ~ Sonya Wallace APPROVED # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # pHr~ I.rpS PB WELL FH,F~ R&D # BPX # STATE OF ALASKA TEXACO RECEIVED FEB 0,~ 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA, INCA F'.O. BOX toe360 ANCHORAGE, ALASKA 995i0 DATE: t-~D-92 REF-Ei':ENCE' ARCO CA~EL~ HOLE FINAL3' J~'';~2-i6 i.~-6-9i"'//4~'CL FOR STRE3'$ FRAC ' -,,...j~" 3- t 4 t Z- t G-9 t _v"/4-:UL !- U~! S ~ t,:ES S FRAC .F;..F~'4-7 t2-i8-9t v .CCL FOR BRIDGE PLUG u .. t ~-3 t 2-26-9i ,."'CL;L FOR TUBING CUTTER ~;. ,>.t 4- i 4 t 2-24-9 ~ ~ F/EF.'F/COLLAR FOR TUB I NG CUTTER ~'" ~4 4-35 7-28-9t /,~"DSN ' ~'-' . · ,';,-2~-~,.."/FsN , , - , ,~n.-r~ 8-t6 t2-9-9t ~/CCL FOR STRESS F'RAC PLEA3'E SIGN AND RETURN THE ATTACHED COPY AS REC;EIPT OF DATA RUN 3, 5' HLS RUN t, 5' HLS RUN t, 5' HLS RUN t, 5' HLS RUN t, 5' HLS RUN t, 5" HLS RUN i, 5' HL$ RUN i, 5' HL$ RUN t, 5' HLS RUN t, 5' HLS SON'fA WAL. L. F~L;E. A'i-O- i 529 _, J/ A F'F'I:(UVt:.. D ~ TI;.:AN$~ 91. .... RECEIVED dAN 2 1 1992 ^~as~a Oil & Gas b'Obs. Commission Anchorage DISTRIBUTION ~ CENTRAL FILES ~ CHEVRON D &H ~'- EXTENSIF~N EXPLORATIF~N · "- EXXON HARATHON · .-' HOBIL F'HII_LIF'S F'B WELl- F'IL..E:~; F,' & D '"' BF'X 'Il' STAi'E OF AI_ASKA TEXACO ARCO ALASKA, INC./~ P.O. BOX i(~360 ANCHORAGE, ALASKA 995t DATE' t~'~-3~-~i, REFERENCE' ARCO CASED HOLE FINALS t t-~6 Jit-i8-9t ~'F~OD FROFILE ~-q~ ~ ~-22 ~-~ 4-~ ECT -~'_ ~ 3-28 ~ -t ~-9~ ~ LEAK D~'I'ECT ~-~4-3 .~-~-9~ ~ PROD F'ROFILE ~/~(~ 4-~4 ~-3~-9~ ~ LEAK DETECT ~4-~4 ~-8-9~ LEAK DETECT ~~ ~/-~ ~5-~5 ~8-~8-~ PROQ PROFILE RUN RUN t , 5' R[JN RUN RUN RUN t , .5 ' RUN RUN RUN t, 2' RUN t, 5" RUN t, 5" PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA. RECEIVED BY .~__J~' HAVE A NICE DAY! ~ONYA WALLACE ATO- i 5'29 AF'F'ROVED i i~,'A N,~'-~ 9i CAMCO CA~CO CAMCO CAMCO CAMCO CAMCO CA~u CA~CO CAhCO CAMCO CAMCO DISTRIBUTION CEN't'RAL F'£LE$ CHEVRON EX'I' EN$ION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO * THE CORRECT API~ FOR t7-2 IS 5~-~29-2~486. RECEIVED JAN 1 0 199~- Alaska Oil & G~s Cons. Commission Anchorage Prudhoe Bay Drilling To: Doyon 16 Rig Supervisor From' Bill Kirton /~1/~ ARCO Alaska, Inc. ~- ~ , ~ ENG~ Date: Mon, Jan 6, 1992 ~TA~HI , Subject: ,D,,S ,14-14i Completion The 9-5/8" production packer in DS 14-14i has pressure tested to 3500 psi but the tailpipe does not hold pressure. It is felt that the FC plug in the X nipple has prematurely sheared. Please continue to run the completion as detailed in the program. Mike Minder at the AOGCC has waived the tubing side portion of the test provided the tubing side pressure is .recorded at zero during the tubing annulus test. Please fax a copy of the completed MIT form and the pressure chart to the AOGCC at 276- 7542 and to the 'Drilling Department. The annulus test should be at 3500 psi for 30 minutes. GWK:PGS:pgs CC: Mike Minder- AOGCC Jeff Hall Marty Lemon Phil Smith RECEIVED JAN - 8 t992 Nas~ 0il & Gas Cons. Commissie~ ~6.nchorage ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 December 12, 1991 L. C. Smith Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage AK 99501-3192 Re: Application for Sundry Approvals. Dear Mr. Smith: Please find enclosed the Sundry Approval Application for Drill Site Well 14-14. Sincerely, D. Gilleqt~fie Operations Superintendent dDG/enh RECEIVED DEC 2 6 1991 AI~ 011 & Gas Cons, Commission Anchorage ALA(~KA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Repair well__ Plugging ~ Time extension ~ SlJmulate ~ Change approved program __ Pull tubing x Variance__ Perforate__ Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory ~ Stratigraphic ~ Service 6. Datum elevation (DF or KB) RKB = 71 feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 8. 1284' FNL, 1044' FEL, SEC 9, TION, R14E UM At top of productive interval 9. 2498' FNL, 129' FWL, SEC 11, TION, R14E UM At effective depth 10. At total depth 2470' FSL, 242' FWL, SEC 11, TION, R14E UM Well number DS 14-14 Permit number 81-102 APl number 50- 029-20625 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 12327 feet 9454 feet 12277 feet 9408 feet Size Plugs (measured) Junk (measured) Cemented Measured depth 13-3/8" 9 -5/8" 300 sx PermaFrost 2600 ax AS/Il & 400 ex ASII 500 sx G 110' 2632' 11358 1237' 7" 350 sx G 12322 measured 11570'-11588', 11602'-11640', 11650'-11670', 11690'-11710' true vertical 8839'-8951' Tubing (size, grade, and measured depth) 5-1/2" L-80 @ 11100' True vertical depth RECEIVED Nat~ .Oll & Gas Cons. commtSs~e' ~/~j~ttorage. Packers and SSSV (type and measured depth) Baker 'SAB'Packer @ 11028'; Camco 'Bal-O SSSV @ 2264' 13. Attachments Description summary of proposal X ,,,, 14. Estimated date for commencing operation December29, 1991 16. If proposal was verbally approved Name of approver Date approved Detailed operations program BOP sketch 15. Status of well classification as: Oil Gas Service Seawater Injector Suspended 17. I hereby certify that th~{0re~oing is true and correct to the best of my knowledge. Signed ~..~ ~,~, ~.3~~ Title WorkoverSuperintendent \ FOR COMMISSION USE ONLY lConditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Original Signed E~y Approved by order of the Commission David W., Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PRUDHOE BAY DS 14-14 PROPOSED WORKOVER PROCEDURE SUMMARY Rig: Doyen 16, Standard Pad to Pad Move Timing: Est 12/23/91, 11 days Workover Fluid/Pressure.' 8.5 ppg seawater/3650 psi @ 8800' TVD pre-Riq Work 1. RU WL and a lubricator. RIH and pull the 5-1/2" SSSV at 2269'. 2. RU electric line and RIH with a 5-1/2" chemical cutter. Cut the tubing @ +/-11,000" (in the top of the first full joint above the PBR). 3. Freeze protect to 2000' with diesel. Bleed the tubing, inner annulus, and outer annulus to 0 psi. 4. Install BPV. Remove flow line. Dig out cellar & level pad. Ria Work -- 10. 11. 12. 13. 14. 1 MIRU Doyen 16. 2. Pull the BPV. Circulate the diesel from well, Save the diesel to freeze protect with at the end of the well. Install a 2-way check valve. 3. ND the tree. NU and test the BOP's to 250/5000 psi. Test the casing packoffs. 4. Pull the 5-1/2" tubing. The tubing will be junked. Note the condition of the tubing and location of any holes on the morning report. 5. RIH with a mill/overshot to the tubing stub. Attempt to release thee C E IV E D Baker K anchor without shearing the PBR. If needed, shear seal asssembly and make a second tdp to recover PBR. DEC 6. RIH with a PRT. Mill out and retrieve the 9-5/8" Baker SAB pa.c.ke.r, 7. RIH with a bit. Clean out fill to 11,900'. A~asKa 0il & Gas Cons. commissle~ " 8. RIH w/a 9-5/8" and 7" scraper spaced out to 11,750'. Anchorage 9. RIH with a 7"RBP & 9-5/8" test packer. Test the casing and liner lap to 3500 psi. Displace well to clean, inhibited seawater. POOH and LDDP. RU e-line. Run GR/JB to 11,750'. Set 7" isolation pkr on e-line. Run GR/JB to TOL. Set 9-5/8" pkr with solid FC plug in tailpipe on e-line. RIH with the 5-1/2" completion string. Space out and pick up the tubing hanger Displace 140 bbls diesel down the tubing. U-tube the diesel between the annulus and the tubing. Land the tubing. RILDS. Install the 2-way check valve. ND BOP's. NU a new 5" tree and test it to 5000 psi. Set the BPV. Release the dg. G. T. Goodrich Drilling Engineer 12/18/91 BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PS1 WP TR! PLE RAM STACK WORKO VER RISER I ANNULAR PREVENTER 2" KILL LINE MANUAL GATE HYDRAULI C GATE I PIPE RAMS I PI PE RAMS I DRILLING SPOOL 4" CHOKE LINE HYDIqAULIC MANUAL GATE GATE I, BLIND RAMS I , STATE OF ALASKA ALASKA {/ AND GAS CONSERVATION CO~ 'lSSlOl~ II~ I 6 I ~ ~ [ APPLlCA'I ,ON FOR SUNDRY APFrtOVA-LS 1. Type of Request: Abandon-- Suspend Operation shutdown -- Alter casing-- Repair well -- Plugging -- Change approved program Pull tubing Variance 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360,.Anchorage, AK 99510-0360 4. Location of well at surface 1284' FNL, 1044' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2498' FNL, 129' FEL, Sec. 11, T10N, R14E, UM At effective depth 5. Type of Well Development -- Exploratory Stratigraphic Service X At total depth 2470' FNL, 242' FEL, Sec. 11, T10N, R14E, UM 12. Present well COndition summary Total depth: measured 12327' feet true vertical 9454' feet Plugs(measured) None Effective depth: measured 12277' feet true vertical 9408' feet Junk(measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Re-enter suspended well Time extension Stimulate Perforate Other X 6. Datum of elevation(DF or KB) 71' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 14-14 9. Permit number 81-102 10. APl number 50 - 029-20625 feet 11. Field/Pool P_rud_hoe B_a¥ ,0~ ~Oll~ K'l: .l:lV DEC 2 6 1991 Non~laska 0il & Gas Cons. C0mm[ssion Anch0ra~e Measured depth True vertical depth 81' 20" 300 sx Permafrost "C" 110' 110' 2603" 13-3/8" 2600 x Fondu & 400 sx AS II 2632' 2632' 11332' 9-5/8" 500 sx Class G 11358' 9087' 1243' 7" 350 sx Class G 11085 - 12322' 8881' - 9449' measured 11512'- 11552', 11557'- 11567', 11570'- 11588', 11602'- 11640', 11650'- 11670' 11680'- 11710' true vertical 9203' - 9233', 9237' - 9244', 9246' - 9260', 9270' - 9298', 9306' - 9321 ', 9328' - 9351' Tubing (size, grade, and measured depth) 5-1/2" /4-1/2", L-80, w/tail @ 11100' MD Packers and SSSV (type and measured depth) Baker "SAB" pkr @ 11028', Camco BAL-O sssv @ 2264' 13. Attachments ' ' Description summary of proposal ~ Detailed operations program __ 14. Estimated date for commencing operation ~ 15. Status of well classification as: Continue on H20 injection - Per Verbal Notice 16. If proposal was verbally approved Lonnie Smith 12/5/91 Name of approver Date approved Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~' ~/, /~%~' ~.~.?,~c_~- Title Operations Superintendent ? FOR COMMI~.