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178-039
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG DEC 2 .1 2019 Ia. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ElWDSPL ❑ No. of Completions: Zero tb. Well CCllassss� DevelopQlgr� IJ r fy� ❑ � • V Service 0 Stratigraphic Test ❑ 2. Operator Name: BP Exploration (Alaska), Inc 6. Date Comp., Susp., or Abend.: 11/27/2019 14. Permit to Drill Number/Sundry 178-039 ' 319.222 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 7, Date Spudded: 5/13/1978 15. API Number: 50-029-20312-00-00 4a. Location of Well (Governmental Section): Surface: 413' FNL, 576' FWL, Sec.03, T10N, R14E, UM Top of Productive Interval: 413' FNL, 576RAL, Sec 03, TION, R14E, UM Total Depth: 413' FNL, 576 FWL, Sec. 03, TION, R14E, UM 8. Date TO Reached: 5/19/1978 16. Well Name and Number: PBU PWDW3-1 - g Ref Elevations KB 78 GL 40.50 . BF Surface 17. Field/Pool(s): PRUDHOE BAY, PRUDHOE . 10. Plug Back Deplh(MD/TVD): Surface / Surface 18. Property Designation: AOL 028312 - 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 676892 ' y- 5945248 Zone - ASP 4 - TPI: x- 676892 y- 5945248 Zone - ASP 4 Total Depth: x- 676892 y- 5945248 Zone - ASP 4 11. Total Depth (MD/TVD): • 6150'/ 6150' • 19. DNR Approval Number: 77-044 12. SSSV Depth (MD/TVD): None 20 Thickness of Permafrost MD/TVD: 1900' (Approx.) 5. Directional or Inclination Survey. Yes ❑ (attached) No 0 Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (ft MSL) 21, ReArillaaterel Top Wndow MD/TVD N/A 22, Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary OIL/SP IBHCS/GR. FOC /GR/Cal, 4-Am1 Cal, GR/CBL/VOL/CCL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 94# Hoo Surface 119' Surface 119' 30" 370 sx Arctic Set 13-3/8 72# N -e0 Surface 2737' Surface 2737' 17-1/2" 5040 w PF 11 9-5/8" 47# sao-s5/N-80 Surface 6131' Surface 8131' 12-1/4" 500 sx Class'G', 510 sx PF'C' 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): flbanQm Q/A�TrE Zd{-it VE.��� ,ED _iY� 25, TUBING RECORD GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 7" 26# x 5-1/2" 17# 3924' 1 3720'/ 3720' x 4-1/2" 12.6# L-80 3799'/ 3799' 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was 0 AAC i)(2 used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, gas lift, etc.): NIA Date of Test: Hours Tested:: Production for Test Period —► GiLBbI: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio Flaw Tubing Press Casino Press: Calculated 24 Hour Rete --4► Oil -Bbl: Gas -MCF: Water-Bbl Oil Gravity- API (con): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only e /1j�0.20 rhaQQ7s�+�z° ABDMS & DEC 311019 26. CORE DATA Conventional Consist Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost -Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 5540' 5540' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top Cretaceous 5540' 5540' Base Cretaceous 6030' 6030' Formation at total depth: Base Cretaceous 6030' 6030' 31. List of Attachments: Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, Paleontological report, production or well test results, per 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Alvaro, Mike Authorized Title: S ecialist Contact Email: mike.aivano@bp.com Authorized Signature: Date:t 23 1 Contact Phone: +1 9075645475 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-007 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item Ia. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Sall Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so stale in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flouring, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 26. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this forth: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10A07 Revised 512017 Submit ORIGINAL Only WELL NAME: PWDW3-1 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 3604' 186 Bbls Class'G' 3574'- 3579' Punch Tubing 3057' 174 Bbls Class'G' 2990'- 2995' Perforate Casing 2840'- 2845' Perforate Casing 2368' 141 Bbls Class'G, 1300'- 1310' Perforate Casing Surface 148 Bbls Class'G' Surface 20 Gal AS I T/I/O = 307/269/1. Temp = SI. T & IA FLs (WIE request). T & IA FLs @ surface. IAP decreased 3 psi, TP & OAP unchanged since 05-06-2019. 5/9/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 11:45 T/I/O = 305/269/1. Temp = SI. T & IA FLs (WIE Request). T & IA FLs @ surface. TP decreased 2 psi, IAP decreased 7 psi, OAP unchanged since 05-09-2019. 5/15/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 15:15 T/I/O = 303/258/1. Temp = SI. TBG & IA FL's (WIE Request). Well house and flowline removed. WV is blinded. Tbg & IA FL's @ surface. TP decreased 2 psi, IAP decreased 11 psi, & OAP unchanged since 5/15/19. MV is locked out (call H-808 to unlock). 5/23/2019 SV, SSV = C. MV = LOTO. IA, OA = OTG. 15:40 T/I/O SSV/250/0. Temp= S/I Special Projects Job Scope: Cement control & balance lines for P&A Pumed 2.5 gallons each down C & B lines. Mix up 2.5 gallons of 14.0 ppg SqueezeCrete cement and pump 2.4 gallons down each down C&B lines. Cation tags hung 5/26/2019 with information. Wait 72 hours and pressure test both lines. PT to 2500 psi during test. ****WELL S/I UPON ARRIVAL**** (Plug & abandonment) DRIFTED W/ 2-1/2" SAMPLE BAILER TO 3,550' SLM (No issues) PERFORMED SBHPS LOG W/ BP GAUGES PER SOR (good data) 5/27/2019 ****WELL LEFT S/I & TENDER NOTIFIED OF STATUS UPON DEPARTURE**** T/1/0= 16/252/5 Temp= SI (LRS Unit 46 - Assist SLB Cement: Reservoir Cement Plug) Pumped 5 bbis Methanol (50/50) spear followed by 37 bbis 1 % KCL, @ 5 BPM for Injectivity 5/28/2019 test, WSR continued to 05/29/19 ***SLB Fullbore Pumping Crew** Job Scope: Plug and Abandon Reservoir. MIRU SLB and LRS pump crews. LRS starts injectifity test down TBG w/1 % KCL. 5/28/2019 **Continued on 05/29/18 WSR** WSR continued from 05/28/19 (LRS Unit 46 - Assist SLB Cement Van: Injectivity Test/Reservoir Cement Plug) Continue to pump an additional 250 bbis 1 % KCL (290 bbls total) to establish -400 psi @ 5 BPM injectivity rate. Pump 5 bbis 60/40 meth spear for SLB. SLB cements. SLB pumps 5 bbis FW. Displace cement w/ , 137 bbls Diesel (TOTAL DISPLACEMENT=142 bbls) Valve positions, SV/C WV/NA SSV/C MV/C IA/O OA/0, 5/29/2019 1FWHPs 316/214/7 **Continued from 05/28/19 WSR** LRS pumped injectivity test down TBG w/KCL (5 bpm @ -400 psi, refer to LRS AWGRS for specifics), and 5 bbl 50/50 spacer. SLB pumped 10 bbis FW spacer, 186 bbls 15.8 ppg Class G cement, and 5 bbis FW spacer. Launched 1x8" foam wiper ball. LRS displace cement w/137 bbis diesel. Cement in place @ 03:01. Tag hung on MV. FWHP's = 327/214/7 5/29/2019 115.8ppg class G cement in TBG T/I/O = SSV/240/0. Temp = SI. Special Projects Job Scope: Pressure test Cemented Control & Balance lines to 2500 psi **PASSED**. Pressure Test Cemented Balance line to 2500 psi, lost 79 psi in 5 min. Pressure Test Cemented Control line to 2500 psi, lost 53 psi 6/1/2019 in 5 min. Control & Balance lines bled to 0 psi. Tags hung. ***Job Complete*** T/1/0= 7/229/0 Temp=Sl LRS unit 72. Assist HES slickline (PLUG AND ABANDONMENT) AOGCC (Guy Cook) witnessed CMIT-TxIA to 1500 psi FAILED because the IA did not pressure up. Pumped 20 bbis of 50/50 McOH. AOGCC (Guy Cook) witnessed MIT-T to 1500 psi PASSED at 1632 psi.11750 psi Max Applied Pressure). TBG lost 86 psi during the first 15 minutes and 15 psi during the second 15 minutes. Pumped 1 bbl of 50/50 McOH to achieve test pressure. Bled back 1 bbl. ***Job 6/5/2019 Cont. to 06-06-2019 WSR*** Daily Report of Well Operations PBU PWDW3-1 ***WELL S/I ON ARRIVAL*** (P&A) DRIFT TO 3593' SLM w/ 1.80" SWAGE & 1.50" SAMPLE BAILER (recovered wiper & 1/2 cup of cement) DRIFT TO 3598' SLM w/ 1.80" SWAGE& 1.50" SAMPLE BAILER (recovered wiper) DRIFT TO 3598' SLM w/ 1.80" SWAGE & 1.75" SAMPLE BAILER (no recovery) DRIFT TO 3604' SLM w/ 1.80" SWAGE & 1.50" SAMPLE BAILER... recovered -1 cup of 6/5/2019 cement ***Job Cont from 06-05-2019 WSR**** Pumped 56 bbls crude down IA for a LLR of 5 bpm @ 480 psi. (SEE LOG) FS3 Control Room notified of Well Status per LRS departure. 6/6/2019 FWHP's=Vac/400/Vav SV,SV,WV=C SSV=O ***MV=C*** IA,OA=OTG ***WELL S/I ON ARRIVAL*** (plug and abandonment) RIGUP HES RELAY UNIT 046 6/12/2019 ***CONT. TO 6/13/19 WSR*** ***CONT. FROM 6/12/19 WSR*** (plug and abandonement) RIH W/ 5'x 1-9/16" TUBING PUNCH. PUNCH TUBING FROM 3574-3579', 4 SPF, 0 DEG PHASE, CCL STOP @ 3563.'TO9'. RRELATED TO TUBING TALLY DATED 3/1/97 6/13/2019 ***JOB COMPLETE / DSO NOTIFIED*** T/I/O= 440/230/0 Temp=S/I (LRS Unit 70 - Assist SLB Cement: Reservoir Cement Plug) 6/14/2019 Rigged up and pressure tested, did not pump any fluids. ***Continued on 06-15-19 WSR*** Initial T/I/O: 445/100/Vac **SLB Fullbore Pumping Crew** Job Scope: Place TxIA lateral Cement Plug. MIRU SLB and LRS. LRS pumped 5 bbls 50/50, 50 bbls Surfactant, 304 bbls 9.8 ppg NaCl down TBG taking returns up IA to OTT. 40% losses, unable to get 9.8 ppg NaCl returns to surface. LRS bullheaded 92 bbls 9.8 ppg NaCl down IA as contingent FP. SLB pumped 10 bbls FW spacer followed by 174 bbls 15.8 ppg Class G CMT, 3 bbls FW flush down TBG taking IA returns to OTT. Drop 8" foam wiper ball. LRS displace with 115 bbls 9.8 ppg NaCl and,5-bbi-EQ/50 down TBG up IA to OTT. ***Est 2 bbls of returns after cement turned come .Est 150+ of 174 bbls CMT losses*** tree valves greased. FWHPS= 46/6/0 15.8 ppg Class G CMT in TxIA Est TOC in TBG = 3200' MD / 3200' TVD 6/15/2019 Est TOC in IA = 3152' MD / 3152' TVD ***Continued from 06-14-19 WSR*** (LRS Unit 70 - Assist SLB Cement: Reservoir Cement Plug) Pumped 5 bbl 50/50 spear and 50 bbls Surfactant, 304 bbls 9.8 ppg NaCL down TBG taking returns up IA over to open top tank. Return sample from IA 8.3 ppg. Bullhead 92 bbls 9.8 ppg NaCL down IA. SLB pumped 10 bbls fresh water followed by 174 bbls 15.8 ppg class G cement and 3 bbls fresh water down TBG. LRS displaced TBG with 115 bbls 9.8 ppg NaCL and capped with 5 bbls 50/50. Valve Positions SV, SV, SV, WV= Closed SSV, MV= Open CVs OTG. Choke Traile-SI. 6/15/2019 IFinal WHP= 46/6/0 T/1/0 = 50/VaGVac. Temp = SI. IA FL (FB request). No wellhouse or flowiines. Temp scaffolding installed around well. IA FL @ near surface. 6/17/2019 SV, WV = C. SSV, MV = O. IA, OA = OTG. 20:10 T/I/O= 0/8/0 Temp= S/I LRS Unit 70 (CMIT-TxIA 1500 psi) Travel, Rig up to well and 6/17/2019 pressure test. ***WSR continued on 06-18-19*** ***WELL S/I ON ARRIVAL SWCP 4518***(p&a) RAN 3.50" CENT, 3" SAMPLE BAILER TAG TOC @ 3057' SLM (aogcc witness tag) LRS PERFORM PASSING CMIT-T x IA (aogcc witness) 6/18/2019 ***WELL LEFT S/l, OPERATOR NOTIFIED ON DEPARTURE*** Daily Report of Well Operations PBU PWDW3-1 ***WELL S/I ON ARRIVAL*** (sidetrack) RIGUP HES ELINE UNIT 863 6/18/2019 ***CONT. TO 6/19/19 WSR*** ***WSR continued from 06-17-19*** LRS Unit 70 (CMIT-TxIA 1500 psi for Plug & Abandon) CMIT-TxIA PASSED to 1603/1610 psi. Target Pressure = 1500 psi, Max Allowable Pressure = 1750 psi. Pumped 4 bbls 50/50 meth/water down T/IA to start test @ 1743/1750 psi. TxIA lost 22/21 psi in 1st 15 min and 19/19 psi in 2nd 15 min for a total loss of 41/40 psi during 30 6/18/2019 minute test. Bleed TxIAP down bleed back -1 bbl T/1/0=43/49/vac Temp=Sl Assist S -line (P&A post cement) AOGCC State witness by Brian Bixby CMIT TxIA PASSED @ 1685/1669 psi Target psi 1500 Max applied 1750 psi Pumped 1.4 bbls of 35* 50/50 meth H2o down IA to reach test psi 1st test 1st 15 min TP lost 28 psi IAP lost 38 psi 2nd 15 min TP lost 15 IAP lost 26 for a total of 43/64 psi in 30 min 3rd 15 min TP lost 11 IAP lost 21 4th 15 min TP lost 09 IAP lost 21 Bleed well head psi off bleed back 6/18/2019 .80 bbl 3 swab valve shut SSV open master opoen casing valves opoen to gauges Final ***CONT. FROM 6/18/19 WSR*** (plug and abandonment) RIH W/ 2" MILLENNIUM PERF GUN 5' X 2", 6 SPF, 60 DEG PHASE, PERFORATE 2990-2995'. TUBING DROPPED FROM 300 PSI TO 0 PSI. POOH RIH W] PREtiSURt EY TOOLS PERFORM STATION STOPS AND LOG AS REQUESTED. POOH. RIH W/ 2" MILLENNIUM PERF GUN 5'X 2", 6 SPF, 60 DEG PHASE. PERFORATE 2840-2845'. . POOH RIH W/ PRESSURE SURVEY TOOLS PERFORM STATION STOPS AND LOG AS REQUESTED. POOH 6/19/2019 IRDMO. T/I/O = 5/Vac/Vac. Temp = SI. T& IA FL (FB request). No wellhouse or flowline. Temporary scaffold installed. T & IA FL @ near surface. 6/20/2019 SV, WV = C. SSV, MV = O. IA, OA = OTG. 02:20 T/1/0=5/0/0 Temp=Sl (LRS Unit 76 - Injectivity Test) Road to location, RU to choke trailer. SV and SSV have issues. Road to MI to load 9.8 ppg NaCl while WS remove foam wiper ball from ball launcher. Pump 11 bbls 9.8 ppg NaCl at -0.3 bpm down TBG to verify communciation w/formation (TxIA pressures climbed very slowly while pumping). SD and monitored pressures while WSL confered w/town. Pumped additional 9 bbls 9.8 ppg NaCl down TBG to establish injectivity of 1 bpm @ 1090 psi. 6/20/2019 Valve positions=SV closed, SSV, MV open, CV's OTG T/I/O = VAC/0/0. Dry Hole conversion. RU CIW lubricator #68-839 with 6"'K' BPV #612. PT to 350/3500psi (PASS) Rundown through cown valve and set at 165" Pumped up underneath through IA to 300psi for 5 minutes to perform LTT (PASS) RD lubricator and and Remove 6" CIW Tree and installed 6" CIW Dry Hole Tree. Torque to API specs 1-3/8" L7M = 907ft lbs. RU Lubricator with 6" 'K' Test dart. Run down and set at 90" PT to 350/3500psi (PASS) Close Crown Valve gate and PT against Crown Valve gate to 6/21/2019 350/3500psi (PASS) RU lubricator with 6" W pulling tool. T/I/O=BPV/Vac/0 (LRS Unit 76 - Assist Valve Crew: Pressure Test BPV (Plug and Abandonment) Pumped 4.2 bbls 9.8# Brine down IA to reach 300 psi. Held 300 psi for 5 min Ito 6/21/2019 test BPV. FWHP=BPV/0/0 Daily Report of Well Operations PBU PWDW3-1 T/1/0=32/2/0 Temp=Sl (LRS Unit 76 - Circ-Out, Displace Cement) Pump the following down the tubing, taking returns up the IA to surface tanks: 298 bbls 50/50 methanol Obtain IA sample of 7.7 ppg via mud scale. T/IA Pressures = 8/3 psi. Monitor for 3 hrs. Pressures rose to 119/119/1. SLB pumps cement and drops ball. Displace cement/ball w/ 85 bbls 9.8# Brine, 6 bbls 50/50 down Tbg. taking returns up IA to surface. TOTAL DISPLACEMENT of 96 bbls. Valve postions upon departure: 6/22/2019 FWHP=27/36/2 Initial T/I/O = 136/16/2. Temp=S/l. SLB fullbore pumping crew. Job Scope: Plug & Abandonment with cement down 7" TBG and up 9-5/8" IA to surface. LRS previously circlulated well to 50/50. SLB pumped down the TBG taking returns from the IA to surface tanks: 10 bbls FW 141 bbls 15.8 ppq Class G cement. and 5 bbls FW spacer. Launced 1x8" foam wiper ball. LRS displace cement with 85 bbls 9.8 NaCl and 6 bbls 50/50 down the TBG with returns from the IA to surface tank. Clean cement sample from IA. FWHP=27/36/2 15.8 ppg Class G cement in TBG and IA EST TOC in TBG = 2500' MD / 2500' TVD I TOC in IA = surface 6/22/2019 EST BOC in TBG = 2840' MD /2840' TVD / EST BOC in IA = 2840' MD / 2840' T/1/0=0/0/0 MIT-T PASSED To 1681 Psi. 1750 Max, 1500 Target. (Plug And Abandonment) Pumped 1.0 bbls Diesel down TBG to reach test pressure. Loss of 40 psi 1st 15 min. Loss of 7/17/2019 17 psi 2nd 15 min. SV/MV Closed. IA,OA OTG ***WELL S/I ON ARRIVAL*** (P&A) TAG TOC W/ 3.64" JUNK BASKET @ 2368' ELMD PERFORATE 7" TUBING 1300'-1310' WITH 1-9/16" MILLENNIUM HMX, 6 SPF, 60 f3EGREE 7/19/2019 PHASING ***JOB COMLETE, WELL LEFT S/I*** T/I/0= 0/0/0. Temp=Sl (LRS Unit 46 - Circ Out TxOA Post Eline Perf) Pump the following down the Tubing, taking returns thru punched Holes 1300-1310', up OA to Surface Tanks 9 bbls 50/50 to establish communication between TxOA 50 bbls of 180* Diesel 50 bbls of 180* 9.8 ppg NaCl Brine ***Had to surge OA to OTT to get Arctic pack to move. Pumped at various intervals due to actic pack plugging off OA/hardline while pumping (SEE LOG FOR DETAILS)*** 7/19/2019 *** WSR continued on 07/20/19*** *** WSR continued from 07/19/19*** (LRS Unit 46 - Circ Out TxOA Post Perf) Continue to let soak for 1 hour. Pump the following down the tubing, taking returns up the OA with the following: 15 bbls of 9.8 ppg NaCl brine to confirm rate prior to pumping freezable fluids. 50 bbls of 160* surfactant water 181 bbls of 9.8 ppg brine. to Cic-Out Tank ***Returns appear clean and 1:1 ratio. Tank has - 420 bbls*** OA integrity test Per WSL. Pressured T/OA to 1000 psi monitord for 5 min. no abnormal fall off (See log for detail.) Tags hung on MV. SV/MV= C. CV's=OTG 7/20/2019 FWHP's= 0/0/0 SLB Fullbore pumping crew Objective: Plug and Abandon TxOA from -1300' to surface.. MI/RU/PT SLB cementers. Pumped 10 bbls FW spacer and 40 bbls 15.8 ppg class G cement down TBG taking returns from the OA. 7/21/2019 **Continued on 07/22/19 WSR** Daily Report of Well Operations PBU PWDW3-1 **Continued from 07/20/19 WSR** Pumped 108 bbls (148 bbls total) 15.8 ppg Class G cement down TBG taking returns from the OA to surface tanks. Job Complete. 15.8 ppg class G cement TxOA TOC = surface 7/22/2019 EST BOC TxOA = 1300' MD / 1300' TVD Reset WACH's Goliath saw on 20" conductor. Used 60T crane attached to tree cap. Pulled 2K over estimated weight and used escavator pulling at base of dryhole tree away from crane and cut. Made cut just past midway point and broke saw blade. Detached blade and ran saw to far side of conductor. Flipped and attached the saw blade backwards. Started cutting pulling back to center of planned cut. Broke second blade estimated depth on 9 5/8'. 20" conductor broke leaving about 4" contact areas 180 deg across from each other. 11/24/2019 Attempted to break remaining conductor. Continue cutting operation reset saw 90 deg from cut that made it over half way on all Csg strings. Completed clean cut across all Csg strings. 9 5/8" and 7" TBG fell 15" depth of 11/25/2019 cement in conductor at 19" pick saw out of excavation and release crane. Clean out 20" conductor and 13 3/8" Csg down to top of 9 58" & 7" TBG Mix 20 gallons of 15.6 AS1 cement and dress to top edge of strings. Set heat in Shoring box to keep area warm until cement sets up. Notification sent to AOGCC, Austin Mcleod responded at 05:37 AM to meet on site Wednesday at 9:00 AM to inspect P&A site. Pad Grade 0' Tundra Level 5.6" Top of Csg stub 102" = 4'8" below tundra (AOGCC requirement 3') 11/26/2019 Bottom of hole Plug and Abandonded 3' below tundra (Final depth in header references tundra). AOGCC Rep Austin McLeod witnessed cut, depth of cut, cement to surface and confirmed bead welded information on marker plate as per Sundry. Permission given to pull shoring box land 11/27/2019 began back filling of hole. ***Job Complete*** 0 R_ GR78 ABANDONED PWDW3 TBG TOC 7/19/19 2368• ELM — 13-3/8• CSG, 729, N-80, D= tz.347• 2737" EST 14, & TBG BOC (0622/19) —2840' TAGGED TBGTOC 06/18/19 3067" ESTIA TOC (06/15/19) –3152' EST IA & TBG BOC (06/15A 9) —357,V TBG PUNCH (06/13/19) 3574' - 3579' r TAGGED RES CMT PLUG 06/15/19 3604' - 7' TBG, 26#, L-80, .0383 bpf, D = 6.276• 3779' TOP OF 5-1/2' TBG 3719' Minimum ID = 3.625" @ 3878' 44/2" CAM DB -5 NIPPLE 5-12' TBG, 17#, L-80, .0232 bpf, D = 4.892• 380T TOP OF 5-12' TBG- PC 3807" 5-112• TBG -IPC, 17#, L-80, .0232 bpf, D = 4.892' 3819' TOP OF4-112• TBGNPC 381W PERFORATION SUMMARY REF LOG: BHCS ON 05/19!78 ANGLE AT TOP PERP 0 @ 2840' Note: Referto Pmdwfion DBbr Nsbrical erfdata SIZE SPF INTERVAL OpWSqz DATE 33)8' 4 5540-5565 C 0226!79 33/8' 4 5640-5650 C 0226779 3aW 4 5658-5673 C 0226779 3J/8' 4 5690-5705 C 02126(79 33/8' 4 5725-5735 C 0226(79 3-3/8' 4 5852-5867 C 0226(79 338' 4 6020-6030 C 0226179 I PBTD I 9-5/8• <dQ;_"Ii 1 SAFETY NOTES: _ SURFACE -1300• TX OA CMT(07/19M9) 1300•-1310• 7-X 9-5/8• TBG & CSG PUNCH (07/19/19) --Z-2'13W 7• HES RBP SSSV NP. 1)=5.963' ALL STRINGS CUT 3' BELOW TUNDRA GRADE. CEMENTED TO SURFACE & MARKER CAP WELDED ON. 11/27/19 17•X5-1/2•XO. D=4.865' 1 3720' 1--19-518- X 5-12' TNV HB -BP T PKR, D = 4.865- 19-5/8- X 5-12' BKR FB -1 PKR I 14-12• CAM DB -5 NP, D = 3.625' 1 ® ELMD 7"701/11188 FISH- 4-1/2" TUB WG TA L 6004' H FISH - PERF GUN DATE REV BY COMMENTS DATE REV BY COMMENTS 0527f/8 ORIGINAL COMPLETION 0627/19 