~ION U~l= ONLY Conditionsof approval: No~tliiy Commission so representative may witness Plug integrity . BOP Test Location clearance ¢ Mechanical Integrity Test Subsequent form required 10- Wo,~ Approved by order of the Commissioner ,,, Original Signed By David W. Johnston BOP sketch Oil __ Gas __ Suspended __ Date i Approve, ~pprovec~ CoPY ~Returned ~o Form 1.0-403 Rev 06/15/88 W. J. O'Brien PRB-24 659-5102 DS 14-14 Annular Communication Action Plan Discussion Recent diagnostic work indicates that the tubing has two holes (105' and 11,016' ELM). There is no evidence of 9-5/8 x 13-3/8 communication. The following plan is proposed: Plan 1. Continue on seawater injection until its rig workover. The workover is scheduled for mid-January, 1992. RECEIVED DEC 2 6 199! Alaska Ol~ & Gas Cons. Cornmissien Anchorage STATE OF ALASKA ALASKA( '_ AND GAS CONSERVATION APPLICA, ION FOR SUNDRY APPROVArS' 1. Type of Request: Abandon Suspend Operalion shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension SlJmulate Change appro"~ program '~11 tubing -'-- Variance Pe~te X Ot--"~ 99510-0360 5. Type of Well Development -- Exploratory Stratigraphic Service X 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 4. Location of well at surface 1284' FNL, 1044' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2498' FNL, 129'FEL, Sec. 11, T10N, R14E, UM At effective depth RECEIV£D DEC - 199t At total depth 2470'FNL, 242' FEL, Sec. 11, T10N, R14E, UM Alaska 0ti & Gas Cons. Anchorage 12. Present well condition summary Total depth: measured true vertical 12327 feet 9454 feet Plugs(measured) None 6. Datum of elevation(DF or KB) 71' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 14-14 9. Permit number 81-102 10. APl number 50 - 029-20625 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12277 feet 9408 feet Junk(measured) None Length Size Cemented Measured depth True vertical depth 81' 20" 300 sx Permafrost "C" 110' 110' 2603' 13-3/8" 2600 sx Fondu & 400 sx AS II 2632' 2632' 11332' 9-5/8" 500 sx Class G 11358' 9087' 1243' 7" 350 sx Class G 11085-12322' 8881-9449' measured 11512'-11552', 11557'-11567', 11570'-11588', 11602'-11640', 11650'-11670', 11680'-11710' true vertical 9203'-9233', 9237'-9244', 9246'-9260', 9270'-9298', 9306'-9321', 9328'-9351' Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, w/tail @ 11,100' MD Packers and SSSV (type and measured depth) Baker "SAR" pkr @ 11,028', Camco BAL-O sssv @2264' 13. Attachments Description summary of proposal x Detailed operations program ___ BOP sketch x 14. Estimated date for commencing operation 4Q 1991 16. If proposal was verbally approved Oil _._ Name of al)prover Date approved Service 17. I hereby certify that thefo~ .)ing is true and correct to the best of my knowledge. Signed :~~/~ "~:,~'~/~v~~ Title FOR COMMI~II3N H~I= ONLY 15. Status of well classification as: Gas ..._ Suspended .-_ Water Injector Conditions of approval: Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 cc: SW (2), JWP ORIGINAL SIGNED BY Ir~NNIF C, SMITH SUBMIT IN TRIPLICATE , , PRO (1~ SUMMARY OF ' ARCO Alaska, Inc. proposes to shoot additional perforations in DS 14-14 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit. This well will be perforated approximately 500 psi underbalanced and flowed to clean up (the expected bottom-hole pressure is 3650 psi). All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed perforation intervals: 11752-11770'MD 11774-11802'MD 11806-11834'MD Reference Log: BHCA 10/21/81 REC£1 ED DEC; - ~) t99t Alaska Oil & (~as Cons. Gom~ss'~o~ Anchorage 6 3 2 COILED IUB[NO UNIT BOP E0U ! P,£at 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSi 4 1/16-PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" .~q£AR RAMS ~. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFINO BOX RECEIVED DEO - ~ 1991 taka Oil & Gas Cons. Co Anchorage H]REL]NE BOP EOU]PHENT _ 1. 5,000 PSI ?" WELLHEAD CONNECIOR IrLANGI 2. 5000 PSI WlRELIN[ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Olrlr ARCO ALASKA, INC. F'.O. BOX i88368 ANCHORAGE, ALASKA DATE' 7-3~-9t REFERENCE' ARCO CASED HOLE FINALS ~ -22 7-3-9~ ~ -24 6-27-9~ ~ -25 7-4-9~ 2-9 6-29-9~ 5-3 6-23-9~ 9-2 7-8-9~ 9-35 7-8-9~ J3-t .~ 7-6-9J t 4-t 4 7-5-9~ * ~ 7-t t 6-20-9t t 7-t t 6-20-9t t8-7 7-5-9t t 8-t 7 7-5-9t PROD PROFILE PROD PROFILE PROD PROFILE PROD PROFILE PROD PROFILE LEAK DETECT LEAK DETECT LEAK DETECT LEAK DETECT LEAK DETECT CASING INSPECTION CALIPER LEAK DETECT PROD PROFILE PROD PROFILE PROD PROFILE RUN I , 5 · RUN i, 5 · RUN t, 5' N~sk3 Oi~ & G~s Goos. ~omm~S~N t, 5 ' & i G" &n~bo~s~e RUN i, 5" & i O" RUN t, 5' RUN'i, 5' RUN i, 5' RUN i , 5' RUN t, i'&5' RUN i, 5' RUN i, 5' RUN i, 5' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY ___ HAVE A NICE DAY! $ONYA WALLACE AT0-i529 APF'RovEDt~ TRANS.'9 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D &M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS PB WELL FILES R & D BF'X STA]'E OF ALASKA TEXACO * THE CORRECTED BOTTOM LOG INTERVAL I$ 4,900 FEET STATE OF ALASKA ALASKA {r AND GAS CONSERVATION COI('~'~ ISSION APPLICA'I,ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing ....- Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Suspend ..--- Operation shutdown Repair well Plugging Pull tubing Variance 5. Type of Well Development _,_ Exploratory Stratigraphic serv~ X 4. Location of well at surface 1284' FNL, 1044' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2498' FNL, 129' FEL, Sec. 11, T10N, R14E, UM At effective depth At total depth 2470' FNL, 242' FEL, Sec. 11, T10N, R14E, UM Re-enter suspended well Time extension Stimulate Perforate ,,,.mm. Other X 6. Datum of elevation(DF or KB) 71' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 14-14 9. Permit number 81-102 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12327' feet 9454' feet Plugs(measured) None 12277' feet 9408' feet Junk(measured) None Length Size Cemented 10. APl number 50 - 029-20625 11. Field/Pool Prudhoe Bay Oil Pool RECEIVED d U L 1 2 1 91 Alaska 0ii & Gas Cons. CQm~[~tl Measured depPgllCllb/a~iertical depth 81' 20" 300 sx Permafrost "C" 110' 110' 2603" 13-3/8" 2600 x Fondu & 400 sx AS II 2632' 2632' 11332' 9-5/8" 500 sx Class G 11358' 9087' 1243' 7" 350 sx Class G 11085 - 12322' 8881' - 9449' measured 11512' - 11552', 11557' - 11567', 11570' - 11588', 11602' - 11640', 11650' - 11670' 11680'- 11710' true vertical 9203' - 9233', 9237' - 9244', 9246' - 9260', 9270' - 9298', 9306' - 9321 ', 9328' - 9351' Tubing (size, grade, and measured depth) 5-1/2" / 4-1/2", L-80, w/tail @ 11100' MD Packers and SSSV (type and measured depth) Baker "SAB" pkr@ 11028', Camco BAL-O sssv @ 2264' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch . 15. Status of well classification as: Oil __ Gas __ Suspended Water Injector ~ ,, ,, I Approva, No.~/...~ 14. Estimated date for commencing operation Continue on H20 injection only - Per Verbal Notice 16. If proposal was verbally approved Name.of approver Date approved Service . , I 17. I hereby certify that the foregoing-i~true and correct to the best of my knowledge. I I Sign e~-~J~m~~ ~~ .. Title Ope rations Su pe ri ntende nt I ~,,/ FOR COMMISSION URI= ONLY ' ~ns of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Commissioner ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C,,~SMiTH Date 7/ SUBMIT ~T~IP~LL~ATE Form 10-403 Rev 06/15/88 W. J. O'Brien PRB-24 659-5102 DS 14-14 Annular Communication Evaluation Action Plan Discussion Tubing X 9-5/8" communication is suspected. The 9-5/8 annulus pressure matches the tubing pressure. Liquid leak rate was measured at 7 gpm at 1300 psi down the 9-5/8 annulus. The following evaluation plan is proposed: Plan 1. Return well to seawater injection (SWI) only. 2. Install a standing valve in the tubing tail. 3. Perform a spinner/temperature log to locate the source of the tubing x 9-5/8 communication. Alaska Oil & ~s Cons. INJECTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC PER AREA INJECTION ORDER #4 DATE: 6/28/91 TIME: NOTIFIED BY: S. J. Massey AOGCC CONTACT: Lonnie Smith REASON: Injection Well 14-14 annular Communication per Rule 7 Requirements of Area Injection Order No. 4. DISCUSSION: Told Lonnie that we suspected TBGx9-5/8 communication in DS 14-14: the 9 5/8 was matching the TBG pressure (400 psig). First noticed leak Wednesday afternoon (6/26/91) during prep work for state MIT's. We can inject down the 9-5/8 at 10 gpm at 1300 psig. We would like to continue injection until the well can be completely evaluated. AOGCC RESPONSE: Verbal approval to continue injection. Sundry notice needs to be filed. Sundry Notice Req'd at this time? YES - . Signed' NO DS Supv. Sr. Well Supv. FS Supt. Field Area Ops. Engr. Annular Comm. Spec. U L t 2 & Gas Cons. Co,mmV, ssi0~ Anchors, ge TESTED BY: ANNULAR LIQUID WELL# /'~/-? ~ COMMUNICATION TEST LEAK RATE TYPE OF TEST: ~..'.=j I~LRT SPECIAL INSTRUCTIONS: INITIAL PRESSURE DATA TIME: //~) HRS (ARRIVAL ON LOC.). WELL STATUS: FLOWING / INJECTING / SHUT IN TaG ~/'~O PSi 9-5/8" ~-~'~ PSI 13-3/8" ~/~/O PSI SSSV CONTROL/BALANCE LINES TBG HANGER TEST PORT CAVITY: / PSI ~' PSI BLED' TO 0 PSI? ~~_~ FLUID BLED: 9-5/8" TEST PORT CAVITY:. ~' pSI. BLED TO~0 FLUID BLED:..,/". PRE-.TEST: PREPARATIONS . TYPE OF-FLUID AND~ VOLUME BLED: TUBING LOADED W/ BLS CRUDE + ,, 9-5/8" ANNULUS BLED F/ PSI TO TYPE OF FLUID AND VOLUME BLED: f' 9-5/8" LOADED W/ ~ BBLS CRUDE + ~ 13-3/8" ANNULUS BLED F/ i PSI TO ,.~ TYPE OF FLUID AND VOLUME BLED: BBLS DIESEL PSI BBLS PSI 13.3/8" LOADED W/ //~ BBLS CRUDE + ~ BBLS DIESEL TIME (HOURS) TEST DATA PRESSURE DATA PACKOFFS TUBING / 9-5/8" / 1:~-3/1)" TUBIN~I /~ VOLUME /--'~ VOLUM ! (INCHES1 (B,.B LS', /_L/_Yo / ~,_~__ / TOTAL / / I VOLUME': PUMPED: /1.9~ BBLS,~ ......... AVERAGE~ RATE: ,~;'~. : PUMPING COMMENTS.:' RATE STEADY? YES/NO .... FINAL PRESSURE DATA' WELL STATUS: FLOWING~SHUT llq R[CEIV D ~?