BTNIJMD TBG PUNCH (06/13119) 1213188 7• TBG COMPLETION 0627/19 JJUJMD TXIA CMT PLUG (06115119) 038387 LAST WORKOVER 0627/19MRD/JMD TXIA CMT PLUG &ADPERFS 04/11/16 RCTIJMD SSSV CORRECTION 0723/19 TJS/JMD TAG TX OA TOC & PUNCH TBG WWI 9 JNL/JMD CORRECTION TO CSG DEPTH 12109/19 AB/JMD ABANDONED 1127/19 0627119 MRD/JMD RES CMT PLUG (0529/19) PRUDHOE BAY UNIT WELL: PWDVV3-1 PERMIT No: 1780390 API No: 50-029-20312-00 SEC 3. TION- R14E. 470324' FEL & 411.62' BP Exploration (Alaska) MEMORANDUM TO: Jim Regg P. I. Supervisor FROM: Austin McLeod State of Alaska Alaska Oil and Gas Conservation Commission �q I7ftl(j DATE: 11/27/19 Petroleum Inspector SUBJECT: Surface Abandonment PBU PWDW3-1 BPXA PTD 1780390; Sundry 319-222 11/27/19: 1 traveled to Flow Station 3 and met up with BPXA representative Dan Scarpella to witness the surface abandonment of the well. I was informed once cut the 7 -inch tubing and the 9-5/8 inch casing fell approximately 15 inches. I did not witness this, as when I showed up everything was cemented to surface (the tubing and casing strings were not visible). I did receive photos from just after the cut was made. It appeared and I was told, that those non-visible strings did have cement to surface. The well appeared to be cut off at the proper depth, with Dan telling me it was 3 foot 2 inches below tundra. The Y4" thick marker plate had the proper information welded to it but with the 20 -inch conductor being "egged" and slightly elongated, the plate did stick out slightly past the outermost string on one side with a slight gap on the other. No other exterior defects noted. I also received a photo of the plate welded on and modified to size. Attachments: Photos (4) 2019-1127_Surface_Abandon_PBU_PWDW3-1 am.docx Page 1 of 3 M N CD co N � 3 G a d °i X r � W J U a� mQ a O 1 v wN C O d C/) cU 0U C7 �O y O N M0 3 t � N d r I N I ON MNOI Flu MEMORANDUM TO: Jim Regg Q ZZ�I 1 P.I. Supervisor 1� q `1 State of Alaska Alaska Oil and Gas Conservation Commission FROM: Brian Bixby Petroleum Inspector Section: 3 Township: 10N Drilling Rig: NA Rig Elevation: NA Operator Rep: Rob Bryan Casing/Tubing Data (depths are MD) Conductor: 20" O.D. Shoe@ Surface: 13 5/8" O.D. Shoe@ Intermediate: O.D. Shoe@ Production: 9 5/8" - O.D. Shoe@ Liner: O.D. Shoe@ Tubing: 7"x5.5"x4.5" -O.D. Tail@ Plugging Data: Test Data: DATE: June 18th 2019 SUBJECT: Well Bore Plug & Abandonment PBU PWDW3-1 - BP Exploration_ Alaska Inc. PTD 178-039; Sundry 319-222 Range: 14E Meridian: Umiat Total Depth: 6150 ft MD " Lease No.: ADL 028312 119 - Feet 2737 - Feet IA 1734 Feet 6131 Feet p Feet 3924 Feet Suspend: P&A: XXX Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Initial Tubing 1728 15 min 1700 30 min 1685- 45 min Result 1674 IA 1734 1695 16991648 ' p OA 0 0 0 0 Remarks: I witnessed the top of cement tag at 3057 ft MD (slickline). The IA and the Tbg were pumped up at the same time with a jumper and then isolated for the pressure test - held 45 minutes to verify decreasing pressure loss. Attachments: none rev. 11-28-18 2019-0618_Plug_Verification_PBU_PWDW3-1 bb MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg l l Depth Btm DATE: June 5, 2019 MW Above P.I. Supervisor Fullbore Bottom ' 4799 ft MD - 3621 ft MD ' 6.8 ppg - Wireline tag SUBJECT: Well Bore Plug & Abandonment PBU PWDW3-1 - FROM: Guy Cook BPXA Petroleum Inspector PTD 1780390; Sundry 319-222 Section: 3 Township: 10N - Range: 14E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 6150' MD Lease No.: ADL0028312 ' Operator Rep: Tyson Shriver/Jerry Lau/ Eric D. Suspend: P&A: X ' Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 20" O.D. Shoe@ 119 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2737 - Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 9 5/8" - O.D. Shoe@ 6131 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 7 x 5.5 x 4.5" "O. D. Tail@ 3924 - Feet Tbg Cut@ Feet Plugging Data: Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Bottom ' 4799 ft MD - 3621 ft MD ' 6.8 ppg - Wireline tag 0 0 Test Data: Initial 15 min 30 min 45 min Result Tubing 1733 - 1647 1632 _ IA 293 - 287 287 P OA 0 0 0 Remarks: First tag with wireline was at 3598 ft MD; did not get a cement sample, but did get chunks of the wiper ball pumped during the cement job. Attempted a CMITxIA, but the IA would not hold pressure greater than approximately 290 psi. The IA was isolated and performed a passing MIT -T. The second tag was at the same footage, but again did not produce a cement sample. I instructed Jerry Lau (BPXA), who replaced Tyson Shriver (BPXA) during preparations for pressure testing, that they could not move forward until given the go ahead from the AOGCC. I also let him know I would be in touch with Mel Rixse (AOGCC) to let him know what had happened during our testing and that Mel would give direction on what the plan forward would be. I left location and was told they were rigging down for the evening. I received a call at 22:00 hrs from Eric Dickerson (BPXA; replaced Jerry Lau) informing me that they had successfully tagged cement approximately 10 ft deeper than the previous tags and had a ✓ sample of cement. I told him that I would contact Mel Rixse in the morning and we would go from there, but they were not to proceed further until the AOGCC had got back to them and to save the cement sample. I called Mel Rixse and he asked me to look at the cement sample and let him know if the cement was good. I met Eric Dickerson and looked at the cement sample and informed Mel Rixse I thought it was a good cured sample of cement. Attachments: None � rev. 11-28-18 2019-0605_Plug_Verification_PBU_PWDW3-1_gc.docx THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Aras J. Worthington Integrity & Interventions Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 995519-6612 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ww W. aogcc, alaska.gov Re: Prudhoe Bay Field, Prudhoe Bay Undefined Water Disposal Well, PBU PWDW3-1 Permit to Drill Number: 178-039 Sundry Number: 319-222 Dear Mr. Worthington: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 9 day of May, 2019. RBDMSi� MAY 0 9 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 MAY 0 1 2019 1. Type of Request: Abandon RI r Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ OpReee C Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number. 178-039 ' 3. Address: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029-20312-00-00 99519-6612 Stratigraphic ❑ � Service 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ® PBU PWDW3-1 9. Property Designation (Lease Number): 4 10. Field/Pools: l4 VW_'A 513119 ADL 028312 PRUDHOE BAY, PRUDHOE BAYANATER DISPOSAL WELL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Tata) Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MO: 6150 6150 6050 6050 None 5991,6004 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 39-119 39-119 1530 520 Surface 2699 13-3/8" 38 -2737 38-2737 5380 2670 Intermediate Production 6095 9-5/8" 36-6131 36-6131 1 8150/6870 1 5080/4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size:Tubing Grade: Tubing MD (ft): 5540-6030 5540-6030 7 269 x 5-V2" 17# x 4-1/2" 12.6# L-80 34-3924 Packers and SSSV Type: 5-1/2" TIW HBBP TP Packer Packers and SSSV MD (ft) and TVD (ft): 3720/3720 5-V2" Baker FBA Packer 3799/3799 12. Attachments: Proposal Summary ® Wellbore Schematic 0 13, Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service Z 14. Estimated Date for Commencing Operations: June 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 21 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Aivano, Mike (Udelhoven) be deviated from without prior written approval. Contact Email: mike.aivanoCQbp.com Authorized Name: Worthington, Area J Contact Phone: +1 9075645475 Authorized Title: Interventions & Integrity Engineer Authorized Signature: Date: �D COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 w ,r �Z Plug Integrity L ,Er- _ / BOP Test ❑ Mechanical IntegrityTestIr Location Clearance Other. PaO¢d CLO Cr -,7-v t- 4a GE L/ L9 iN C+�T LLMC .r.� Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS./MAY 0 91019 / Spacing Exception Required? Yes ❑ No PY Subsequent Form Required: I0-4 07 APPROVED BVTHE Approved by COMMISSIONER COMMISSION Dale: ORIGINAL V Vt Aj( MlSubmitForm and Forth 10-403 Revised 046V1 7 Approved application is valid for 12 months from the date of approval*Adachments in Duplicate 040�44 by S PWDW3-1 P&A Intervention Engineer Mike Aivano (907) 564-5475 Reviewed by Aras Worthington (907) 564-4102 Production Engineer Prachi Vohra (907) 564-4677 Expected Start Date: June 1, 2019 History PWDW3-1 is the produced water disposal well for FS3 with perforations from 5540' and — 6030' and in the Cretaceous. It was originally drilled and completed in 1978 with two RWO's to repair tubing related issues with the most recent in 1997. The well has had a history of having hard fill up to —4799' and consisting of schmoo, fines and asphaltenes. Fill clean outs in the past have involved a motor and mills to get through the fill, a video log in 2000 documented a pilot hole being drilled through the fill and not fully removing it along with a possible casing leak at 4799' md. An IPROF/ RST WFL was run in 2010, none of the 8 waterflow measurements indicated any movement of fluid behind casing, deepest at 4602' and and the shallowest at 3975' md. More recently, obstructions in the tubing have been found from as shallow as —3570' slur inside the 7" tubing. A caliper log run in April 2019 showed that there is buckling, areas of high metal loss and potential holes in the tubing. The well has been classified as Not Operable as of April 4, 2019 due to the tubing obstructions and the results of the caliper log. Most recent MIT -IA on Sept 12, 2018 passed to 1979 psi. A new produced water disposal well will be drilled once PWDW3-1 is abandoned. Objective The objective of this procedure is to place cement plugs across and above the reservoir zone as well as the upper wellbore to permanently abandon the well. Procedural Steps Special Projects Injectivity test into Control and Balance lines. Cement Control and Balance lines. PWDW3-1 P&A Sundry Q DHD 1. Wait on cement 3 days. Pressure test Control and Balance Lines to 2500 psi. Slickline 1. Drift and Tag to —3500' for SBHP Survey. 