/~ PSI 13-3/8" ' /-/~0 PSI TIME: /)/~ HRS TBG .,D~ PSI 9-5/8" SSSV CONTROL/BALANCE LINES TUBING HANGER TEST PORT CAVITY: 9-5/8" TEST PORT CAVITY: .~ / PSI PSi PSI BLED TO 0 PSI?4:~~I~LQ Revised 2/12/91 ANCHORAGE, ALASKA I)~TE: REFERENCE' AF,'CO 3--6 4-20-9 S-i t 4--~ 6-9~ S-J2 4-t9-9~ S-~ 4 4-22-9t S-23 4-i 6--9i 4-5 4-20-91 4- i 4 4-3'3-9 i 5..-S 4 .... 26-9i i5-6 4-.29-9i 6-7 4--2(~-9i i 6-.i 2 4-27-9i 8-i i 4-29-9t CASED HOLF FINALS IN J, PROF, INJ. PROF. INJ, PROF, PROD F KC F [;AS ENTRY G~S LIFT IN J, PROF. F' R 0 D, F' R 0 F', PROD, PROF'. G~S LIFT PROI) F RL F'. TEHF', RUN RUN I:;:UN RUN RUN Ii:UN RUN R U N R !J N RUN RUN i w t, t, t, t, t, t, i, i, t, t, t, # "2" & 5 · 5" 5" 5" 5:" CAM[:[) CAMCO CAMCO C A M C 0 C A M C 0 CAMCO C A M C 0 C A M C 0 CAHCO C A H C 0 C A M C 0 · . - ~ .. · ·. FLEASE SIGN ANI) RETURN I'FIE ATTACHED COF:'Y AS RECFIPT OF' I)Al' HAVE A NICE DAY~ ' $ONYA WALLACE ATO-t 529 A & · -- 'TF:ANS~ 9 i~'?'i~':: DISTRI:BUTION . - CENTRAL FILES '"' CFIE:VRON '!1' D & H · '.": EXTENSION EXF'LOR~I'ION ,-~' EXXON HhRAI'HON ~ MOBZL. ~ - F'FIlI..LIPS F'B WELL F'IL. ES R & D ""'... BF:'X · ..*S'II'AI'E OF ALASKA I'EXA[:O A R C 0 A t... A,S' K A: .I] N C :. I::'., O, BOX ANCHORAGE, AI..ASI(A '?'~5~ (') DATE:: 6-':22-'89 REF'ERENCE' ARCO CAGED HOLE FINALS -' i ::' ;' "' "' t -'t 9 4-.t 4-8? COLI..AF~,, I E..RF I:(UN t, 5 3-7 6-'?-89 INJECTION PROFILE RUN 'i, 5" 3-i 2 6 '" t 2-89 PE:RF F,,EL,:...~RD F;,'.L.IN t" '1 ~' "l .... !" .-- - .~ , 4-'S 4-t4-89 COI_I_AI',,, I- L. RF RUNS 4-t ~: 6-. t t -.89 COI...i_A '" /" "" ... ., k, FE. RF F(UN t, '::, 4-2(~, 6-2-89 INJECTION F'I:;:OF'ILE F;:tJN t, .~-' t 2 6'" :.~-' 139 P ]: T ~',,' R U N i , "-~" 5-' t ;~ 4- ''~ ":~' ,c < ...... , * ", '" ,,...:,"- ..i '2 C 0 R U N t , LL. AR/F ERI- 5" .,i '1 .... i ''),:. "" '$. 6 "" 4 '-~:i.::. <:;': (:; A ,<~' I.. I F:' T ,~ LJ I:,~ ¥ E. Y R U N i , '.i):" i 2'-3°,. ~..6-t 4""89 COLI_AR/PERF I'<UN i, ':;"., t 4- t :3 6 - .3 - 89 :1: N d i:.:: C T I 0 N P R 0 F: I L E: R U N t t4-i.4 .6-JJ-8~ IN,JEC'FION PROFILE RUN 'i, 5" t ~'~"-' 4 6- 4"" 139 L E: A I<: D E l' ~:.:'C"I" .l: 0 N R U N i , t" · ? -"" · "1 / "1 '" i" t.5-t5 ~-t ?--89 ~.)L.I..~, I-E-RI- RUN I , t 6-"? 4-"28-'8~ COL. I_AR/F'E:F~F' RLJN t , 5" t8"-2J '5--Ji'-8~ F'IT$ RUN t , 5 F'I_E:ASE SIGN AND REI'LJRN THE ATTACHED COPY AS RECEIF'T (.:iF DA'FA, HLS CAPiCO $C:H HI_.S A '1' I..A :~;' L:AMI:::O C A M C O HLS C A t'~ C 0 A1 l_ A ;.~' CAHCO C A M C 0 CAHCO ~ fi_AS I.-II.S CAMCO HAVE A NICE DAY! ATO-i 529 TRANS:~ 8926S ,,. Alaska Oil & Gas Cons. Commission Anchorage D I SI'R I B U l' ]: 0 N C ... ENTRAL FILES ~ PHIL. LIP,<;'. CHEVRON F'B WEL. L F'ILEi. S D & M R &'D EXTENSION EXPLORATION ...'"' BF'X EXXON .,'"'STAI'E OF AL. ASKA MARATHON - ..-'"' TEXACO MOBIL . STATE OF ALASKA ' ALASK .....L AND GAS CONSERVATION C~ ~MMISSION .~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISED 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-102 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK '99510 50- 029-20625 ,,, 4. Location of well at surface 9. Unit or Lease Name 1284' FNL, 10~+~' FEL, Sec. 9, TION, Eld+E, UH Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2498' FNL, 129' FWL, Sec. 11~ T10N, RI#E~ UM 14-14 ....... At Total Depth 11. Field and Pool 2470' FSL, 242' FWL, Sec. 11, T10N, R14E, UM Prudhoe Bay F~eld 51 Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Ba.y 0i ] Pool RKB 71'I ADL 28312 , , , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. i5. Water Depth, if offshore 116_No. of Completions 10/02/81 10/21/81 10/26/81 N/A feet MS L . . 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) i9. Directional Survey 20. Depth where SSSV set 21. Thickness Of Permafrosi 12327'ND, 9~+5~+'TVD 12277'ND~' 9~08'TVD YES ~ ... NO [] 2270' feetMD .. 1900] (Approx) ... 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Ca]. GR/CBL~ CBL/VDL/GR/CCL~ G.Y. ro-Nu]tisho.t ................ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ......... 20" 9.~# H-z~0 Surf 110' 32" . 300 sx PF ........ 13-3/8" 72# L-80 Surf 2632' 17-1/2" 2600 sx AS I I I & ~00 ex! AS i I 9-5/8" ~+7# L-80 & Surf 11358' 12-1/M' 500 sx £1a~ C n.m~_ .... S00-95 i 7" 29# L-80 11, 085' 12322' 8'1/2" 350 sx C] ass G cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING REcoRD ........ interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ....... 5-1/2" 11100' . . 110.~ Ref: BHCS 10/21/81 11570-11588'MD , , 11602-116~0'MD 26. ACI D, F RACTUR E,' CEMENT SQUEEZE, ETc. 11650-11670'HD '"D'i~PTH INTERVAL (M'D) 'AMouNT & KIND OF MATERiAL"USED' ......... 11690-11710'MD N/A 88:39-8951 'TVD ................. 27. PRODUCTION TEST ,, Date First Production I Method of Operation (Flowing, gas lift, etc.) 7/15/82 ,I FI owi ng , , Date of Test` HoUrs Tested PRODUCTION FOR OI L-aBE 'GAS-McF WATER-B'BL CHOKE SIZE I GAS'~oIL RATIO' .......... ,8/28,/82 6.1 TEST PERIOD ~ 1186 787 ,0, ,69 ....I ~ .... , __ ,, , Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) ,,P,ress. 973 N/A 24-HOUR RATE .~F Z~667 3098 0 27.0 28. CORE DATA Brief descrip~!°n of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ;, · Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SlD~c1:17~:DANI Submit in duplic~ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . Top Sad] erochi t 11509 ~ 8790 ~ N/A Base Sadlerochi t · 122;37 ' 9379 ~ · _ . . · · . ~ · .... 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is' true and correct to the best of my knowledge Signed ~ OJ~/'~ ~/ ~./~ Title Associate Enqineer Date /-b--~7 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'combustio~n. 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 produci'ng intervals for oQly the interval reported in item 27. Submit a Separate form for each a~,ditional interval to be separately'Produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing artd~e.!locatio~;~)f the cementing tool. ~ ~ ' ;:' i ~ ..,-? Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item: 28':il.f no'cbrbS'~ak:ea:, indicate"n. o n e." Form 10-407 ARCO Cased '"::.' -2-~:::,F.: ~_-'-.- -.-.£- 8~, 5:-7-86 _=--':-.--'"-86 .-' 26-85 ::-P ~ 'q _- ~: L'-"F ¥ ~ ~ T,.i _- ~ -' ~-,' :~ ,..~" U~] ~i r.-,_.. 2 '; ~ ! C.) C: T i C: 'i"..' t' )- '.'.2 ~ [ ~ e Fi tl '.'] T e .,'a ;:.' ~---': '/' .3 t ~ 'r e ."?. ~'.:- v e y ::;1E'n i'Q iE~C:T i C:,.] P'i-GT ~ i.e ?"-t~i-i 'i _: -. i n j e c: t i c)'n 5"~- c-.- f i ~ e f.: u 'ni 5 ' '"':p i i".':, i_..:5~ '"'.,"~j · [:".,-Of , i---.'.Li..~i 'i '="~_.- ~;F-i "~i",el- E:u~-vey .F-.:un 'i. _., '~'-' ~ .... *~ .... F"?c, f i[e R~n ~ _:- r'-~ o.. :... !'njec:±icn ~-.,,_~t; ;e Run r: .... ,-, ..... :-,,.=- ~ :..- ,-..- ,-- _.- C. a i~'., :.2 .... {_.a i'fiC 0 C} a .~,~ '-.':: c~ Ca {:'~C .'-Z, ;... ....... :...-~ i~! _ ._ i_:a f~i ,.'E_ ,3 C.: a i'i'i C' 0 ,_, a IDC © C:a mC 0 · ~a mc o · 3f data. <. ARCO Alaska, Inc,." Post Office'*==X 100360 Anchorage, Alaska 99510 Telephone 907 276 121'5 Date.: February 11, 1985 Reference: ARCO Pressure Reports 2-10 ~/Static Gradient 1-26-85 Camco 5-2~Static Gradient 1-24-85 Camco 6-3 ~Static Gradient 1-23-85 Camco · {-14~14~ressure Fall Off 12-2-84 O0 15-8 ~-S'tatic Gradient 1-25-85 Camco ~5-9 ~Static Gradient 1-25-85 Camco 15-16"~tatic Gradient 1-25-85 Camco 15-20/Static Gradient 1-25-85 Camco 17-9 ~Static Gradient 1-27-85 Camco P~~lease sign and return the attached copy as recipt of data. Received by Pam Lambert , ATO 1429C Trans O2% Chevron EXploration Services. Extension Exploration Texaco Marathon Mobile E & P ~illips ~'~.~hc~' BaY Well Files ~'~ D ~~;~l~sk~-. ARCO Al~sk,,. Inc. Is · Suhsldtlry of AtllntlcRichfieldComplny ARCO ALa:.?ka, In P,.O~ Box t00360 A'nchor~ge, ALa_~R~ D,. ,S', "i:'4"= i 4 ? i i .... 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'"' ,:!':, '"' S.-,-'",..-,:" ,':;'-. 1'7 ,:. .,:i .... ,:::, z:. L.. i" ,.'.'..." ,.':. r.) i 'i"i 'i", (..'-.', 'i" .J:;.'. i": ...... i2 .... "'/' ' ,:::, ..,. :() i I:' f' 'i" ,,". m ;:'., r-, .-q F;.: i 2 ..... ~:':::'.., .":..,(::: F:' :':-.' ,." ::: r:' i n n ,.':.:, r i 2 .... i .... :3,:I. D i 'i" i:' .,r e mi:' iN.' 4 ."'.,....,':, ,':,. ,':, <.~ " ' , -".. .,'.. ~' .... ::' ;' ,? F:: i i"i i"i (E' i" J... C) g 4 "').... ")"':: . ."')..'l '~ ' I ...... '"' ~ .,' ..... '-- ~:.'::; "~' J:':. i::: ; 'i'l i'i (':'? l" ,'"~ ':~,,' ...... I ......... t. J'i "'" "'~ ' :.J Ev ,. :.: i i i '!.' J'i (-.'..': .:'.-i ,. ,..:':i C: ::: :.,. C (:)!::' 'y' .3 <-': 'i- ~::: F' ~:'.: : :::: .t-,. ,:::, :.,:' Chevron Mob i L i'; &: H Hr;l:.', i t. '::' :"" F:' ExpLoration Service:'.¢' Phi L L ip.'_~ E × t e n s' i o n E x p I. o r a t: i o n f:" r u. ,::J h ,:::, e !-) ..'-', ':/ t.d ,z.:, I. L Exxon Fi: &. g Gei'~y Soh i o i"ia'~".:':'~ th,:::,r~ State o'f A La.ska i" I L ,::.::. ARCO Alaska, inc. Post Offic~~ ~x 360 Anchorage[ ,aska 99510 Telephone 907 277 5637 April 13, 1984 Reference: ARCO Cased Hole Finals D.S. i-iA 2-3-84 D.S. 9-21 2-6-84 D.S. 9-22 ~/ 2-1-84 D.S. 12-25/ 1-29-84 D.S. 12-25~ 1-29-84 D.S. ~ 14-14~ 1-12-84 D.S. 17-6'/ 3-24-84 CBL/VD Gyro Continuous Tool GR CBL/VD CET EPL Collar/Perf 'Ran 1 5" Sch Run 1 Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" GO se sign and return the attached copy as receipt o'f data. FRIDAY THE 13th is upon us - Have a Nice One! Kelly McFarland ATO-1429F Trans. #144 DISTRIBUTION Chevron Mobil D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Sm it ~ .~/~/~ ~~ ~:~ Sohio State of Alaska .~:~ska 0~] & Gas Corns. Commission Anchorage ARCO Alaska, Inc. Post Offic~.