2. Take down hole static tempressure survey at —3500', —3400', —3300'. (This is required by the Geo's and drillers for an accurate pressure of the reservoir for drilling the replacement well) Fullbore 1. Pump the following surfactant wash for the tubing and reservoir zone. Bullhead down the tubing. • 5 bbls McOH 300 bbls of 1% KCL brine 2. Pump the following for a cement plug across the reservoir zone. Bullhead down the tubing. Estimated BHP = 2484 psi @ 5300' tvd • 5 bbls McOH • 10 bbls freshwater • 186 bbls of Class G cement as per design ( 25 bbls excess)' • 2 bbls freshwater • Foam Ball • 142 bbls diesel • Top of cement in the tubing at —3720' Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-100cc (20-50cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 4 hours Slickline / Fullbore 1. Tag TOC - AOGCC Witnessed 2. CMIT TAA to 1500 psi — AOGCC Witnessed " 3. Punch holes in 7" tubing at 3690'( use Eline if unable to use Slickline) Fullbore 1. Pump the following surfactant wash for IA. Pump down the tubing and take returns from the IA. 5 bbls McOH • 50 bbls hot (160°F) freshwater + surfactant ( 2 gal/mgal F103 and 2 gal/mgal UO67) • 240 bbls of 9.8 ppg brine PWDW3-1 P&A Sundry Q 2 2. Pump the following for a cement plug, down the tubing and up the IA. • 5 bbls McOH 10 bbls freshwater • 125 bbls of Class G cement as per design ( 12 bbls excess) • 2 bbls freshwater Foam Ball 117 bbls 9.8 ppg brine • 5 bbls freeze protect Top of cement in the tubing at -3200', top of cement in IA at surface. Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 pp Slurry Temperature: between 800 and 110°F Fluid Loss: 40-100cc (20-50cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: iMinimum 4 hours Slickline / Fullbore 1. Tag TOC 2 MIT -T to 1500 psi Eline 1. Perforate 7" tubing at 2990' md. 2. Perforate 7" tubing at 2840' md. Record static bottom hole pressures. Record static bottom hole pressures. The perforations and static pressures surveys are to document pressures in the SW sands for drilling purposes. After abandonment of PWDW3-1 a new well will be drilled to replace it. The Geo's and Drillers have some uncertainty of what the sand pressures may be in this zone and want to reduce risk during drilling of the new well by taking pressures in PWDW3-1 prior to abandonment. Fullbore 1. Pump the following down the tubing, bullheading into the perforations at 2990' and 2840' • 5 bbls McOH • 120 bbls of 9.8 ppg (to establish injection) 10 bbls freshwater 35 bbls of Class G cement as per design ( 10 bbls excess) • 2 bbls freshwater • Foam Ball • 96 bbls crude Top of cement in the tubing at -2500'. PWDW3-1 P&A Sundry Q 3 Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-100cc (20-50cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: I Minimum 4 hours Slickline / Fullbore 1. Tag TOC 2. MIT -T to 1500 psi 3. Perforate 7" tubing at 1300' for communication between the tubing and OA. Fullbore 1. Pump down the tubing and up the OA to remove Arctic Pack. • 50 bbls of hot (160°F) diesel • 50 bbls of hot (160°F) 9.8 ppg brine • Let soak for one hour • 50 bbls hot (160°F) freshwater + surfactant ( 2 gal/mgal F103 150 bbls 9.8 ppg brine. and 2 gal/mgal UO67) Pump OA surface cement plug down the tubing and up the OA. Top of cement will be at surface in the tubing and OA when completed. • 10 bbls freshwater • 145 bbls Class G Cement as per design( 20 bbls excess) Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab p +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-100cc (20-50cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 4 hours DHD Assist Fullbore with the cement job and pump N2 across the wellhead valves to remove excess cement from the valves. This will help when opening valves in later steps to check pressures. Bleed all wellhead pressures to 0 psi. Monitor wellhead pressures 24 hrs after pressure were bled to 0 psi. PWDW3-1 P&A Sundry Q Special Projects 1. Excavate and cut off all casings and wellhead 3' below original tundra level. Top job the conductor x 13-3/8" annulus, all other annuli, and the tubing as needed. 2. AOGCC witness cement tops in all annuli and tubing. 3. Bead weld marker cap on outmost casing string ( conductor pipe ) to read as follows: BP Exploration Alaska, Inc. PWDW3-1 PTD# 178-039 API# 50-029-20312 PWDW3-1 P&A Sundry Q PWDW3-1 Volume Calculations 9-5/8"47# OD ID BPF 7" 26# 7 6.276 0.0383 5-1/2" 17# 5.5 4.892 0.0232 4-1/2" 12.6# 4.5 3.958 0.0152 9-5/8" 47# 9.625 8.681 0.0732 9-5/8" x 4-1/2" 8.681 4.5 0.0535 9-5/8" x 5-1/2" 8.681 5.5 0.0438 9-5/8" x 7" 8.681 7 0.0256 13-3/8" x 9-5/8" 12.347 9.625 0.0581 Reservoir Abandonment Plug arm Too BPF Volume 9-5/8"47# 3690 6000 3924 0.0732 152.0 4-1/2" 12.6# 3924 3819 0.0152 1.6 5-1/2" 17# 3819 3720 0.0232 2.3 9-5/8"x 4-1/2" 3924 3819 0.0535 5.6 Middle Abandonment Plug Rtm Total Volume Total Volume +25 bbl 1•f 1b1.5 186.5 BPF Volume 7"26# 3690 1 3200 0.0383 18.8 9-5/8"x 7" 3690 1 0 0.0256 94.5 Total Volume 113.2 Total Volume +10 bbl 123.2 Plug to Cmt off the Test Perf Btm Top BPF Volume 7"26# 3000 2500 0.0383 1 19.2 Total Volume 19.2 Total volume +5 bbl 24.2 Surface Abandonment Plug Rrm Tnn BPF Volume 7"26# 1 1300 0 0.0383 49.8 13-3/8" x 9-5/8" 1 1300 0 0.0581 75.5 Total Volume 1Z5.3 Total Volume+20 bbl 145.3 PWDW3-1 P&A Sundry v2 6 ELEV a" do IAITimum ID = 3.625" @ 3878' 412' CAM Da NWPLE PER ORATON SLUAk O' iS LOG. BGS ON 05/19!78 ANGLE AT TOPPEW 00SSM M,xr. RNar b Rodmo CIS for hwWMd WN dab SIZE SFF I HTERVAL COWSW LATE 173' LAST woRCOVBt 5510 - SSS O OWSrt9 157 W27A1 5610-5650 O 0728/79 3715 4 5658-5673 O 071!6/79 1315 4 sm - 575 O 0726/79 1715 / S725-$78 O 0=211/79 3315 t 5852 - 58W O 0226/79 37? 4 BOZO - 6070 O 0726/79 PWDW3-1 I SAIT°NOTES: I 2356' 9.5/8" FO w/ Arctic Pack to Surface 2518' 9-5/8" FO w/ cmt below to "3028 4801' Est TOC for 9-5/8" DUE RB7 BY I CX WENTS I D\TE I REV BY I �TS 052728 ORGML COW ETON 0/111116 NcTimo 5 ml�r»nN /7MM 7' TBG COWLETION 030597 LAST woRCOVBt 01711001 S63T CpN9C1®rof/1M/As 030101 S&LG FINAL W27A1 IBRD CDfd�T1016 PWDW3-1 P&A Sundry v2 FOLC OE BAY lM you PNON/31 RMU N, 1780390 A I?b 5002320312-00 BP BgOms 195 (AIMkJ4 UATOR ELE_ stv Mote. 0 Perf @ -1300'-Circ Cmt to Surf in OA with Top of Cmt in Tbg at Surf Bullhead cement in to Perfs w/TOC at `2500' Mfniiwm D = 3-625-@387W 4112" CAM DB -6 NIPPLE Punch @ -3820'- Bullhead Cmt w/ TOC in Tbg at -3720' t9iORATON SL&tAkRf REF LOG'. tfaS ON 05119/78 ANG EAT TOPP66: 0 Q 5510 Mm. fakir b RoOucbn OB for lia Sl DM Mr+ FIEV BY I OOLOAENCS I GATE REV BY OOMf3T15 SiF MBNAL OVW MTE OOg587 t Ssa-55M O OZ716/79 S G 4 5810. 5650 O 01!16179 1 5658-5673 O 022" 1 5690. 5705 O 01116r79 r 1 5725-5735 O 01/Xr79 1 5952 - 5867 O 0726!79 1 6020 - 6070 O 02MM ISAFETY NOTES: 2356' 9-5/8" FO w/ Arctic Pack above 2518' 9-5/8" FO Cmt from 2518'to`3028' Perf and record pressure -2990'&2940' Punch @ -3690'-Circ Cmt to Surf in M with Top of Cmt in Tbg at -^3200' 4801" Est TOC for 9-5/8" OATS I FIEV BY I OOLOAENCS I GATE REV BY OOMf3T15 0527/78 17/3188 OOg587 OV10g1 Sf33T 7EEd S G PWDW3-I P&A Sundry v2 Cmt added for Upper Aband Cmt added for Res Aband Plug ❑ Cmt from Drilling Phase na11OE BAY UNIT V43 -L g1gVl11 PEMU Nv. 1760390 ARN1: 5002420.712-00 ® 6pbrMbn (AIr►y BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT 01-05B (207-048) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates r rrr rr4 116 1 11 i�UIP-101wZIM 5 (Md): 74,298,972 ��Illllllll�llllllllllllllll�llll��11•�III�� ������ Clllllll��� _ IIIII��R��Yiidir' .. - rlllll��l� v��u► �� 1,000,000 t 0 0 a 100,000 iLU Z>o m10,000 w O O v LL a 1,000 u 3 U N 100 0 Q t 10 1 Jan -2005 Jan -2007 Jan -2009 Jan -2011 Jan -2013 Jan -2015 Jan -2017 Jan -2019 Produced Gas (MCFM) . GOR a Produced Water (BOPM) o Produced Oil (BOPM) 10,000,000 W w 1,000,000 N 0 O 100,000 0 CD0 10,000 T 0 W 1,000 H O 100 r(1 0 0 10 s SPREADSH EET_2070480_PBU_O1-O5B_Prod-I nject_Cu wes_W ell_Oil_V 120_201904O2.xlsx 5/6/2019 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Thursday, April 4, 2019 1:45 PM To: AK, OPS EOC Specialists; AK, OPS FS3 DS Ops Lead; Ak, OPS FS3 Facility PTL; Ak, OPS FS3 Field PTL; AK, OPS FS3 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Brown, Don L.; G GPB FS3 Drillsites; Meixueiro, Paulina; Vandergon, Mark A; Vohra, Prachi; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (DOA) Subject: NOT OPERABLE: Injector PWDW3-1 (PTD #1780390) Loss of reservoir access due to restriction in wellbore ------ Attachments: PWDW3-1.pdf All, Injector PWDW3-1 (PTD #1780390) was undergoing coil tubing service work on 4/4/2019 when a wellbore restriction was found that prevented access to the reservoir. The restriction is an indication of tubular damage and possible loss of well integrity. At this time the well is reclassified as Not Operable and will remain shut in. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 ICS(4 PL06 h6 3--I PmF/60.30 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, May 02, 2015 10:27 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator � 5146 _ � Subject: April 2015 AOGCC MIT Forms Attachments: April 2015 MIT Forms.zip Please find the attached MIT forms for April 2015: SCANNED JUN 0 g 201 5 Well PTD Comments 13-19 1811800 AOGCC Form A-08 1740040 AOGCC Form A-27 1982350 AOGCC Form L-105 2020580 AOGCC Form NGI-03 1750610 AOGCC Form P2-28 1950440 AOGCC Form P2-46 1931320 AOGCC Form PWDW3-1 1780390 AOGCC Form S-09A 2140970 Post RWO S-11B 1990530 AOGCC Form V-217 2061620 AOGCC Form Kevin Parks (Alternate: Whitnrev Petit?, BP Alaska-Well Integrity Coordinator Glint Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 • r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggl alaska.gov AOGCC.Inspectors@alaska.gov phoebe.brooks(rDalaska.gov chris.wallace(rDalaska.gov OPERATOR: BP Exploration(Alaska),Inc. / /41 l s FIELD/UNIT/PAD: Prudhoe Bay/GPB/PWDW3 DATE: 04/17/15 OPERATOR REP: Whitney Pettus AOGCC REP: Witness waived by Chuck Scheve-voicemail Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well PWDW3-1 ' Type Inj. W _ TVD _ - 3,720' Tubing - 995_ - 998 ' 1,000 -1,002_ Interval 4 P.T.D. 1780390 ' Type test P Test psi 1500 Casing 396_ 2,001. -1,976 '1,964 P/F P Notes: 4 yr MIT-IA cretaceous disposal OA 193 218 223 230 146 F TEMP Pumped 1.0 bbl ambient diesel TIME 1050 1102 1117 1132 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing . P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD TubingInterval P.T.D. Type test Test psi Casing P/F Notes: OA S TYPE INJ Codes TYPE TEST Codes INTERVAL Codes II D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU PWDW3-1 04-17-15.xls • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: --/ / DATE: Monday, May 09, 2011 Jim Regg 5 //, i ( P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PWDW3 -1 FROM: Lou Grimaldi PRUDHOE BAY UNIT PWDW3 -1 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT PWDW3 - 1 API Well Number: 50 029 - 20312 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG110504172345 Permit Number: 178 - 039 - Inspection Date: 5/4/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j PWDW3 -I Type Inj. W TVD 1 3720 1 IA 10 1600 1730 P.T.D1 1780390 IT sPT Test psi 1500 OA 6 , 70 70 Interval 4YRTST p/F I ' Tubing 640 650 820 Notes: Test terminated due to FS -3 changing rate and temperature of well. Will retest at a future date. Mr' a. 2 Lif Monday, May 09, 2011 Page 1 of 1 . • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Ell( lit DATE: Monday, May 09, 2011 TO: Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PWDW3 -1 FROM: Lou Grimaldi PRUDHOE BAY UNIT PWDW3 -1 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv2,4 - NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT PWDW3 - 1 API Well Number: 50 029 - 20312 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG110506085009 Permit Number: 178 - 039 - Inspection Date: 5/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well TPWDW3-1, Type Inj. i w- 1 TVD I 3720 ' IA 708 1919 - 1886 1883 1879 1876 P.T.D 1780390 'tTypeTest SPT I Test psi , ' i OA 70 310 315 360 385 400 Interval 4YRTST pp' . „ 1 4 7 Tubing 1338 1339 1339 , 1341 1341 1341 Notes: .7 Bbl's to pressure up. OA had increase during test. I left results as incomplete and will be decided in town. . Al i\ na ct 4s - 150 '1' 5 ; 1 Atreo14, OA- c{e a-s - -44 - Vie. a e9 7�aP, rate /;.t ei 1 \APY 3. 2O11 Monday, May 09, 2011 Page l of 1 it • Page 1 of 1 Regg, James B (DOA) X,2ef a- ^51 Aft it05 - 0( 5 From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, May 09, 2011 10:39 AM To: Regg, James B (DOA) Subject: RE: PWDW3 -1 MIT 5 -5 -11 ) Attachments: PWDW3 -1 (PTD #1780390) TIO and Injection Plot.doc Jim, Enclosed are the 90 day TIO and Injection plots you requested for PWDW3 -1 (PTD #1780390). Please advise me if you need further information. Gerald Murphy BPXA Well Integrity Coordinator From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, May 09, 2011 10:18 AM To: AK, D &C Well Integrity Coordinator Cc: Grimaldi, Louis R (DOA); Maunder, Thomas E (DOA) Subject: PWDW3 -1 MIT 5 -5 -11 Inspector witnessed MIT 5 -5 -11; results inconclusive due to increasing pressure in IA during test. Please send 90day TIO Plot for PWDW3 -1 (PTD 1780390); would appreciate a rate plot as well for same timeframe. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 5/9/2011 • PWDW3-1 (PTD #1780390) TIO Plot Well: PWDW3-1 i Tbg -ire- IA 2 C 00A —4--000A \ On \ - , - - - 02/12,1 02; n21211 07 r.1 ■ 0' 31 11 '1i 0 1/03/11 0/' '16111 r /21'11 0 ' "60 11 07■11 PWDW3-1 (PTD #1780390) Injection Plot We PWDW3-1 40 I 21130) 471 , 29 C20 4,3,C .22 '3^ J 2.1,023 ctr — WHIP .7_ 16,1:0 43 — GI 14,0361 — Other 12,170 re■ On 1E0 10 1.,:3 6,003 1 4.003 2,02' 02/22,11 02/16,11 012/210 '11 00'05/1 i 02/12/11 02 1 ',11 03'20 04/° O41 04 01/2311 01133/11 03,07/11 r . • 0 TREE = MCEVOY , j WELLHEAD = GRAY PWD3 -1 SAFETY NOTES: ■ ACTUATOR = 7 i KB. ELEV = 78' I BF. ELEV = KOP= 0 ■ , Max Angie = 0 Co _7 2130' I— 7' HES MBR SSSV NIP Oaten MD = 6161' b W /BLANKNG SLV , 0 =5.983* ■ DatamTVD- { 113 -3/8" CSG, 72 #, N-83, D = 12347' H 2737' F--A Minimum ID = 3.625" @ 3878' 4-1/2" CAM DB -5 NIPPLE 17" TBG. 26 #, L-80, .0383 bpf, 0 = 6.276" H 3719' mmi — 371 s 7 X 5-1/7 XO, ID= 4.865" H� I ITOPOF5- 1l2 "TBG1 --I 3719' { ►4"! i 3720' H9 -98 ° X 5- 1 /2" TIN FE- BP TPfCR, D =4.865" 1 3754' H5- 1 /2 " HESXN NP, ID= 4.551 i ►Z�I m il 3799" H9.5/8 "X 5.1/2' BKRFB -1 PrCR 15 -1/2 TBG,17 #, L-80, .0232 bpf, 0 =4.892" I 3807' W ITOP 5 -1/2" TBG-IPC H 3802 3$07' H5-112" MU. ESHOE (RUN IN BKR PKR SBR) 15 -1/2" TBG -PC, 17 #, L -80, .0232 bpf, 0 = 4.892" J--f 3819' 3819' 1 112" X 4-1/7 X01 ITOP OF 4-1/7 TBG -NPC H 3819' 3878' I--i4 -112" CAM DB -5 NF? 0 = 3.625' 14 -1 /2 TBG -APC, 12.6 #, L-80-0152 bpf, ID =3.958" H 3924' 3924' H4 -112' TUBING TAI. I I 3920' - H EL C TT 01/11/881 PERFORATION SUMMARY REF LOG: BHCS ON 05 /19/78 ANGLE AT TOP PER F: 0 @ 5540' Nate: Refer to Production DB for historical perf data SIZE SW" INTERVAL Opt/Sq{z DATE 3 -318" 4 5540 - 5565 0 02/26/79 3 -3/8' 4 5640 - 5650 0 02/26/79 3 -3/8" 4 5658 - 5673 0 02/26/79 { 3 -3/8" 4 5690 - 5705 0 02/26/79 3 -3/8" 4 5725 - 5735 0 02/26/79 3 -3/8" 4 5852 - 5867 0 02/26/79 3 - 3/8' 4 6020 - 6030 0 02/26/79 ' 5991' j--1FISH -4-1/2" TUBING TAIL Il i 6004' HFISH - PERF GUN 1 I I PBTD I-- 6050' r f'i'tirFfft't 4..0•••••11• ' ,,t f #. ! #. . 1.. 1 t � # 4 I9- 5/8`CSG,47 #,N80, 8.681" H 6161' 46/446#4a DATE - REV BY COMMENTS DATE REV BY COMMENTS ' PRUDHOEBAY UNIT 05/27/78 OFOGNAL COMPLETION WEIL: FWDW3 -1 12/31/88 7" TBG COMPLETION P62MT t'b: 1780390 03/03/97 LAST WOW(OVER API Ab: 50 -029- 20312 -00 01/10/01 S - SLT' CONVERTED TO CANVAS SEC 3, T10f R14E, 4703.24' FTi 8 41 1.62' FNL 1 03/01 /01 SIS-LG FtiAL 09/27/01 RN/TP CORRECTIONS _ BP Exploration (Alaska) • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ^ Repair Well ^ Plug E'erfcratians ^ Stimulate^ Oiher ~, II of Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ and Water fIOW 1001 Change Approved Program ^ Operat. Shutdown[ Perforate ^ Re-ante Suspended Well ^ 2. Operator BP Exploration (Alaska}, Inc. 4. Well Class Before Work: . Permifto Drill Number; Name: Development ^ Exploratory ^ ' ' 178-0390 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50.029-20312-00-00 II. Property Designation {Lease Number) : ` 9. Well Name and Number: \ ADLO-026312 PBU PWDW3-1 PRUDHOE BAY FIELD! PRUDHOE BAY POOL '11. Present bNc1I Condition Summary: Total Depth measured 6150 feet Plugs (measured) None feet true vertical 6150 feet Junk (measured) 5991' 6004' feet Effective Depth measured 6050 feet Packer (measured) 3720 3799. true vertical 6050 feet (true vertical) 3720 .3799, Gasinfl Length Size MD TVD Burst Collapse Structural Conductor 80 20" SURFACE - 123 SURFACE - 123 Surface 2737 13-3/8" 72# N-60 SURFACE - 3737 SURFACE - 2737 4930 2670 Intermediate 6102 9-5/8" 47# N-80 SURFACE - 6161 SURFACE - 6161 6870 4760 Production Liner Liner Pertoratior3 depths Measured depth: SEE ATTACHED - ~ ,~ ~ ,,,,- True Vertical depth: _ ,,,,, _,. Tubing, (size, grade, measured and true vertical depth) 7" 26# LL-80 SURFACE - 3719 SURFACE -.3719 5-1l2" 17# L-8Q 3719 - 3619 3719 - 3819 4-1/2" 12.6# L-80 3819 - 3924 3819 - 3924 Packers and SSSV (type, measured and true vertical depth} 9-5/8"X5-1l2" TIW HB-BP T PKR 3720 ,3720. 9-5/8"X5-112" 8KR F6-1 PKR. 3799 3799. i 2. 5innulation or ccn~©nt squeeze summary: Intervals treated (measured): g~,,~~ ~ . r ~`~~ a.~ s ~f { ~ ~ ~ ~ ~5 ~ ~ ~ 4 ° Tr~atment'descriptions including volumes used and final pressure: . 13. Representative Daily Average Production or Injection Data ~iI-8b( Gas-htcf 4~iater-Bbl Casing Pressure Tubing pressure Prior to well operetioht Subsequent to operatlort; 14. Attachments: .Weil Class alter work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X ~ti'eli Status after work: Oil Gas WDSPi, ~ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 77. (hereby certify u~al t11e foregoing is true and correct tothe best of my knowledge. Sundry Number or N/t. if C.O. Exempt: NA Contact Gary Preble ..___ Printed Name Gary i'reblF Title Data Management Engineer ~ i / Signature ~ ~~ Phone 564-4944 Date 7!1!2010 corm ~u-~u~t r~eviset}'nwua ~ .,u~.~~." ~~~~°'°' ~~^r .~ ~~ ~ 7- z ~ - to STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate^ Other Q Caliper Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ and Water flow locl Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ 178-0390 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-20312-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028312 PBU PWDW3-1 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 6150 feet Plugs (measured) None f t true vertical 6150 feet Junk (measured) 5991' 6004' feet Effective Depth measured 6050 feet Packer (measured) 37 3799 true vertical 6050 feet (true vertical) 20 3799 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" SURFAC 123 SURFACE - 123 Surtace 2737 13-3/8" 72# N-80 SURF E - 37 SURFACE - 273 4930 2670 Intermediate 6102 9-5/8" 47# N-80 SURFACE - 61 1 RFACE - 61 6870 4760 Production ,~T Liner Liner _ ~. Perforation depth: Measured depth: SEE ATTAC ~ _ _ _ ~ ~ True Vertical de th: ~ _ _ p _ ~ Tubing: (size, grade, measured and true vertical depth) 7" 26# L-80 SURFACE - 3719 SURFACE - 3719 5-1/2" 17# L-80 3719 - 3819 3719 - 3819 ~ ,, 4-1/2" 12.6# L-80 3819 - 3924 3819 - 3924 Packers and SSSV (type, measured and true vertical depth) 9-5/ X5-1/2" TIW HB-BP T PKR 3720 3720 /8"X5-1/2" BKR FB-1 PKR 3799 3799 R~~~~vE® 12. Stimulation or cement squeeze summary: ~ ~) (~ 3 (~ 2 ~ ~ o Intervals treated (measured): ~lasl~a di! €~ ~a~ Cu'~. ~crxnission Treatment descriptions including volumes used d final pressure: r~flCitflf 3~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well opera ' n: Subsequent to ope tion: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys un Exploratory^ Development ^ Service ^~ Daily Report of Well Oper ions X 16. Well Status after work: Oil Gas WDSPL ~ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify t t the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Conta Gary Preble Printed Name Gary Pre _ Title Data Management Engineer Sign ure Pho 564-4944 Date 6/30/2010 roan iu-4u4 rceviseu iicwy ~ ~upm~ JUry ~ '~ ~~~~ auunm viiyuiai vnry PWDW3-1 178-039 PERF ATT~4CHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base PWDW3-1 2/26/79 PER 5,540. 5,565. PWDW3-1 2/26/79 PER 5,640. 5,650. PWDW3-1 2/26/79 PER 5,658. 5,673. PWDW3-1 2/26/79 PER 5,690. 5,705. PWDW3-1 2/26/79 PER 5,725. 5,735. PWDW3-1 2/26/79 PER 5,852. 5,867. PWDW3-1 2/26/79 PER 6,020. 6,030. AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • WSR -PWDW3-1 - 6/17/2010 • WELL SERVICE REPORT Page 1 of 1 WELL DATE JOB SCOPE DAY SUPV PWDW3-1 6/17/2010 CALIPER ELIAS COST CODE PLUS DAILY WORK NIGHT SUPV APBFS3WPOP-M IN PROGRESS TILBURY MIN ID DEPTH TTL SIZE KEY PERSON UNIT 3.625 " 3878 FT 4.5 " SWCP-GOSSETT SWCP #10 RU SWCP #10 ON PWDW3-1 ***CONT WSR ON 6-18-10*** LOG ENTRIES Init Tb IA OA -> 0 0 0 TIME COMMENT 13:00 SAFETY STAND DOWN SLB CAMP TO COVER RECENT INCIDENT 15:30 TRAVEL TO FS3/ PWDW3-1 16:00 MISU, INSP LOC, PERMIT UP IN CONTROL ROOM, PJSM, RESEARCH JOB 17:00 BEGIN R/U .125" WIRE, 24 TURNS 18:20 C/O TO GOSSETT, INSPECT LOC, PJSM 20:30 TS: 8'x 1-7/8" WB, OJ, LSS, STROKE SSV 21:00 RU COMPLETE, STANDBY FOR BLEED TANK AND TRIPLEX 23:30 BLEEDTANK ON LOC, STANDBY FOR TRIPLEX 23:59 CONT WSR ON 6-18-10 Final Tb IA OA -> 0 0 0 FLUID SUMMARY N/A http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=626E247B64414737... 6/23/2010 WSR - PWDW3-1 - 6/17/2010 ~ • WELL SERVICE REPORT Page 1 of 1 WELL DATE JOB SCOPE DAY SUPV PWDW3-1 6/17/2010 CALIPER BOYLES COST CODE PLUS DAILY WORK NIGHT SUPV APBFS3WPOP-M BRUSH /BROACH; CALIPER TUBING; HOT OIL MOFFITT TREATMENT; PUMP MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0 " 0 FT 0 " LRS-BARTLETT LRS 70 DAILY SUMMARY TIO= Assist SLB SLickline ,Brush and Flush for Caliper run. JOB CONTINUED on 06-18-10 LOG ENTRIES Init-> TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 20:00 Start ticket, Road to FLO 3 20:20 Arrive at Flo # 3 ,Check in With SLB 20:40 Go si n in at FLO 3 control room, Fuel units 21:16 PJSM 21:25 Sot units 21:30 Grou PJSM 21:50 Support -Move units slightly,Lay out Iines,Standb for Bleed tank to arrive 23:45 Support -Bleed tank arrives, Wait for Triplex to arrive ,Have not been inside wellhouse 23:59 End ticket Job CONTINUED on 06-18-10 Finales FLUID SUMMARY BBIs diesel http://app s2-alaska.bpweb.bp. com/awgrs-wellservicereport/default. aspx?id=4967F5 C6A78944039... 6/23/2010 WSR - PWDW3-1 - 6/18/2010 • WELL SERVICE REPORT Page 1 of 2 WELL DATE JOB SCOPE DAY SUPV PWDW3-1 6/18/2010 CALIPER ELIAS COST CODE PLUS DAILY WORK NIGHT SUPV APBFS3WPOP-M CALIPER TUBING TILBURY MIN ID DEPTH TTL SIZE KEY PERSON UNIT 3.625 " 3878 FT 4.5 " SWCP-GOSSETT SWCP #10 B&F TBG W/ 7" BLB & 5.87" G-RING DOWN TO XO @ 3696' SLM W/ NO PROBLEMS B&F TBG W/ 5.5" BLB & 4.45" G-RING, UNABLE TO PASS XN NIP @ 3736' SLM B&F TBG W/ 5.5" BLB & 4.00" G-RING DOWN TO XO @ 3788' SLM W/ NO PROBLEMS B&F TBG W/ 4.5" BLB & 3.50" G-RING OUT EOT, CLEANED UPTIGHT SPOT @ 3849' SLM D&T W/ 3.50" CENT, TEL, & S.BAILER, LOC TT @ 3891' SLM/ 3920' ELM, 29' CORR, TD @ 4627' ELM, 913' FILL ,SAMPLE OF SCHMOO RAN PDS CALIPER AS PER PROGRAM, GOOD DATA *""WELL S/I ON DEPARTURE, TURNED OVER TO FS3 CONTROL ROOM"** LOG ENTRIES Init Tb IA OA -> 0 0 0 TIME COMMENT 00:00 CURRENTLY STANDBY FOR A TRIPLEX 01:22 TRIPLEX ON LOC, PT LUB 200# - 2000# 01:39 PJSM W/ LRS, RU, PT HOSE, START PUMPING HOT DIESEL 03:10 20 bbl AWAY, RIH W/ OC, KJ, 7" BRUSH, 5.87" G-RING, BRUSHED DOWN TO 7" X 5-1/2" XO AT 3696'SLM W/ NO PROBLEMS 117 bbl DIESEL AWAY OOH W/TLS 04:26 RIH W/ OC, KJ, 5-1/2" BRUSH, 4.45" G-RING, UNABLE TO PASS XN NIP AT 3736'SLM POOH 137 bbl AWAY 05:31 RIH W/ OC, KJ, 5-1/2" BRUSH, 4.00" G-RING, RUSHED TO 5-1/2" X 4-1/2" XO AT 3788'SLM, NO PROBLEMS 06:14 C/O TO EICHELBERGER, INS LOC, PJ NT TECH ON L ECK OUT SSV PANNEL 07:19 RIH W/ OC, KJ, 4 1/2" BLB, & 3.50" G-RING. BRUSHED 4 1/2" TBG FROM 3819' MD OUT TT, CLEANED UP TIGHT SPOT 3849' SLM, POOH ' a~ ` ~ 07:59 OOH, R/D LRS 08:44 MECHS ON LOC INSPECTING PRESSURE RELIEF VALVE SETTINGS ON ALL EQUIPMENT 09:23 SETTING INSPECTION COMPLETE, PROCEDE W/ DRIFT RUN 09:52 RIH W/ 3.50" CENT, TEL, & S.BAILER, LOC TT @ 3891' SLM/ 3920' ELM, 29' CORRECTION, TD @ 4598' SLM/ 4627' ELM/ CORRECTED 11:00 OOH, SAMPLE OF SCHMOO 11:17 RIH W/ CALIPER, DTR NOT COUNTING CORRECTLY, POOH 11:21 OOH, RE-SET CALIPER & REPLACE ENCODER CABLE 12:09 RIH W/ CALIPER 12:38 PARK 4000' SLM/ 3999.95' DTR BOX, WAIT FOR ARMS TO OPEN 12:50 14:21 SIBO, STANDBY FOR DATA 15:20 GOOD DATA, NOTIFY WSL, RDMO 16:47 R E ,SWAB S/I, MASTER OPEN, WING S/I & FLAGGED, SSV TO PANNEL, CASING VALVES OPEN TO GAUGES 16:59 RD COMPLETE, STANDBY FOR NEXT JOB 20:59 TRAVEL TO DS 15-45 END TICKET Final Tb IA OA -> 400 0 0 FLUID SUMMARY WSR - PWDW3-1 - 6/18/2010 ! • Page 2 of 2 1 BBL DIESEL TO PT LUB http://apps2-alaska.bpweb.bp.com/awQrs-wellservicerenortldefault.asnx?id=8696'7F46E36E4136B... 6/23/2010 WSR - PWDW3-1 - 6/18/2010 i WELL SERVICE REPORT Page 1 of 2 WELL DATE JOB SCOPE DAY SUPV PWDW3-1 6/18/2010 CALIPER BOYLES COST CODE PLUS DAILY WORK NIGHT SUPV APBFS3WPOP-M BRUSH /BROACH; DRIFT/TAG; HOT OIL MOFFITT TREATMENT; PUMA MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0 " 0 FT 0 " LRS-BARTLETT LRS 70 JOB CONTINUED from 06-17-10 TIO= 0 /20 /0 temp = SI Assist SLB Slickline Brush and Flush for Caliper run ,Pump 10 bbls 60/40 Spear followed by 155 bbls hot Diesel down TBG while S/L RIH. S/L in control of well upon departure. FWP=400/20/0 **IA & OA=OTG** LOG ENTRIES Init-> 0 20 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 00:00 Support -Start ticket, Job continued from 06-17- 10, Waitin for Tri lex to arrive 01:21 Tri lex arrives SLB Testin Lubricator 01:45 Ri u to Pum And Sub 02:12 PT surface lines to 3500 si 02:20 0 20 0 Static ressures , 150 si on S-riser 02:32 1 0/start 60/40 100 20 0 Pum down Tb 02:37 1 3 45 *f 150 20 0 02:40 1 5 45 *f 200 20 0 02:44 1 10 45 *f 250 20 0 Swa to Diesel 02:49 1 0/start dsl 40 *f 150 20 0 Start warmin u dsl 02:55 .6 2.9 120 *f 175 20 0 02:57 1 5.5 "' 170 *f 210 20 0 03:02 1 11 155 *f 210 20 0 03:10 1 20 155 *f 210 20 0 03:14 .5 23 150 20 0 Slow to let SLB Slickline o into well 03:18 1 27 100 *f 220 20 0 Burner shut off when I slowed rate, Back up to rate 03:24 1 33 150 *f 250 20 0 SLB O erator would like us to increase rate 03:31 1.9 45 145 *f 600 20 0 03:33 1.9 50 155 *f 600 20 0 03:43 1.9 69 155 *f 625 20 0 03:55 1.8 93 680 20 0 04:06 1.8 114 700 20 0 Cool down Coils 04:08 1.8 117 100 *f 700 20 0 SD Standb for SLB Slickline to C/O tools 04:56 1.7 117 130 *f 700 20 0 Resume um in and Heatin diesel 05:06 1.7 130 155 *f 700 20 0 05:09 1.7 133 700 20 0 Cool down Coils 05:10 1.7 137 90 *f 700 20 0 SD,SLB Slickline C/O tools 06:35 Crew C/O Houlton for Bartlett 07:26 .65 137/st DSL 70* 400 20 0 Continue um in while heatin . 07:43 .6 148 180* 450 20 0 07:49 .6 152 450 20 0 Cool down. 07:54 .6 155 100* 450 20 0 SD 08:20 RD 09:15 Si n out FS3 Control Room. 09:59 End ticket. - - Final-> _ http://apps2-alaska.bpweb.bp.com/awgrs-wellservicere WSR - PWDW3-1 - 6/18/2010 DISPATCHED T _ _ _ n C http://apps2-alaska.bpweb.bp.com/awgrs-wellservicerenort/default.asnx?id=C477CFFBC 18D467... 6/23/2010 WSR - PWDW3-1 - 6/19/2010 WELL SERVICE REPORT • Page 1 of 1 WELL DATE JOB SCOPE DAY SUPV PWDW3-1 6/19/2010 ANN-COMM CLINGINGSMITH COST CODE PLUS DAILY WORK NIGHT SUPV APBFS3WPOP-I AC-MONITOR UNKNOWN MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0 " 0 FT 0 " CH2-MILLER UNKNOWN I T/I/O = SSV/Vac/Vac. Temp = SI. Monitor for bubbling in cellar. PWI.2" integral installed on IA. Cellar is dry & has no bubbling. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. httn_//anns2-alaska bnweb.bn.com/aw~rs-wellservicerenortJdefault_asnx?id WSR - PWDW3-1 - 6/22/2010 WELL SERVICE REPORT Page 1 of 2 WELL DATE JOB SCOPE DAY SUPV PWDW3-1 6~22~20~ ~ CALIPER DAHLEM COST CODE PLUS DAILY WORK NIGHT SUPV APBFS3WPOP-M INJECTION PROFILE; RST / CNL / PNL BRACKETT MIN ID DEPTH TTL SIZE KEY PERSON UNIT 3.625 " 3878 FT 3.958 " SWS-DECKERT SWS 2266 INITIAL T/IA/OA = 200/0/0 PSI RIH WITH WELL SHUT-IN. START WELL INJECTING PRODUCED WATER AT 5 MBWPD. CONDUCTED 80 FPM UP PASS WITH SPINNER/TEMP/PRESS. INCREASE INJECTION TO 20 MBWPD AT 205 PSI AND 148 DEGF. CONDUCT 80 FPM UP FBS PASS WITH SPINNER/TEMP/PRESS. COMPLETE RST-WFL STATION LOGS AT 4602', 4575', 4475', 4375', 4275', 4175', 4075' AND 3975'. NO ANOMALIES FOUND. SHUT IN WELL. CONDUCT FINAL 80FPM RST-WFL VERIFICATION PASS. RDMO AND HAND OVER TO DSO. FINAL T/IA/OA = 200/0/0 PSI ***JOB COMPLETED*** LOG ENTRIES Init Tb IA OA -> 200 0 0 TIME COMMENT 10:00 ARRIVE ON LOCATION. WELL INJECTING ON ARRIVAL. BEGIN SPOTTING 10:35 MEET WITH FSO AND DISCUSS JOB. BEGIN SIGNING PERMIT. 10:45 PERMIT SIGNED. CONTINUE SPOTTING EQUIPMENT 10:56 SPOTTING COMPLETE. BEGIN RIG UP. 10:57 TREE CAP WEEPING AND GAGE PEGGED OUT AT 3000 PSI. DSO CONTACTED AND SWAB CRACKED OPEN TO BLEED PRESSURE. 12:01 WELL SHUT IN. STOP FOR SAFTEY MEETING 12:14 SAFTEY MEETING COMPLETE. CONTINUE RIG UP. 13:11 SURFACE CHECK EQUIPMENT 13:22 SURFACE CHECK GOOD. CONTINUE RIGGING UP. 13:37 STAB ONTO WELL. FUNCTION TEST WIRELINE VALVES. 