~ .nx 360 Anchorag~ aska 99510 Telephone 907 277 5637 February 24, 1984 ? Reference: Arco Pressure Data D.S. 7-2 z'/~' 1-20-84 D.S. 11-2 ~-1-18-84 'D. S. 13-.19 ~-12-28-83 D.S. 13-21'~1'2-84 D.S. 14-14 '-~-12-84 D.S.18-1f 2-4-84 2-4-8 PBU Data Sheet PBU Horner Plots w/Listing Horner Plots w/Listing Horner Plots w/Listing PBU . PBU Data Sheet DA Sch Sch Sch Camco se sign and return the attached copy as receipt of data. HAVE A NICE DAY! Kelly McFarland ATO-1429F Trans. f~ 069 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe Bay R & D Caroline Smith Sohio State of Alaska Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 29, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re- DS 13-6 Permit No. 81-121 DS 13-9 Permit No. 81-158 DS 13-19 Permit No. 81-180 DS 13-21 Permit No. 82-53 DS 13-24 Permit No. 82-65 DS 14-13 Permit No. 81-101 ~'~DS 14-14 Permit No. 81-102 Enclosed are the Completion Reports for work done on the above-mentioned well s. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lw Enclosures cc' Sohio Petroleum Co. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ' OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~X Water Injection ... ~. 2. Name of Operator 7. Permit Number ARCO Alaska, Tnt; 81-102 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50-029-20625 4. Location of well at surface 9. Unit or Lease Name 1284'S & 1044'W of NE cr., Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2A4tgl_8o' ~eNptLh, 129' FWL, Sec ll, T10N, R14E, UM U.S. 14-14 tal ° . 11. Field and Pool 2476' FSL, 234' FWL, Sec. 11, T10N, R14E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) t 6. Lease Designation and Serial No. Prudhoe 0i 1 Po01 RKB 71' -/ ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10/2/81 10/21/81 10/26/81I --- feet MSL) 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+l-VD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 12310'MD,9440'TVD 12277'MD,9408.'TVE YES[~ Nor--] 2270 feetMD 1900' (approx) ~2~:.Type Electric or Other Logs Run DIL/SP/BHCS/GR,FDL/CNL/GR/Cal. GR/CBL, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf llO' 32" 300 SX Permafrost 13-3/8" 72# L-80 Surf 2.632' 17-1/2" 2500 SX Fondu & 400 sx AS II 9-5/8" 47# L-80 &. Surf. 11358~' 12-1/4" 500 sx Class ',G,' cmt. soo-95 7" 29# L-80 11085'~ 12322' 8-1/2" 350 sx Class "G" cmt. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 1'11 O0" 1103.3 , 1 '"6.80 L'l 1r6'~}0I MD 4 spf ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 1:]'557' -11567' ~'MD ' ' ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 115t2'-11552' MD . 8793'- 8935' TVD .. Ref. BHCS 10/22/8'1 '~. i. 27. PRODUCTION TEST Date First Production " ~' I Method of operation (Flowing; gas'lift, etc.) Water In.iectionI N/A '"' .....' Date Of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OILRATIO N/A TEsT PERIOD J~ ' FIo~ Tubing Casing Pressure cALCULATED: , OI'L-BBL' : GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 'N/A 24_HOUR RATE --r ' ! 281 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, Top Sadlerochit Base Sadlerochit MEAS. DEPTH 11509' 12237' TRUE VERT. DEPTH 8790' 9379' GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Engi nec_r Date INSTRUCTIONS % General: This form is designed for submitting a complete and correct well completion report a~d.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. I.!;em 16 and 24: If this well is completed for separate production from more than one interval (multiple. c°mpletion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for ~this well should show the details of any multiple stage cement-' ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc.~r? Prudhoe Ba~, _ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 15, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.S. 13-2A D.S. 13-11 D.S. 13-13 D,S. 14-13 D.S. 14-14 Permit No. 83-21 Permit No. 81-76 Permit No. 82-178 Permit No. 81-101 Permit No. 81-102 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. S cheve DFS / TKKW/lmi At t achment s cc: Sohio Petroleum ARCO Aleeka. Inc lJ a S[.~bstdlary of AllanllcRlc;~fleldCornpany STATE OF ALASKA ALASKA ,L AN D GAS CONSERVATION C(~'vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LL~] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-102 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 029-20625 50- 4. Location of Well 1284'S & 1044'W of NE cr. Sec. 9, T10N, R14E, UM 2498' FNL, 129' FWL, Sec.ll, T10N, R14E, UM 2476' FSL, 234' FWL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 71' RKB 12. 11, T10N, R14E, UM I 6 . LeaSe Designation and Serial No. ADL 28312 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 14-14 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate J~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent detail~ and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for injection into the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Intervals 11512-11552' MD 11557-11567' MD 11680-11690' MD Ref: BHCS 10/22/81 ECEIVED APR i, 5 ~ ~. ~ Naska 0J~ & Gas Cor~s, Oommissio~ anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of ApprOval, if any: Copy ~turned ~ L~t~[F, a. S~f~ By Order of Approved by. COMMISSIONER the Commission . Date /7 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc/ Prudhoe B[~ jineering Post Office Bbx 360 Anchorage, Alaska 99510 TelephOne 907 263 4248 Donald F. Scheve Regional Operations Engineer February 2, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: D.S. 14-13 14'14 Permit No. 81-101 8'1-102 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc: Sohio Petroleum ARCO Alaska, Inc. 18. Subsidiary Of AtlanflcRIchfleldCompeny ALASK ' ILAND GAS CONSERVATION MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-102 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50- 029-20625 4. Location of Well 1284'S & 1044'W of NE cr. Sec. 9, T1ON, R14E, UM 9. UnitorLeaseName Prudhoe Bay Unit 2498'FNL, 129'FWL, Sec. 11, T1ON, R14E, UM 2476'FSL, 234"FWL, Sec. 11, T1ON, R14E, UM 5. Elevationinfeet(indicateKB, DF, etc.) 71' RKB 6. Lease Designation and Serial No. ADL 28312 10. Well Number D. S. 14-14 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice,' Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well · [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~' Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). I~-/~~ ~ ARCO Alaska, Inc. has converted well D.S.':l~=~to produced water injection servece. This well is part of the Flow Station 3 Injection Project and was intended for this service as indicated in the "Application for Approval as a Qualified Tertiary Recovery Project for Purposes of the Crude Oil Windfall Profit Tax Act of 1980, "(August, 1982). The well began receiving water on January 15, 1983. Notice of Intention" was not submitted. Note: Due to an oversight, the" ' P, EC'EIVED, FEB - 1983 Alaska OJJ & Gas Cons, Cornmissior~ Anchorage' 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. ~/~¢/ ~ ~, /~ ~/C~. Title Regional Operations Engineer Date The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Office Box 360 AnchorageK' '~ka 99510 Telephone[ .77 5637 December 22, 1982 RE: ARCO Cased Hole Finals D.S. 1-12-- 11-25-82 D.S. 1-18~ 11-24-82 D.S. 1-23 / 11-27-82 D.S. 2-6J 11-27-82 D.S. 4-11 f10-17-82 D.S. 12-4 ~ 9-26-82 D.S. 12-8B/11-25-82 D.S. 12-20J11-28-82 D.S. 13-18~ 9-28-82 D.S. 14-14~ 9-3/4/5-82 D.S. 16-12W 10-14-82 CH CNL Run 3 5" SCH CH CNL Run 3 5" SCH CBL/VD Run 1 5" SCH CH CNL Run 3 5" SCH Spinner 5" Camc Spinner 5" Camc CH CNL Run 2 5" SCH CBL/VD Run 1 5" SCH Spinner 5" Camc Spinner 5" Camc Spinner 5" Camc ~~P[ease sign and return the attic, bed copy as receipt of data. Becky. Benedict AFA - 403 Trans. #671 DISTRIBUTION NORTH GEOLOGY R'&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS ARCO Alaska. Inc. ts a SuDslcl'mary of AtlanticRichfieldCompanv ~las~a, Inc, Post Office~ox 360 Anchorag~ ska 99510 TelephoneX~ur 277 5637 November 15, 1982., Re: ARCO Pressure Data D.S. 14'13 10-6/7-82 D.S. 14-14 9-3/5-82 D.S. 14-20 · 9-2-82 D.S. 17-9 10-8-82 Pressure Build-Up Survey Pressure Build-Up Survey Pressure Build-Up Survey Pressure Build-Up Survey ~Please sign and return the attached copy as receipt of data. Camco Camco DA DA Becky Benedi ct AFA - 403 Trans. #610 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ~Xo;OI~ ~Cho/~g~, 6om%s/o° GE~Y D&M STATE OF ALAS~ DALLAS September 22, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re: D.S. 12-14 - Permit No. 81-138 D.S. 13-8 - Permit NO. 81-148 D.S. 13-12 - Permit No. 80-142 D.S. 14-13 - Permit No. 81-101 D.S..14-14- Permit No. 81-102 D.S. 14-15 - Permit No. 81-84 Enclosed are Completion Reports for work done on the above- mentioned wel 1 s. Very truly yours, D. F. Scheve Regional Engineer DFS:TKKW'skh Enclosures cc' Sohio Petroleum Co. AI:ICO Alaska. Inc. is ,~ subsidiary o! AII3nticFlichf~'~ldComp~ny WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well .. OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-102 3. Address 8. APl Number P. O. Box 360; Anchorage, Alaska 99510 5o- 029-20625 4. Location of well at surface 9. Unit or Lease Name 1284'S & 1044'W of NE cr. Sec. 9, TION, R14E, UM Prudhoe Bay Unit At Top Producing Interval ~ "10. Well Number 2498'FNL, 129'FWL, Sec. 11, TION, R14E, UM U.S. 14-14 At Total Depth 11. Field and Pool 2~7~'F.SI _ 23~,'FWI S~r. Il TIDr; R14E; lin Prudhoe Bay Field 5Tl~l'ev-ati~n i~ ~eet '(indicate K~B, DF,-e~c.) 6. Lease Designation and Serial No. Prudhoe 0i 1 Pool RKR 71' ADI 29312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15..Water Depth, if offshore I16. No. of Completions 10/2/81 10/21/81 10/26/81.I --feet MSLI 1 12310'MD 9440'TVD 12277'MD 9408 ' T\ [~ES E[ NO[] 2270 feetMD 1900' (approx.) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDL/CNL/GR/Cal. GR/CBL, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 110' 32" 300 sx Permafrost 13-3/8'I 72# L-80 Surf 2632' '17-1/2" 2500 sx Fondu & 400 sx AS II 9-5/8" 47# L~80 & Surf 11358' 12-1/4" 500 sx Class "G:' cmt. S00-95 7" 29# L-80 11085' 12322' 8-1/2" 350 sx .Class "G" cmt. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MI]) 5-1/2" 11100' 11033' Ref° BHCS 10/21/81 11570-11588'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11602-11640 'MD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11650-11670'MD · 11690-11710'MD ~ ~,~2 i ¥ F. 8839-8951 'TVD. -- - ,. 27. PRODUCTION TEST SE?~ Date First prOductiOn i Method of Operation {Flowing, gas lifL etc.) 7 / 15/82{ F 1 owl n g Alas~ Olt & ~" Conm. Commission , . , Anchorage Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 8/28/82 6.1 TESTPERIO.D"~'' 1186 ' 787 0 69I 664 Flow Tubing Casing Pressure · CALCULATED O L:BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 973 : N/A ' 24'HOUR RATE ~ 4667 3098 0 .27.0 "2~. COP E DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .... Form 10-407 Submit in duplicate Rev. 7-1-80 ' CONTINUED ON REVERSE SIDE NAME Top Sadlerochit Base Sadlerochi MEAS. DEPTH 11509' 12237' TRUE VERT. DEPTH 8790' 9379' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~G~_ _,~~,~/' Title Regional Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate productiOn from more than one interval (multiple completion), so state in item 16, and in'item 24 show the producing intervals for only the interval rePorted in item 27. Submit a'separate form for each additional interval to be separatelY produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supPlementa records for this well should show the details of anY~'multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 September 1, 1982 Reference: TYPOGP~APHICAL ERROR ON AN ARCO LOG Please note that the Cased Hole Final CBL/VD labeled D.S. 14-4 is incorrect and should actually be 14-14. The date is 10-24-81, run 1, and is a Schlumberger log. If you have any questions or need and further clarification, please call me at 907-263-4232. Kelly McFar land DISTRIBUTION R&D MOBIL DRILLING GET~ PHILLIPS D&M SOHIO GEOLOGY ~THON CH~RON DALES August 3, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re- D.S. 14-11 D.S. 14-13 ~D.S. 14-14 D.S. 14-16 D.'S. 15-11 D.S. 15-12 D.S. 15,13 D.S. 15-14 D.S. 15-15 Permit No. 80-131 Permit No. 81-101 Permit No. 81-102 Permit No. 81-81 Permit No. 81-132 Permit No. 81-146 Permit No. 81-124 Permit No. 81-170 Permit No. 81-181 Enclosed are. "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Operations Engineer DFS' TKKW-mlc Enclosures Distribution- Sohio Petroleum Co. ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASK '~ LAND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-102 3. Address 8. APl Number P.O. Box 360 Anchorage, Alaska 99510 50-029-20625 4. 12. Location of Well 1284'S & 1044'W of NE cr Sec 9, T10N, R14E, UM (surface) 2498'FNL, 129'FWL, Sec 11, T10N, R14E, UM (top producing) 2476'FSL, 234'FWL, Sec 11, T10N, R14E, UM (TD) Elevation in feet (indicate KB, DF, etc.) 71' RKB I 6. Lease Designation and Serial No. ADL 28312 9. unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 14-14 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE.OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 7-10-82. RU perforating unit, pressure tested surface equipment. .RIH with gun #1, tagged PBTD at 12760'MD, shot 11688-11708'MD with 4 SPF (20' ref CNL 10-29~81), flowed to tank for clean-up, monitored rate, and took shakeouts. POH - all shots fired. RIH with gun #2 but gun misfired. POH. RIH with gun #2-2. again gun misfired. POH. Suspect bad cable, change trucks. RIH with gun #2-3, shot 11648-11668'MD 4 spf (20' ref CNL 10-29-81), flowed to separator for clean-up. POH - 1 shot misfired. RIH with gun #3, shot 11618-11638'MD 4 spf. (20' ref. CNL 10-29-81), flowed to separator for clean-up. POH - 1 shot misfired. RIH with gun #4, shot 11600-11618'MD, 4 Spf (18' ref CNL 10-29-81), flowed to separator for clean-up. POH - all shots fired. RIH with gun #5, shot ~.~_~'-11586'MD 4 spf. (18' ref CNL 10-29-81), flowed to separator for clean-up. POH - 1,shot misfired. RIH for static pressure survey. POH and RD. Ran SSSV. Secured well 7-15-82. AUG - 5 .S82 0il & Gas Cons. O0mmissi0r~ 14. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Signed ,~ . Title Regional Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Reference: · Arco Cased Hole Finals D.S. 13-1 6-19-82 CNL Run 3 5" D.S. 13-30 7-20-82 ACBL/VDL/GR Run 1 5" D.S. 18-2 7-17-82 ACBL/VDL/GR Run 1 5" D~S. 16-12 7-9-82 Diff Temp Log Run 1 2" D.S.~ 14.-14 7-12-82 Collar & Perf Log Run 1 5" Please sign and return the attached copy as receipt of data. Kelly McFarland Trans. # 347 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIP S~ D&~ SOF~10:: GEOLOGY MAKATHON STAT~ OF ALASKA CHEVRON ARCO Alaska, Inc. is · subsidiary of AllmntlcRIct~tleldCompany Post Office Box 360 Anchorage. A~--ka 99510 Telephone 90% '7 5637 July 27, 1982 Reference: Arco Pressure Data D.S' 14-13 7-12-82 D.S. 14-14 7-12-82 D.S. 15-15 6-28-82 Shut-in Pressure Gradient Survey Shut-in Pressure Gradient Survey Shut-in Pressure Gradient Survey GO GO GO Please sign and return the attached Kelly McFarland Trans. # 321 copy as receipt of data. ~DISTRIBUTION NORTH GEOLOGY DRILLING MARATHON CHEVRON GEOLOGY QXlS. May 11, 1982 Reference: ARCO MAGNETIC TAPES & LISTS ""~ ~;:~"~':~ 10/29/81 D.S.7-2' 5/2/82 D.S.15-1 '~ 2'/17/82 Tape #ECC 1150 Tape #ECC 1289 Tape #ECC 1222 se sign amd return the attached:.copy as receipt of data. ~.~ry F. Kellis North Engineering Transmittal # 154 DISTRIBUTION NORTH GEOLOGY .... ~ON R&D MOBIL DRILLING GETTY ~~~'~ GEOLOGY MARATHON Oil & Ga:; Cons. CommJssi°n Anchorage February 1, 1982 Reference: ARCO CASED HOLE FINALS ----- D. S. 14-26 12/31/81 CNL Run 1 ~ D.S.14-12 12/5/81 CNL Run 1 2"/5" 2"/5" D.S.13-3 / 1/2/82 Gamma Ray Run 1 5" 15-10 ~ 12/3/8i 14-26-~f.~ 1/4/82 Collar Log Run 1 5" ACBL/VDL/GR Run 1 5" CNL/GR Run 2 2"/5" ACBL/VDL/GR Run 1 5" -~. D. S. 14-137T. 11/23/81 CNL Run 1 2". D~S~14 11/23/81 CNL Run 1 5" 13-10 ' 12/5/81 Temp Log Run i 2"/5" D'oSo14-13 11/23/81 CCL With Gyro Run 1 2"/5" D.S.14-12~ 12/7/81 CBL/VD Run 1 5" D.S.15-13 ~/11/28/81 CBL/VD Run 1~ ~5" *NOTE:'D.S.14-13 2" CNL is dated incorrectly and the date should be 11/23/81 instead of 11/2/81. ~e;icg%p;nad sr%te~re~p %he of data. Mary Fo Kellis North Engineering Transmittal # 924 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY , PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON F E B 0 5 1.91!,: ARCO Alaska. inc. is a ~ub'.i~d~at'¥ ol All,3nl~CR~chheidCompany Aiaska Oil & G~s Cons. Commission Anchorage ARCO Alaska, Inc./ Post Officet[ .360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 22, 1982 -. Reference: ARCO MAGNETIC TAPES & LISTINGS D.S.14-14 10/2!/81 Tape #.ECC 1138 DIFL,BHC/AC,CD/CNL ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 904 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA~ ~ ~ ~!! V£~ CHEVRON ~~' ' ~k,. . Alaska Oil & Gas Cons. Commission Anchorage ARCO Ataska. inc. ms a sa135~l~ary of Atl<3n[~cRichtieidCo,"npany ARCO Alaska, Inc. 'Post Off':ic_~' '~! 360 ' Anchorage;~: ,.~,a}ka 99510 Telephone 907 277 5637 November 25, 1981 Mr. Hoyle Hamilton State Of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 11-3 DS 15-11 DS 12-14 DS 14-12 DS 13-8 DS A-7 DS 14-13 DS lA-9 DS 14-14 DS B-8 DS 14-15 DS B-9GI Dear Sir' Enclosed please find the following' (1) The Completion Reports for DS 13-8, DS 14-14, DS 14-15, DS 15-11, DS 15-12, DS A-7, DS lA-9 and DS B-8. (2) The Monthly Drilling Reports for DS ll-3, DS 12-14, DS 14-13, DS 15.12, DS lA-9 and DS B-9GI. Sincerely, P. A. VanDusen District Drilling Engineer PAV' GA: ltc Enclosures ARCO .qla~ka lng ~s a sul:)sJd~ary of Atlanticll~¢,hll,'[dComp,--~'W ..... """~'STATEOF ALASKA'{ 16 A/. ALASK/~,,,2~ AND GAS CONSERVATION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I--I. ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Arco Alaska, :Inc. 81-102 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50-029-20625 - 4. Location of well at surface 9. Unit or Lease Name · L~)CATIONS ~ Pr~dhoe Bay Unit 1284'S & 1044'W of NE cr. Sec. 9, T10 N, R14E, UM, At Top Producing Interval VERIFIED 10. Well Number 2498'FNL, 129'FWL, Sec. 11, T10N, R14E, UMlisurf'--F---i DS 14-14 At Total Depth B.H. ~ - _ 11. Field and Pool 2476'FSL. 234'FWL. Sec 11 T10N. R14E. UM Prudhoe Bay Fi eld ,5. Elevation in feet (indicate KB, DF, etc.) 1-6. Lease Designation an~l Serial No. Prudhoe 0i 1 Pool 'RKB 71 'I 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 10/2/81 10/21/81 10/26/81I --feetMSLI 1 1.7. Tot~al Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 'i]_2310;~D 9440'TVDq2277'MD 9408"TVD YES[]j~ NO'[] 2270 feetMD ' 1900~ (approx) "-22¢~/pe Electric or Other Logs Run ' ·DIL/SP/BHCS/GR, FDL/CNL/GR/Cal. GR/CBL, CBL/VDL/GR/CCL .23· / ~_~, ~ ...... cASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . "20" 94# H-40 , Surf ll0' 32" 300sx Permafrost 13-3/8" 72# ' L-80 Surf 2632' 17~'' 2500sx Fondu & 400sx AS II ? 9-5/8" 47# L-80/ Surf , 1,1.358' t2~',! '500SXr:.Class "G" cmt $00-95 -~- Z,, 29# L-80 11085' ~.123,22'~ 8½" 350sx Class "G" cmt 24.Perforations open to Production (MD+TVD of Top and B~ttOlIi'~'~'~ 25. TUBING RECORD . interval, size and number). ..SIZE DEPTH SET (MD) PACKER SET (MD) TO = !~ ~.%? 6 ~,A¢¢ (~.,~¢~ 5~" 11100' ]1o33' ...... ~ N/A 0¢, ~,l~,l~. Ie L 26. ACl D, FRACTURE, CEMENT'SQUEEZE, ETC. ' .. . ,.'--I..Iv DEPTH INTERVAL (MD) AMOUNT& KIND.OF MATERIAL usED .: :' .'. , . , ? , -'.., . : N/A ·. . . 27. "pRODUcTION T~sT' Date ,F:. irst Production .. Method of Operation (F ow ng, gas lift, etc.) 'i~' '~ ,; ,~ : ,: " ,, , ,,. ,' " ~. ' ~ ' . N/A ...... ,,' ', Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO ! ,- TEST PERIOD I~ .:. Flowtu. bing . Casing Pressure CALCULATED I~ Q L-BBL ~ .GAS-MCF WATER-BBL OILGRAVITY-API (corr) . ' "' · 24-HOuR RATE-r ' ' ' '""; '": ..... Press. ,. :, ·. ., ,; , , ~ , ~ - , · ,~, ,, , I~ ' ¢' ' 28. ' CORE DAT~, "' . r ' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · // · . F;~":'t'x .., ,. '.! .... ' ,; , , : , ,- · ., . , , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME .......... Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 11509' 8783' 0/W Contact 11874' ~ 9104' Base Sadlerochit 12236' 9350' N/A , . 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is ~i~e and correct to the best of my knowledge~ Signed . .. ritleSr. Drilling En.cjr Date ~/~l~/ .... 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 formand in any attachments. Item 16 and 24: .;¢~ this well is completed for separate production from more?than one interval (multiple completion), so state in item 16, and ~n ~tem'24 show the producing ~ntervals for only the ~nterval 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.). It~im 23: Attached supplemental records for this well should s~w the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 - Drilling History - NU 20" Riser. Spudded well @ 1730 hrs, 10/2/81. Drld 17½" hole to 2647'. Ran 64 jts 13-3/8" 72#/ft L-80 csg w/shoe @ 2632' Cmtd 13-3/8" csg w/2600sx Fondu & 400sx A.S. II, ND 20" riser. I~stld 13-3/8" pack-off & tstd to 2000 psi-OK. NU BOPE & tstd to 5000 psi-OK. Tstd csg to 1500 psi-OK. Drld FC & cmt. Tstd csg to 1500 psi-OK. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW-OK. Drld 12¼" hole to 11,400'. Ran 278 jts 9-5/8" 47#/ft L-80/SO0-95 csg w/shoe @ 11358' Cmtd 9-5/8" csg w/5OOsx Class "G" Cmt. Instld'9-5/8" pack-off & tstd'to 5000 psi-OK. Tstd csg to 3000 psi-OK. Drld FC & cmt. Tstd csg to 3000 psi-OK. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW-OK. Drld 8½" hole to ]2310'TD. Ran~ DIL/SP/BHCS/GR & FDC/CNL/GR/Cal. Arctic packed 9-5/8"x13~~'Sts~ ~' w/300 bbl H20, 300sx Permafrost "C" andl31 bbl Arctic Pack. Ran 29 j 7" 29#/ft L-80 Butt lnr fr/ll,085 to 12,322'. Cmtd 7" lnr w/350sx Class "G" cmt. Drilled cmt to 12,2~7 PBTD. Ran GR/~BL. Tstd lnr lap to 2000 psi-OK. Displaced~well to NaC1/NaBr. Ran CBL/VDL/GR/CCL. Ran 5½" completion assembly w/tail @ 11,100' and packer ~ 11,033' Tstd tbg hanger & pack-off to 5000~psi-OK. ND BOPE. NU tree & tstd to 5~00 psi-OK. Displaced tbg w/diesel andannulus w/30 bbl cap. Dropped ball and set pkr. Tstd tbg to 3000 psi & annulus to 200 psi-OK. Closed SSSV ~ 2270' Instld tree cap and tstd to 5000 psi-OK. Secured well and released r~g ~ 0600 hrS. 10/26/81. A PETROLANE ~PANY REPORT of SU¢-SURF.4CE D~fRECTION.4'L SURVEY ARCO ALASKA, INC. COMPANY DS 14~ Well Number: 14 WELLNAME prudhoe,Bay, North Slope, Alaska' LOCATION JOB NUMBER A1081D0042 SURVEY BY LeJuene TYPE OF SURVEY DATE Directional Single Sh~:E C E ~ V E D 21-0ct-8t NOV 0 9 I98~ ~aska 0il & Gas Cons. Commission Anchorage OFFICE Alaska Eastm. an Whtpstock P. O. Box 4-19?O/Anchorage, Alaska 99509/(907) 349-4617 October 26, 1981 ARCO ALASKA, INC. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: 14-14 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Directional Single Shot Date: 21-Oct-81 Method of Computation: Radius of Curvature Surveyor: D LeJuene Job Number: A1081D0042 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Directional Single Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may contunue to serve you in the future. Sincerely, ) District Directional Drilling Supervisor RJ/bb cc: file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ,,,, -,-; r.:.: L" I.::.: VI:::R-i C A L. t;E: ;:;:. ' *, .. ,.., .... ,.-, L S U B S [': A D E',:: 'TH SECT ]:0~! T L:'O. 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H-~mi ~-~ ~ ~u f . :: .... .... , ....... : ............ p ....... . ...... =:.~ .... ~ ............ , ...~lg~ .... =:.- =:.~ ......... . ~ -~ 94 ':: ' ... · :~ ...................... 4..~ .... ~OO ,,..,~ %.': ~ ':, '",~[~; -~;~ ............. ~_ ~{-~ ......]~ ~- , . ._. .%. ~ ~. : , ~ ~ , '~'T-~ '. , ~ ~' ~ , ~ ' , ~, , . ~ - ' : ' : ' t ~ , . y', ~ ~ ~ , . . , ~ , ,~ , . ~ ~ . _ ..... ~ ~~ ~ · -~ ..................... ~ ~-~-~L~-_;.4.4 .......... ~ ~nn' '~ .... ~-~'--~-~ ...... ~--f-~+--~'~.-.~- .~-~ ~ ..... ~ ............ · -., ~ ~ ~ ~,.-~ ~ ........ ~_~ ~ ~" , , ; ; i i ',~, ; , I ; ' .... ~ -.;.' '. -.-: -~-~-1:44-: L,_~ "; ......... ~ r-; .... t-~4'-+"*-~"-~-+4--t-'+-+--,-~ ..~-~ ................ t ..... ~,'-,-~-t~- -~--p+--~- -~+~--~ ;44_+ ...... i..:: ~.' ,, . ,,... ':~: -', ~e, ~ ~ .................... Eastman t ~ Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTION.4L SURVEY JOB NUMBER Al181G0095 ARCOCOMPANY'A ,A~q:,A.. It,~C. ,.,,.~- :.. ,,'. · .,. . DS 14, Well ~mber: 14 PRUDHOE BAY, NORTH SLOPE, LOCATION TYPE OF SURVEY DATE ,. Gyro-Multishot 30-Oct-81 SURVEY BY D Pefferkorn o . OFFICE Alaska Eastman Whtpstock A PETROLANE COMPANY P. O. Box 4-19?O/Anchorage, Alaska 99509/(907) 34~4617 November 9, 1981 ARCO ALASKA, INC. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: 14-14 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Gyro-Multishot Date: 30-0ct-81 Method of Computation: Radius of Curvature Surveyor: D Pefferkorn Job Number: Al181G0095 Attn: Bob Hines Dear Mr. Hines, I am enclosing the ~original and one copy of the Gyro-Multishot Survey run on the above mentioned well. We wish to take this opprotunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, Y HICKMAN District Surveyor AH/bb cc: file Enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide CAMERA NO** 1488 "c'~'"'q'JO'c" BAY, NC,'RTH SLOPE~' A' ' .... 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SSUTH! J .2? ' ~.~ .......... ' · ....~ ...... · I~~RCO ~L~SKa, INC. ' ' · I ~DS 14~ ~ELL .Nfl: I4 GMS -~-.~7-~ ~-:TTI :LL: l_ :-:-7: SCALE ~I-iN. '~= 1000 FEET~' ~:~-i - ..... ~ ..... 7' - ~ [': :~ , ; I - : ' : i i :i i ' ' ' I -- -:- t .... :', ........ ~-~r-~'-~-: ~'~":r":--~ r ',' : .... ~ ~ t-'-~ r' t'~ : "' ......... -' :"'-'-;". .... I --- ; ~ ~HZPSTOCK~ INC.. · -"'-'?i::%~i!-?:-':f'''''::?'-''':~:'-~-~'_ :'":-~:"'?'-';:','~."'~"::-:~-::"T':11 . · 4i~oo -'. : ---.I · C:: rt~ . . · ,~ ._.5ooo -.. '- · i:.i:~ :'~' .~i' ..... 6000 · ._ ...... 8000 -~ !-~-~-i .... !:'~ .... i '-~:- .............. ~._~'r:~:~ ' : I I ; i ....... ~ ....................... ......... ~ , I , . ; - i ;J-- ~ - . i ._ -I . , i : ..... ~ .... T I ; -"... t , : i ! .............. ~ ,~; . 3500; ~ : ....... ~ .... - -~ -4. .'.. ' - ' -: ~ i- ~ ....... --' - ...... i 5000 ~__;; .ELI .... ~ ....... ' . . . ~ . . .... ~ ; ;.i..4~.~.,- ~.~- " : ..... '.. i .... ~l---:~ ~ ;~-~ :, ........ '--- Suggested form to be inserto] in each "Active" well folder to d~.eck for timely compliance wit]] our regulations. · O~rator, Well Name and ~umber Reports and Materials to b~ received by: I I'-~---~ I · ' Date Required Date Received Remarks Ccmpletion Report Yes . Well Histo~ Yes ._ ..... ..... . ~us ~m ' ~ _ ~i .~. %., , . . . ~re ~ips ~~e. ~/~ ' ~ , . . "" Core ~scrSption :..~ ........ Registered Su~ey Plat ~"L~:: Incli:htion Su~ey · n/O ~~ ~/~" Drill St~ Test Re~s ~0 ~ . . .......... .. Pr~u~ion T~t Re~rts W~ P.-v - ~S R~. Yes 11_ 47_~1 ~ ~ ~.~ , , ,. , ~ ...... ~t~z~~-~.~':"" ~. ~ ..... ; ..,: ; ARCO Oil and Ga~ ..... ;mpany North Alask~''~ Oistrict Post Office Box 350 Anchorage, Alaska 99510 Telephone 907 277 5537 Jerry A. Rochon District Operations Engineer November 12, 1981 Reference: ARCO DIRECTIONAL DATA I · D. S. 14-14 10/30/81 Gyroscopic Job No. Al181GO095 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineer%ng Transmittal #736 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M .SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Od ancl Gas Company ~s a Divi$1 .o,n o! AtlanhcRichfieldCompany Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 12, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton' Subject' DoS. D.S. D.S. D.S. D.S. D.S. D.S, 13-6 Permit No. 81-121 14-11 Permit No. 80-131 14-14 P'ermit No. 81-102 14-15 Permit No. 81-84 14-16 Permit '.No. 81-81 14-18 Permit No. 81-06 14-19 Permit No. 81-45 14-20 Permit No. 81-70 Enclosed are our Sundry Notices detailing the work to be done on the above-mentioned wells. Very truly yours, d. ^. Rochon JAR'TKKW:mlc Enclosures ARCO Alaska~ Inc. is a subsidiary ot AllanlicRichfieldCompany A~U STATE OF ALASKA~..'M ALASK ' IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] ,COMPLETED WE LL ;1~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-102 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5o- 029-20625 4. Location of Well 1284' S & 1044' W of NE Cr. Sec. 9, TION, R14E, UM 5. Elevation in'feet (indicate KB, DF, etc.) _ 7l,' RKB 12. I 6 . Lease Designation and Serial No. ADL 283l 2 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 14-14 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter C. asing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska proposes to. perforate selected intervals within the Sadlerochit Sand for production from the prudhoe Bay Unit..Upon perforating the well will be flowed to the flow station for clean up and productio'n' Should additional drawdown be necessary to unload the wells it may be flowed to a tank for initial clean up. The penforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator,'tested to working pressure. The SSSV will be installed at the conclusion of .the perforating and clean up operation. RECEIVED NOV I Alaska Oil & ~?. Cons, Comtnission 14. I hereby y that correct to the best of my knowledge. / Title r)i~tY, ict O,neratinn_~ Fnein~or Signed /,~__/)~. ~ / ~-~'~ ¢.~ ' . ........ ., .... The spac~b.~w for Commission use Date Conditions of Approval, if.any: Approved by COMMISSIONER ArprOved Cop~ the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company North A~, ~ Oisttict Anchorage, Alaska 29510 Telephone, 907 277 5637 Jerry A. Rochon District Operations Engineer November 12, 1981 Reference: ARCO DIRECTIONAL DATA i D.S,14-14 10/30/81 Gyroscopic Job No. Al181GO095 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #736 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. HANAGER D'&M GEOLOGY STATE OF ALASKA A R~O C'.d and Gas Co.'~p,tn¥ ,s ..1 Di ,/lstl).n o! Alta ~J,'...Rlchl~:,ld Comparly EXXON · HOBIL GETTY PHILLI,PS SOHIO MARATH~ ~.~ .... 'Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 4, 1981 Reference: ARCO DIRECTIONAL SURVEY DATA ~D.S.14,14 10/21/81 Single-Shot Job No. Ai081DO042 D.S.15-11 10/7/81 Single-Shot D.S.13-8 10/22/81 Single-Shot Job No. AL 981D30 Job Noo A1081DO046 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #717 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA Gas Ccrnpany ,s a Oivislg. not AtlanlicRichtielclCompan¥ EXXON MOBIL GETTY PHILLIPS SOHIO ~. ~ R~.~ E IV, E J) CHEVRON ' Alaska 0il & Gas Cons. Commission Anchorage ARCO Oil and Gas~,ompany North Alasktlk is~rict Post Office E~ox ,.360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochcn District Operations Engineer November 4, 1981 Reference: ARCO Open Hole Finals D.S.14-14 10/21/81 D.So14-14 10/21/81 D.S.14-14 10/21/81 D.So14-I4 10/21/81 Compensated Densi/Neutron Log/GR Compensated Densilog BHC Acoustilog DIFL Run 1 2" & 5'~ Run' 1 2" & 5'~ Run 1 2" & 5'~ Run 1 2" & 5'~ Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #713 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO C',H an(~ Gas Company :s a Divi$~g,n o! AtlanticRichfielc~Company EXXON MOBIL GETTY PHILLIPS SOHIO CHEVRON 4. 'J~ ~ NOVogIgg] -~ Alaska 0ii & Gas Cons. C0mmis~i0~ Anch0m~0 ,. ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle R. Hamiltog/~~ Chairman Thru: Lonnie C. Smith Commissioner October 12, 1981 Harold R. ~awkins Petroleum Inspector To Witness BOPE Test ARCO, D~ 14-14 Sec. 11, T10N, R14E, U.M. Permit 81-102 9_ctoberS,~ 1.?.8~ - I left Anchorage at 7:10 a.m. by Wien Airlines to Prudhoe Bay arriving in Prudhoe at 8~40 a.m. and at ARCO's DS 14 at 9~30 a.m. When I arrived oR location the BOPE was being nippled up. The BOPE test started at 7:.00 p.m. and finished October 6, 1981 at 4:30 a.m. I filled out an AO~C report (attached). There were two fail~es, the floor valve and the accumulator. (See AOGCC report attached). In summrf I witnessed the BOPE tests on ARCO's DS 14-14. When tests were completed, the~ were performed adequately. O&G #4 -4/80 STATE ~[" AI,ASKA ALASKA OIL & GAS CON::I':}-',VATION COMMISSION B.O.P.E. Inspection Report Inspector Date. WellBj. Operator /~ ~' ii-' .,~ Well .~-,/~ - /~ Location: Sec // Drilling Contractor Rig # / ~t . Representative Location, General . Well Sign General Housekeeping Reserve pit ~,/f BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pres sure , ~ ~ ~... ,. ACCUMULATOR SYSTEM Full Charge Pressure ~ ~,_z9 ~' psig Pressure After Closure / ~ 6~-~ psig · 200 psig Above Precharge Attained: ...... mln~/.~ sec. Full Charge Pressure Attained: z/ min~// sec Controls: Master 0[~ Remote- ~/q~'Blinds switch cover Kelly and Floor Safety Valves Upper Kel it Lower Kelly Bal 1 Type Ins ide BOP Test Pressure Test Pressure Test Pressure /-'/~,~- Test Pres sure Test Pressure Choke Manifold No. Valves ,/ ,? NO. flanges ~, /~ Adjustable Chokes ~/z-~C) Hydrauically operated choke. Test Time ¢~ hrs ._~ Repair or Replacement of failed equipment to be made within days and · Inspector/Commission office notified. Remarks:,,/~{~, .A ~-~'12~, /}/,..,~ /'~ .)~ 7'?'~ L~'~ .~,3.~ ~, /~(3~)/ ..... 7-~ ~o:~]~ Distribution orig: '- AO&GCC cc - Operator cc - Supervisor July 10, 1981 Mr. Po A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re~ Prudhoe Bay Unit DS 14-14 AR~ Alaska, Inc. Permit No. 81-102 Sur. Loc.~ 1284'S, 1044'W of NE cr Sec 9, T10N, R14E, Bottomhole Loc.~ 2528'N, 491'E of SW cr Sec 11, TION, R14E, Dear Mr. VanDusen ~ Enclosed is the approved application for permit to drill the above referenced well.. Well samples and a mud log are not reguired. A dtrecti~nal survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs.,, velocity surveys and dipmeter surveys ~ Many rivers in Alaska and their drainage ~fstems have been classified as impor'~tant for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.58.87~ and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the ~bitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is p .ohiblted by AS 46 Chapter 3, Article 7 and ~e regulations promulgated thereunder (Title 18, Alaska Administrative Code, ChaPter 70) and by the Federal Water Pollution Control Act, .as a~nded. Prior to Mr~ P~ A. VanDusen Prudhoe Bay Unit DS 14-14 -2- July 10, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adeq~late advance notification so that we may have a witness present. very' truly yours, H. Hami 1 ton Chairman of ~D~ Alaska Oil & GaBs¥ 8ons.~~ Enclosure cc'..: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/eno1. ARCO Alaska, Inc. [ Post OffiCe BI[, J60 Anchorage, Alaska 99510 Telephone 907 277 5637 July 6, 1981 Mr. Hoyl e Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 14-14 Dear Sir: Enclosed please find: · 2. 3. 4. · Sincerely, P, A, VanDusen District Drilling Engineer Attachments PAV/HHP:sp The Permit to Drill application for DS 14-14. The $100.00 application fee. The horizontal & vertical wellbore projections. A preliminary as-built drawing. (An updated as-built for Drill Site 14 will be submitted as soon as it becomes avai 1 able. ) The BOP stack diagram & description. RECEIVED JUL 0 9 1~$], Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ("" STATE OF ALASKA ~ ALASKA ,L AND GAS CONSERVATION C .,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL IX lb. Type of well EXPLORATORY'II SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OILI]~ SINGLE ZONE I~] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK 99510 4. Location of well at surface,'-, ~ [~ [, ~" t or lease name 1284'S & 1044'W of~N_E cr Sec 9, TION, R14E, UM Prudhoe Bay Unit At top of proposed producing interval 1:9 (Jbs number 2635'N & 5'W of SE cr Sec 10, TION, R14E, UM JUL0 0 1~{)e1~/ell 14-14 At total depth 2528'N & 491'E o¢~iSw' £r Sec 11 TION rl4E /~kaOil&Gasc°~¢'~6~i§§¢°~°°~ , , , , Anchor;~ge Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Prudhoe 0i l Pool RKB 71 ' 28312 12. Bond information (see ~0 AAC 25.025) Type Statewide Suretvand/°rnumberFed Ins Co. #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed NE of Deadhorse, AK 5 miles 1320 feet well 2640 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date ' ' 12,375'MD 9439'TVD feet 2560 October 1, 1981 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures +.'~,Q,~ psig@ - Surface KICKOFF POINT 2000m feet. MAXIMUM HOLEANGLE+47°I (see20 AAC 25.035 (c) (2) ~z~r)rl psig@ 9439 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY'OF CEMENT "' Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 32" 20" 94# H-40 -- +110 surf I +110 ~.+110 250 sx PF II to surf. 17~" 13-3/~ 72# N-80 BTC ~6'50 surf ~ .+--2700 ~-2. 650 Circ .to 'surf-apx 3000s 12¼" 9-5/8 47# L-80 & BTC +'11140 surf ~ +'ll14Q,d8600 500sx cmt column on ls S00-95 ~ !stage, +300 sx on 2nd stage' 8½" 7" 29# N-80 AB MOD+1535_ _+10840 [~+__9224 +_12375~9439 ~400 sx Class G 22. Describe proposed program: or BTC ARCO Alas,ha, Inc. proposes to directionally drill this well to 12,375'MD (9439'TV,D,) to-pro- duce t~e/Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8 5000 psi RSR~J~BOP stack will be used. The BOP equipment will be pressure tested each week and oper. ¢ut~r6nally tested each trip. A string of 5½" 17# L-80 tubing, packer and necessary provisiol for subsurface safety equipment will be run. A non-freezing fluid will be left in all..un- cemented annuli within the permafrost interval. Selected intervals within the Sadlerochit to be perforated and reported on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. The packer will be set 'abov~ the Sadlerochit. The downhole safety valve will be tested and installed upon conclusion of job. The 13-5/8" 5000 psi RSRRA BOP stack will be tested to 5000 psi. A surface diverter system will be installed and operationally tested prior to spud at least daily thereafter. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below for Commission use ' ' CONDITIONS OF APPROVAL I Samples required Mud log required Directional Survey required APl number []YES I~NO _ []YES I~NO J~[.YES i--]NO 50- ~;)~_~- ~--O~:~.,.~' ' Permit number Approval date ;¢ I- /OZ- fl?/lfl/Rl I SEE COVER LETTER FOR OTHER REQUIREMENTS BY_~'"~ ~¢~ ,COMMISSIONER DATE .'I'~1. ~ 1~ 1OO1 APPROVED by order of the Commission '-"-'-%z ~-'- · ...... Form 10-401 Submit in triplicate Rev. 7-1-80 --~:'-~ ~'.~. ~' :,~" i:~:~"~-~--:,: "~-~-': ~yTi':' ~ ~-',-~-~' :: :'~,-i"-~'~i~i "~-~-? :?:-~'r~!' ~-~'r~-~-~!-~ '~.:--'~-~' i~.--~.:~::~.... ::'-: ~ ::-.'-'.~'~-.'~-!---~ :.~--~-~-'~'5:":,-' · '~.~h~,~;~-:.~':":'' : '~' :'..:' : · '. ~ :..:': :~... :..:::.: ..... 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E ESI'ABLi:SHED' A'T ..................... ~i~8'3.;'~2 .................. 737* 19 ......... 47~"29 .......... 389i,43 OB.JE:CTIVE AT 8971,00 646S,91 47,29 11685,57 T T TIONAL POINT AT TIONAL POINT AT TIONAL F'OINT Al' TIONAL F'OINT AT TIONAL. POINT Al' IONAL F'OINT AT 6281,00 3550,23 47,29. 7720,02 iONAL POINT AT 68~1,00 4145,96 47.29 85S0o82 IONA[" F'OINT ~AT ...... . ............... 749i'~, O0 ................ 4'860.84 ............ 47,"29' .... 9503.,.78 ..... o~ 92: - IONAL POINT AT 7891,00 529:~,10 47, .... 100 ,45 IONAL POINT AT 8076,00 . 5494.49 47,29 10366,18 IoNAE' ' POI NT "~'T 8091.06 ................ 55i0.73 ............. 47-'.29 10388.'29 ¢....c.° ' IONAL F'OINT AT 11261.01 iONAL. POINT AT 11291,96 .............. IONAL F'OINT AT ~.~:.I:::1--S98.',.1. t,~ ~-~¢ 11685::, 57 840 .:36 12260';:50 12375,50 30:;8, o? · .-, ---- -- -. CLOT'"" 1050r~< 16 1167'-----< TION, RI4E, U.M. ! HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYIFIG IN THE STATE OF ALASF~ AND THAT THIS PLAT REPRESENTS AN AS- BUILT SURVEY MADE BY ME, AND THAT ALL DI..'~.ENSIONS AND OTHER DETAILS ARE CORRECT, AS OF' DATE D.S. 14 - CONDUCTORS 9 THRU 16 AS ~llll_T LnCATI'~NS STATE PL~.~,~_ LAT ,-~ LNNG Y × LAT LONG \\ \ \\ \ GEO = 1093' 10. Y = × = LAT = LONG '-. 1068' 1044' 1019' 994' 4 3 9 I0 1637""'~ \ \ 970' '~- "\\\ 9.45' 1754,_~~z'' \ 1872' \ 920 9 \\\ \\\ ~--WELL LINE ANCHOR 5,938,475.76 13. Y = 5,938,~43.83 675,567.36 X =' 675,'45A.54 ?O~,14,1c 2oo,, LAT = 70°I~'Iq 1 z~ 34' 56.2~3~' LONG = 148,'3h, 5~. 197,, · . 5,~3~,593.~O 14. Y = 5,930,060.50 475,53~.61 - X = A75,42~.ql 7n'1~'16.34~" EAT = '7no1~,'20.o71" !~q:'3~'57.02" LONG = 12. Y = 5,93R,~24.32 × = 675,~g4.36 L;,T = 70 14'IP.C5~'' Lqt!G'~ 14~ 34'5~. D.S. l~ /9-16 Atlantic'FI i~'~*f'i"e I d C o m p in y--~- ....... -j'~-A T E: 'O~'rH *M=~C*, ""O~UC~NG D~V~S'O,~ i 'A~O' -- A,LASKA DISTRICT- PR,U. DH_OE BAbY [_~-~ .,,1980 ~ECEIVED 15. Y -- 5,939,I'77.03 x = 67~,!;ql .32 LAT = 70~I~'72.173'' LO~"G = 142 35'90.6&~"' - x' = ~7$,37~. LAT = 7m · ~3.,.77" .... ~ __-~ ~.~-~- ~ _ · ........... CONDUCTOR AS-BUILT ...... 13-5"3" SC~ ~T~C~ 3;;3.M,:.I ~cc~mul~ttr C3cacit'/ -est 1. Check and fill accuzulator reservoir to proper level ~lith nycraulic fluid. 2. Assure that accumulator pressure is ]000 psi with 15CO ps~ dm.msCre~m of t~e regulator. 3. Observe time, then close all Unit~ simultan- eously ano record the time ant pressure re- maining after all units are closed with charging pu~p off. 4. Record on IADC report. {The acceptable lo~er limit is 45 seconds closing time and 1200 psi remaining pressure.} , 13-5/8" BCP Stack Test Fill BOP stack and manifold with a non- freezing liquid. '""" Check that all hold down screv~s are fully re- tracted. Predetermine dppth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. Close annular preventer and chokes and ~ypass valves on manifold. In each of the following tests, first hold ~ .... 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. Increase'p(essure to 3000 psi a~d hold for a min~i,~Jm-..of 3, minutes. Bleed pressure to zero. Open annular preventer and close top set of pipe 'rams. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. ClOse valves directly upstream of chokes & open chokes. Increase press, to 5000 psi & hold for ..... -~- at least 3 min. Bleed pressure to zero. Open top set of pipe rams then close bottom set of-pipe rams. Increase press, to 5000 psi below the bottom set of pipe rams & hold for at least 3 minutes. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. · .'-~.. ... . .- Bleed pressure to zero. Open bottom set Of pipe rams. · Back off running joint and pull out o'f hole. Close blind~rams and test to 5000 psi for at least 3 minutes. · 12. Bleed pressure off all equipment. Open blind rams. l.iake sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. , 15. Check operation of De Gasser. 16. Record test information on Blowout preventer test rom. Sign and send to Drilling Super. ~, .:...~ ~i-.~."'~.:'.: .'i:..:.?-.J.-=-. . 17. Perform complete BOPE test once a'w~ek · : ~%E.~'~ ~-,~-.~.-.,z~:':~ .... -~::,£:..-.... ...... functional operate BOPE daily. RECEtVE. JUL 0 Alaska Oil & (~as Cons. Anchorage SURFACE DIVERTER SYSTEM L J ~'J [ 'I- ® Note: Valves on diverter lines open automatically When the annular preventer is closed. L J JUL 0 9 Aiaska Oil & C~as Cons. 1. 20" BRADEHHEAD IG SPOOL Anchorage Comrni~sio.. 2. 20" 2000 PSI DRILLI; 3. 20" 2000 PSI AHHULAR PREVEHTER 4. ~0" BUTTERFLY VALVES 5. RIG DRILLIJ",IG RISER 6. 10" LI;q~'S TO SUMP 13-5,."3" ~C? ST,:,C'.< Accu~ul at~r Cagaci tv PREVENTER BLINDR~HS PIPE ~MS DRI'LL!NG SPOOL PIPE RRMS 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi do;.lnstream of the regulator. 3. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable loCker limit is 45 seconds closing time and 1200 psi remaining pressure. ) 13-5/8" BOP Stack Test 12. .. JUL 0 9. '"? ..... '-" .... co s.'Co. mi ? Afic;horag~ ' ' 14. 1. Fill BOP stack and manifold with a non- freezing liquid. 2. ~ Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. $.. Close annular preventer and chokes and ~ypass valves on manifold. · 4.. In each of the following tests, first hold ~- 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. Increase."p~essure to 3000 ps~ a~d hold for a min.~.~mm-..o~ ~*minutes. Bleed pressure to zero. open annula~ preventer and close top set of pi "~ams. Increase pressure to 5000 psi & hold fo at least 3 minutes. Bleed pressure to zero. 7. ClOse valves directly upstream of chokes & ope chokes. Increase press, to 5000 psi & hold fo at least 3 min. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom sE of-pipe rams. Increase press, to 5000 psi bel the bottom set of pipe rams & hold for at leas 3 minutes. ' 9. 'Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero -pressure downstream. · .... -'-- -.' 10. Bleed pressure to zero. Open'bottom set Of pipe rams. Back off running joint and pull ou~ o~ hole. Close blind rams and test to 5000 psi for at least 3 minutes. Bleed pressure off all equipment] Open blinc rams. Make sure manifold & lines 8re full ot non-freezing liquid and all valves are set i~ drilling position. Test standpipe valves to 5000 psi. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. · 15. Check operation of De Gasser. 16. Record test information on Blowout preventer tes~ form. Sign and send to Drilling Super. 17. ~[~..rm.c?Plete BOPE test once a'w~ek and CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE YES NO REMARKS (1) Fee (2) Loc 1. Is the permit fee attached .......................................... ~ 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance, from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to'be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait ........................... (3) Admin (9 thru 11) (4) Casg~ (12 thru (~) BOPE ~ %J~]~! (21 thru' 2~) e 10. 11. 12. 13. 14. 15. 16. 17. '18. 19. 20. 21. 22. 23. 24. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst..~_~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ --'--- Is adequate well bore separation proposed ........................... Is' diverter system required a leleeelleeeeleleeelelellleellelleeeeeee Are necessary diagrams of diverter and BOP equipment attached ........~.'__ Does BOPE have sufficient pressure rating - Test to ~-~O~D psig~. Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. (6) Add: 25. Additional requirements ............................................. Additional Remarks: Geology: Engineering: HWK ~ \ LCS BEW I~VA~'~ JKT~ RAD_~ JAL rev: 03/10/81 INITIAL GEO. UNIT t ON/OFF POOL CLASS STATUS AREA NO. ~ SHORE 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 APPEN. DlXl .. No special'effort has been made to chronologically organize this category of information. o. m~mmmmmmmmmm ~ ............. __ .__.j ......... m. Ii..I Itlll:l ._.C.N ............. .,: ........... 26,_8_2..5 ............. 6.R PAGE PAGE 2 11372 11374 2 PAGE ,.'3 13 PAGE 4 o 7~ ~ PAGE 5 PAGE 11576 0 qq 7 11578 0 3q 9 PAGE ? PAGE 11 5.3 PAGE 9 PAGE 10 PAGE PAGE ll.R' 1 5 7.9 11876 11R78 0 7 0 .3 ,,,,2 11880 0 5 ~ 2 .5 tlaa2,,o 5.9 2.~ 1.~ ~0.z 3'~.X ?.5 q. 5."/,,~28.2 8~o9 ~.25 2~¢~0 L1884,.0 5.3 2,2 l.g p8.4 27~ 7,8 43,& 27.1 q~.O 2,29 21.8 P~GE [~ PAGE 0 G 0 ~5 1197G 0 5 ! 2 1 0 8 8 PAGE PAGE PAGE 7 PAGE 0 6 ~+ ~ .3 0 6,2. q 7 PASE PAGE 20 12276 12 0 5 5 5 9 12 6 ~ .2 PAGE LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA, INC. Well D.S.~14-14 ~ Field PRUDHOE BAY County, State N. SLOPE, AK Date 10-21-81 Curve Name (Abbrev.) standard Curve Name Logs Used Scale · GR ..... Gam. ma ..Ray ...... DIFL 0-100, 100-200 GR1 .......... Gamma ...RAY (with Densil0g) i ... . CD/CNL ' 0-.1100, 1.0pT.200 , : CAL : Calipgr ... ~ , ......... CD/CNL' . . 6716 . DEN .. . Dens ity . CDL 2-3. ..... ' DENP Porosity from DenSilog CD/CNL .! 60'0- CN ComPensated Neutron i CD/CNL 60-0 AC AcouStic. BHC-AC 150-50 , SP Self-Potential DIFL 0-100,' 100-200 RFOC Resistivity from Focused Log " .2 - 2000 RILM ~ ~sistivity from Med. Induction " " _ RILD "" Deep Induction " . " CORR Correction Curve of Densilog 'CD/CNL - 5 .5 I · . . . · · · · 111~0, -9999,0-9999.0-9999.09999.0 ~0,99999,999,099,0099.009999.0 33.5999.0 11135, -9999,0-9999,0-9999o09999,0 ~5,39999,999,099,0099,009999o0 35'.1999,0 11380, 11385, -9999.0-9999,0-9999.09999o0 -9999,0-9999,0-9999.09999.0 ~0,79999,999.099.0099.009999,0 3~:1999.0 6S.S999909990099,0099.009999.O ~3999.0 :3L :]. E,:~ 0 , -c~999,0-9c~99 o 0-c~999,0c~99 o 0 ~:~, ~39c~99 o c~.9, Ocj9 o 0099,009999,0 3.3.6325'3,, -99c~9,0-~999 o 0-9999,09999,0 ~§, $9999 · 999, Oc~ · 0099 · 009c~9 · 0 -9999.0-9999.0-9999.09999.0 2~.~9999.999.099.0099.009999.0 22.29999.999.099.0099.009999.0 2~:7999.0 121~0. 121~. -9999,0-9999,0-9999.09999.0 -9999,0-9999,0-9999.0999g,0 PR ~GR AP,,~I. ISTFR , .AR.r_ O.......AL A.StLA.._...I~.1£ ............................................................................................................................................................................................................................ O_,..,.~, ....... !.~ .-....t.~ ....... .P..RU.D. H O.E.....B.A..Y. .... NQR~.H, ...,~L.O..P..£ m C ~ mOmmC m m C I..Li'~. m mm CmmI L.D. m mm S ~ ........... G.~.~....... C ~mt ............ TiE ~J ......... S. PD .......... ~ mCm ~ ........ A. C ............. ~..F. lO.Cll, l iR, I.,L,~i,,.,.R.i~J[.~i..iD,, D.[~''--N ........ Ci Om~.m.~ m iClN ................ ~m~m m .L.E.V.E L... S..P.A.C. !. N.G .................. 0., .5..0..0. 0 ................................................................................................................................................................................................................................................ ....... G ;2, .... S A M .P...L..E:..S .. P E.t~ .... R.E.C.0 B 13.