13:58 WIRELINE VALVES GOOD. BEGIN PT 14:22 PT GOOD. OPEN SWAB AND RIH WITH MH22(6X3)/ 1 11/16" WEIGHT/ PSP/ PILS/RST/PEGS, OAL 47', WEIGHT 200 LB 14:54 ON BOTTOM, BEGIN CORRELATION 15:25 CORRELATION GOOD BEGIN INJECTING AT 5 MBWPD 15:44 BEGIN 80 FPM UP PASS: 139 DEGF, 2085 PSI 15:55 UP PASS COMPLETE, BEGIN 80 FPM DOWN PASS: 134 DEGF, 1603 PSI 16:08 DOWN PASS COMPLETE. BEGIN INJECTING AT 20 MBWPD 16:40 UP PASS AT 80 FPM: 129 DEG F, 2168 PSI. NO ANOMALIES 16:53 UP PASS COMPLETE. DROP DOWN TO TD TO BEGIN STATION LOGS. 17:08 INJECTING AT 205 PSI & 148 DEG F 17:15 BEGIN STATION 1 AT 4602' 17:25 BEGIN STATION 2 AT 4575' 17:41 BEGIN STATION 3 AT 4475' 18:01 BEGIN STATION 4 AT 4375' 18:08 BEGIN STATION 5 AT 4275' 18:19 BEGIN STATION 6 AT 4175' 18:21 BEGIN STATION 7 AT 4075' 18:43 BEGIN STATION 8 AT 3975' 18:55 BEGIN 40 FPM DOWN TOOL CHECK 19:16 TOOL CHECK GOOD. ON BOTTOM. BEGIN FINAL 80 FPM UP PASS. 19:37 UP PASS GOOD. CONTINUE POOH. 19:38 CHANGE OUT WITH NIGHT CREW 20:05 TOOL AT SURFACE, CLOSE SWAB. 20:31 TREE CAP PRESSURE TESTED, NEW O RING INSTALLED 21:20 RI DSO NOTIFIED OF DEPARTURE Final Tb IA OA -> 200 0 0 httn://anns2-alaska.bnweb.bp.com/awQrs-wellservicereport/default.aspx?id=F8DC43725BE042C... 6/23/2010 WSR - PWDW3-1 - 6/22/2010 ~ , ~SCHLUMBERGER I WS DISPATCHED 1 BBL DIESEL FOR PT 1 BBL METH FOR POOH httn://anns2-alaska.bnweb.bn.com/aw~rs-wellservicereport/default.aspx?id=F8DC43725BE042C... 6/23/2010 ~. 11~ler~talr' 11~ulti-Finger ~eliper fag F~esutt~ ~umn~ary~ Company: BP Exploration (Alaska), Inc. Well: PWDW3-1 Log Date: June 17, 2010 Field: Prudhoe Bay Log No.: 10641 State: Alaska Run No.: 1 API No.: 50-029-20312-00 Pipet Desc.: 7° 26 Ib. L-80 Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvll.: 3,728 Ft. (MD) Pipet Desc.: 5.5" 17 Ib. L-80 IPC Top Log Intvl2.: 3,728 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl2.: 3,816 Ft. (MD) Pipe3 Desc.: 4.5" 12.6 Ib. L-80 NPC Top Log Intvl3.: 3,816 Ft. (MD) Pipe3 Use: Tubing Tail Bot. Log Intvl3.: 3,920 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the 4.5" tubing tail @ 3,920' (FEND). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage and to verify the presence of the 4.5" tubing tail and jewelry configuration. The caliper recordinas indicate the _ presence of the 4.5" tubina tail from 8.816' to 3 G20' (EI nnD,1K A 3-D log plot of the caliper recordings across this interval showing the jewelry configuration is included in this report. The caliper recordings indicate the 7" tubina. 5.5" tubina. and 4.5" tubina tail aooear to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross- sectional wall loss or I.D. restrictions recorded. 7" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 19%) are recorded. 7" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 11 %) are recorded. 7" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. 5.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 7%) are recorded. 5.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 1 %) are recorded. 5.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone; (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 :7 4.5" TUBING TAIL -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 10%) are recorded. 4.5" TUBING TAIL -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 3%) are recorded. 4.5" TUBING TAIL -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. Field Engineer: G. Etherton Analyst: C. Waldrop Witness: S. Chambers & 8. Tillbury ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • ~,~~ PDS Multifinger Caliper 3D Log Plot Company : BP Exploration (Alaska), Inc. Field : Prudhoe Bay Well : PWDW3-1 Date : June 17, 2010 Description : Detail of Caliper Recordings Across 4.5" Tubing Tail. • _ PDS Report Overview ~~ ~ Body Region Analysis Well: PWDW3-1 Survey Date: June 17, 2010 Field: Prudhoe Bay Tool Type: UW MFC 40 No. 217957 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7 ins 26 f L-80 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 100 80 60 40 20 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 94) pene. 1 12 81 0 0 0 loss 1 92 1 0 0 0 100 80 -- - -- 60 - 40 20 - 0 - I~ ~ isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole _ Number of joints damaged (total = 91) 6 85 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 1 ~~ i ~ I I 21 II I I I 41 i ~i i 59 i I 79 i Bottom of Survey = 91.2 Analysis Overview page 2 Damage Configuration (body ) U • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 26.0 ppf L-80 Well: PWDW3-1 Body Wall: 0.362 in Field: Prudhoe Bay Upset Wall: 0.362 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: June 17, 2010 Joint No. Jt. Depth (Ft.) Pen. Pen. Pen. Metal Upset Body % Loss (Ins.) (Ins.) ~I % Min. D LD• Comments (Ins.) 0 1 32 0 0.05 14 ~ 6 6.26 Shallow corrosion. 2 67 0 0.04 12 6 6.27 Shallow corrosion. 3 106 0 0.05 14 7 6.26 Shallow corrosion. 4 143 0 0.03 9 2 6.24 Shallow ittin . 5 183 0 0.05 14 4 6.25 Shallow corrosion. 6 7 8 223 264 305 0 0.04 12 7 0 0.04 12 6 --- _ 0 0.05 14__ . 7_ 6.27 Shallow corrosion. 6.27 Shallow corrosion. 6.27 Shallow corrosion. 9 10 11 346 387 427 0 0.05 14 7 0 0.03 8 2 0 0.06 17 4 _ 6.27 Shallow corrosion. 6.23 6.25 Shallow corrosion. I 12 , - 467 0 0.05 14 - _ 8 _ 6.28 Shallow corrosion. - 13 I 507 _ 0 0.05 13_ 5 6.26 Shallow corrosion. _ 14 ~ 548 0 0.05 14 8 6.27 Shallow corrosion. 15 ~ 1.6 17 18 589 629 671 71 1 0 0.04 10 2 ~ ___ 0 0.05 13 _ 6 i 0 0.03 8 I 2 ~ 0 0.05 13 6 6.24 Shallow corrosion. _ 6.27 Shallow corrosion. _ _ - - 6.24 a 6.26 Shallow corrosion. 19 752 0 0.04 10 3 6.26 Shallow corrosion. 20 792 0 0.06 15 8 6.27 Shallow corrosion. 21 833 0 0.05 14 7 6.26 Shallow corrosion. 22 874 0 0.04 1 1 4 6.26 Shallow corrosion. 23 915 0 0.07 19 1 1 6.30 Shallow corrosion. 7 24 956 0 0.05 14 '~ 6 6.26 Shallow corrosion. 25 994 0 0.05 14 7 6.28 Shallow corrosion. 26 1035 0 0.05 13 6 6.26 Shallow corrosion. ' 27 1077 0 0.06 17 8 6.27 Shallow corrosion. 28 -- 11 18 0 0.06 15 9 - -- 6.27 Shallow corrosion. ~ ^ 29 ~ 1 158 0 0.03 9 3 i ^ 6.25 Shallow pitting. 3.0 ~ 1 199 0 0.04 10 ~ 22 i 6.25 Shallow pitting. ~ ' 31 1238 0 0.04 12_ I 3 j 6.24 Shallow corrosion. 32 1278 0 0.04 11 3 ~ 6.23 Shallow pitting. 33 34 1319 1360_ 0 0.05 13 ' 0 0.05 15 8 ~ 6 ~ 6.27 Shallow corrosion. _ 6.26 Shallow corrosion. _ _ 35 36 37 1400 1440 1481 0 0.04 12 4 0 0.04 12 _ 6 0 0.06 15 8 6.25 Shallow corrosion. 6.27 Shallow corrosion. 6.28 Shallow corrosion. X38 39 1523 1563 0 0.05 13__ ; _ 7 0 0.05 14 6 6.28 Shallow corrosion. 6.26 Shallow corrosion. 40 1604 0 0.04 12 4 6.25 Shallow corrosion. 41 _ 1644 0 0.04 12 4 6.24 Shallow corrosion. 42 1684 0 0.05 13 7 6.28 Shallow corrosion. 43 1725 0 0.04 11 ~ 4 6.25 Shallow corrosion. 44 1766 0 0.05 13 ~ 6 6.28 Shallow corrosion. ~: 45 1807 0 0.05 ~ 13 4 6.24 Shallow corrosion. 46 1847 0 0.05 13 ~ 6 6.26 Shallow corrosion. 47 1888 0 0.05 13 5 6.24 Shallow corrosion. 48 1927 0 0.05 14 7 6.27 Shallow corrosion. 49 50 i 1967 2005 __0 0.05 14 _ 0 0.06 15 , 7 _ 7 6.28 Shallow corrosion. - - -_ 6.26 Shallow corrosion. image Profile (% wall) 50 100 II I Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: ELATION SHEET PWDW3-1 Prudhoe Bay BP Exploration (Alaska), Inc USA June 17, 2010 Joint ~I Jt. Depth Pen. Pen. Pen. Metal ~ Min. No. (Ft.) Upset (Ins.) Body (Ins.) % Loss ~ % LD• (Ins.) Comments 51 2046 0 0.05 14 I 8 6.26 Shallow corrosion. i 52 2088 0 I 0.05 14 I 7 6.27 Shallow corrosion. 52.1 2129 0 0.04 12 7 6.30 PUP Shallow corrosion. 52.2 2136 0 0 0 0 5.96 7" HES MBR SSSV Ni le W Blankin SLV 52.3 2141 -- 0 ~ 0.05 13 7 6.27 PUP Shallow corrosion. , 53 54 - 55 _ 56 ~ 57 2149 2190 2230 2270 2311 _ 0 0 0 _ _0 0 0.05 0.05 0.04 0.05 0.04 _ 15 13 12 13_, 10_; ~ 8 t 7 - 6 7_ ___.4_ 6.27 6.27 6.26 6.27 6.24 Shallow corrosion. Shallow corrosion. - - --- Shallow corrosion. Shallow corrosion. Shallow corrosion. 58 59 60 2350 2391 2432 0 0 - 0 __ 0.05 0.05 0.05 13 15 - 13 _;~ 7 8 ~ 8_ 6.27 6.27 6.28 Shallow corrosion. Shallow corrosion. Shallow corrosion. 61 2473__ _ 0 0.05 13 6 6.27 Shallow corrosion. 62 2512 0 0.05 14 _8 6.24 Shallow corrosion. 63 64 65 2553 2593 2635 0 0 -- 0 0.04 0.05 0.03 12 _ 13 9 4 7 2 6.26 6.24 6.23 Shallow corrosion. _ _ _ Shallow corrosion. Shallow ittin . 66 2673 0 0.04 10 4 6.22 Shallow corrosion. 67 2714 0 0.04 12 3 6.23 Shallow ittin . 68 2755 0 0.05 14 7 6.26 Shallow corrosion. 69 2796 0 0.05 14 5 6.25 Shallow corrosion. 70 2837 0 0.04 10 5 6.25 Shallow corrosion. 71 28.78 0 ' 0.06 18 9 6.25 Shallow corrosion. 72 2918 0 0.06 17 9 6.29 Shallow corrosion. 73 2960 0 0.05 14 7 6.24 Shallow corrosion. 74 2998 0 0.05 14 ~ 8 6.27 Shallow corrosion. 75 76 77 3038 3078 3118 ___ 0 0 0 0.04 0.06 0.06 10 15 16 5 9 ~ 6 6.20 6.28 6.24 Shallow corrosion. - - -- _ Shallow corrosion. _ Shallow corrosion. I 78 3158 0 0.05 14 _ 8 ~ 6.23 Shallow corrosion. 79 3199 0 0.05 14 6 6.25 Shallow corrosion. 80 81 82 83 3238 3277 331 7 3356 _ 0 0 0 0 0.06 0.04 0.04 0.06 17 ~ 11 12 15 9 4 6 10 6.24 6.26 6.27 6.29 Shallow corrosion. Shallow corrosion. Shallow corrosion. Shallow corrosion. _ _ 84 85 86 3397 3436 3477 0 0.05 0 0.05 0.06 0.04 13 1 7 12 _ 7 9 6 6.25 6.26 6.23 Shallow corrosion. Shallow corrosion. _ _ Shallo w corrosion. 87 3516 0 _ _ 0.04 1 1 4 6.20 _ _ _ ___ Shallow corrosion. Lt. De osits. 88 3557 0 0.05 13 4 6.25 Shallow corrosion. 89 3597 0 0.05 14 7 6.26 Shallow corrosion. 90 3637 0 0.05 14 I 7 6.25 Shallow corrosion. 91 3676 0 0.05 14 6 6.24 Shallow corrosion. 91.1 ~ 3716 0 0 i 0 0 6.12 PUP Lt. De osits. 91.2 ~ 3726 0 0 t 0 0 4.87 7" x 5.5" X-Over Damage Profile (% wall) 0 50 100 ~~~ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 5.5 in 1 7.0 ppf L-80 IPC Well: PWDW3-1 Body Wall: 0.304 in Field: Prudhoe Bay Upset Wall: 0.304 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 4.892 in Country: USA Survey Date: June 17, 2010 Joint No. Jt. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. LD• (Ins.) Comments .1 3728 0 0 0 0 4.87 9.625" x 5.5" TIW HB-BP T Packer .2 3733 0 0.01 2 1 4.84 PUP To of 5.5" Tubin .3 3752 0 0.01 2 1 4.87 PUP .4 3762 0 0 0 0 4.55 5.5" HES XN-Ni le __ .5 3763 0 0.01 ' 2 0 4.86 PUP .6 1 ~ 1.1 3782 3785 3813 0 0 0 0 0.02 0 0 _ 7 i 0 0 1_ 0 I _ N/A 4.87 N/A _ 9.625" x 5.5" Baker FB-1 Packer __ 5.5" x 4.5" X-Over Damage Profile (% wall) 0 50 100 ~ ~~~~~ I Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 NPC Well: PWDW3-1 Body Wall: 0.271 in Field: Prudhoe Bay Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: June 1 7, 2010 Joint No. Jt. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen Metal % Loss % Min. I.D. (Ins.) Comments 1 3816 0 0.03 10 3 3.92 To of 4.5" Tubin Tail 2 3846 0 0.01 3 1 2 3.91 2.1 3874 0 0 0 0 3.63 4.5" CAM DB-5 Ni le 3 3876 0 0.02 9 1 3.93 3.1 3902 0 0.01 3 1 3.93 PUP 3 2 3920 _ 0 0 0 _ 0 N/A 4.5" Tubing Tail I Damage Profile; (% wall) 0 50 100 i - i Penetration Body Metal Loss Body Page 1 a ~ • TREi= = McEVOY W8_LHEAD = ACTUATOR = GRAY __ KB. ELEV = 78' BF. ELEV = KOP = 0 Max Angle = 0 @ _? Datum MD= 6161' DatumTVD= PWDW3-1 saF~TY nioTES: 2130' ~ 7" HES MBR SSSV NIP W/BLANI4NG SLV, ID = 5.963" 13-3/8" CSG, 72#, N-80, D = 12.34T' N 273T Minimum ID = 3.625" @ 3878' 4-1/2" CAM DB-5 NIPPLE 7" TBG, 26#, L-80, .0383 bpf, ID = 6.276" 3719' TOPOF5-1/2"TBG 3719' 5-1/r' TBG, 17#, L-80, .0232 bpf, ID =4.892" I 380T TOPOFS-1/2" 76G-IPC 380T 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" 3819' TOP OF 4-1/r' TBG-NPC 3819' ~~ 4-1/r' TBG-NPC, 12.6#, L-80, .0152 bpf, ID = 3.958" N 3924' PfftFORATION SUMMARY REF LOG: BHCS ON 05/19/78 ANGLE AT TOP PERF: 0 @ 5540' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DAlE 3-3/8" 4 5540 - 5565 O 02/26/79 3-3/8" 4 5640 - 5650 O 02126179 3-3/8" 4 5658 - 5673 O 02/26/79 3-3/8" 4 5690 - 5705 O 02/26/79 3-3/8" 4 5725 - 5735 O 02/26/79 3-3/8" 4 5852 - 5867 O 02/26/79 3-3/8" 4 6020 - 6030 O 02/26/79 PBTD ...____6050' 9-5/8"CSG, 47#, N-80, ID = 8.681 " 8161' DOTE REV BY COMMENTS DATE REV BY COMMENTS 05/27/78 OPoGINALCOMPLE11ON 12/31/88 7" TBG COMPLETION 03/03/97 LAST WORKOVER 01/10/01 SI5-SLT CONVERTED TO CANVAS 03/01/01 SIS-LG FINAL 09/27/01 RN/TP CORRECTIONS PRUDHOEBAY INUIT WELL: PWDW3-1 PfftMT rb: 1780390 API No: 50-029-20312-00 SEC 3, T10N, R14E, 4703.24' FEL & 411.62' FNL BP Exploration (Alaska) 3719' H 7" X 5-1 /r' XO, ID = 4.865" 3720' H 9-5/8"X5-1 /r' TW HB-BP T PKR, D= 4.865" ~ ~ 3754' HS-1/2"HESXN NP, ID=4.55" 3799' 9-5/8"X5-1/2"BKRFB-1 PKR 3$07' S-1/2" MULESHOE (RUN IN BKR PKR SBR) 3819' H 5 1/2" X 41 /r' XO 3878' 4-1/2" CAM DB-5 NIP, ID= 3.625" 3924' 4-1/2" TUBING TAIL 3920' ELND TT o1/11/8s 5991' ~--~ FISH - 4-1/2" TUBING TAIL 6004' FISH - PERF GUN Page 1 of 1 Bill, Michael L (Natchiq) From: Todd Sidoti [TSidoti@slb.com] Sent: Wednesday, June 30, 2010 11:22 AM To: Bill, Michael L (Natchiq) Subject: PWDW3-1 Log Interpretation Mike, Regarding the RST Waterflow/Pressure/Temperature/Spinner log ran on PWDW3-1 on 22-Jun-2010 I can offer the following interpretation notes: • Tool response and log quality control are well within expected tolerances, quality of the log data is good. • None of the 8 waterflow measurements indicated any mn~iomcnt of {laid hPhind racing o Waterflow station #9 (log file #039) was a tool check station where the tool is moved downhole to simulate upward flow, the tool responded appropriately to this test (33.5 +/- 5.9, 38.2 +/- 2.6 ft/min flowrates) • There was an anomalous reading for the far detector is station #1 (log file #028) showing a false velocity of 142.7 ft/min which is outside the range of that detector. The lack of response on the GR detector further verifies this conclusion. • There is no indication of casing or tubing leaks on the pressure/temperature/spinner passes, each measurement indicates a static flowrate throughout the wellbore. Please let me know if you have any questions or require further clarification. Regards, Todd TODD SIDOTI I SCHLUMBERGER Sales Engineer ~ Dir (907) 273-1739 ~ Cell (907) 632-4113 I tsidoti@slb.com 6/30/2010 OPERABLE: Injector PWDW3-1 (PTD #1780390) Caliper and water flow log complete Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D8~C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Wednesday, June 23, 2010 1:25 PM To: Maunder, Thomas E (DOA) Subject: RE: OPERABLE: Injector PWDW3-1 (PTD #1780390) Caliper and water flow log complete Tom, Yes, the logs, operations report and 404 will be sent for your records. Toxin ~`~. '~ ~~_ ,.~' 4_~` From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, June 23, 2010 11:25 AM To: AK, D&C Well Integrity Coordinator; Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Operator; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer Cc: Janowski, Carrie; Bill, Michael L (Natchiq) Subject: RE: OPERABLE: Injector PWDW3-1 (PTD #1780390) Caliper and water flow log complete Torin, Thanks for the follow-up information. I presume the log results will be submitted for the record. In order to assure proper handling and review, would you submit a 404 with the operations report and the logs? Thanks in advance. Tom Maunder, PE AOGCC From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Wednesday, June 23, 2010 11:11 AM To: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Operator; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer Cc: Janowski, Carrie; AK, D&C Weli Integrity Coordinator; Bill, Michael L (Natchiq) Subject: OPERABLE: Injector PWDW3-1 (PTD #1780390) Caliper and water flow log complete All, Injector PWDW3-1 (PTD# 1780390) was reclassified as Under Evaluation on 06106 due to anomalous injection rate and pressure behavior after the recent proration. Both a caliper and water flow log were run to investigate the injection anomaly. The caliper showed a maximum tubing wall loss of 19% and no channeling behind pipe was observed with the water flow log run on 06/22. The well has been reclassified as Operable, but will be placed on the Monthly Injection Report for two months to monitor rates and pressures. Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Jerry Murphy) 6/23/2010 OPERABLE: Injector PWDW3-1 (PTD #1780390) Caliper and water flow log complete Page 2 of 2 u Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Sunday, June 06, 2010 10:57 PM U To: 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; 'Regg, James B (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Operator; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Integrity Coordinator; Bill, Michael L (Natchiq); AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer Cc: Janowski, Can-ie; Wellman, Taylor T; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: Injector PWDW3-1 (PTD #1780390) Anomalous Change in Injection Pressure versus Rate After Proration Shut In All, Injector PWDW3-1 (PTD# 2071260) has exhibited anomalous pressure behavior after being shut in during proration. The produced water injector lost approxiamtely 500 psi injection pressure, with increased injection rates indicating a change in the downhole characteristics. Current tubing/IA/OA pressures are 800/390/100 psi. Area Injection Oreder 4 E Rule 7 states "The operator shall immediately shut in the well if continued operation would be unsafe or would threaten the contamination of freshwater, or if so directed by the commision". As the well does not currently exhibit either of these conditions, the well may be left on injection to facillitate diagnostic work that is planned. The well will be reclassified as Under Evaluation. Plan forward: 1. Slickline: Drift and tag bottom of the well. Run a caliper in the tubing. 2. E-line: Injection profile and waterflow log If corrective action is required, a form 10-403 will be submitted for Commision approval. A current schematic and TIO plot are included for reference. « File: Injector PWDW3-1 06-06-2010 TIO & Injection Plot.doc» « File: PWDW3-1.pdf» Please contact us if there are any questions or concerns. Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 6/23/2010 Injector PWDW3-1 (PTD #1780390) TIO Plot We1L- PWDW31 4,000 3.000 ~ nnn Injector PWDW3-1 (PTD #1780390) Injection Plot WeN= PWDW31 auu 300 ~ 20D 100 FC1000 t Tbg f IA -~ OA OOA OOOA On 50,OOi~ - WHIP 40,000 9W 3D,D00 s MI 20,000 ~ - GI o -Other 1DDD9 ~ On 04/10/10 04/24/10 05/08/10 05/22/10 13/06!10 03113!10 03!20/10 03!27/10 04/03/10 04!10/10 04/17/10 04/24!10 05!01!10 05/08/10 05/15/10 05/22!10 05/29/10 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'l(4/,¿.j7 h{4fo 7 p, I. Supervisor '( 7 DATE: Friday, May 11,2007 FROM: Bob Noble Petroleum Inspector SlBJECT: Mechanical Integrity Tests BP EXPLORATION CA.L\SKA) TNC P\VDW3· PRUDHOE BAY UNIT PWDW3· Src: Inspector \1'ò - 031 NON-CONFIDENTIAL Reviewed Bv: " D P.I. Suprv $('_.... Comm Well Name: PRUDHOE BAY UNIT PWDW3-1 Insp Num: mitRCN07051 02 14337 Rei Insp Num: API Well Number: 50-029-20312-00-00 Permit Number: 178-039-0 Inspector Name: Bob Noble Inspection Date: 5/1 0/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~" I . I ¡--:-'---"---;--~----~------r-- I ¡--~- Well ¡PWDW3.¡ 'Type Inj. i W : TVD ¡ 3720 i IA i °i_~~o_L J630_--L._J~~L._.--L'_H_' P.T.D¡ J7803~.0 !TypeTest i SPT j Test ~sLl. 1700 i OA 0 . 0 0 i o· i Interval 4YRTST P/F.. P /--=-_l'llbingi';¿; "~-=200 I, 200 ': _o200!--:-'. '-= Notes: o I r;D 0 D<..; 1I.....t2r-<"u"eA {g''2>1- ~SL.(;'e.. I - ~ED JUN 0 6 2007 F1iday, May 11, 2007 Page I of 1 ARCO Alaska, Inc. Post Office Box ~ 00360 Anchorage, Alaska 99510-0360 January 11,1999 Ms. Wendy Mahan Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: PWDW Well Work Activity Dear Ms. Mahan: Attached is a well work history for each of the ARCO operated Produ~r Disposal Wells as you requested. If you require additional information or clar~lease contact Bill Mathews at (907) 263-4607. Sincerely, Injection Engineer Attachments RECEIVED JAN 1 P- 1999 Alaska 011 & t~as Co~ts. Comm~ss~o,, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor C~ DATE: September 19, 2001 Chairman SUBJECT: Mechanical Integrity Tests THRU: Tom MaunderiLJ ,,v~ · ~ "~Pn3_.-'~ BPX P.I. Supervisor~ ,.(.c,---_~ (~ PWDW 1-1 ~) r..?k,,-~-~ PWDW 3-1 FROM: Chuck Scheve PBU Petroleum Inspector Pmdhoe Bay NON- CONFIDENTIAL J......... ' Packer DePth' ' Pretest ~nia~ 15 Hin. 30 Min. ' ...... .I We. IPwaw 1-!lType~nj:! S I'T:V.,D.,.i '1~ I ,!'640I ~r,4o I ~: I P'T'D.-I 176-062 I.T~.~t,,,tl P' ITest'~l ~a~9, ,I c~r';I 700 I 2~ .I.. 2470 I: 2460 I P/F I::e ! I~a~s: 4-year :' wa, I ',' ,, P-T-D-! Notes: ' P.T'.D-! ' ' Notes: we.I , P.T'-D.I , ITy"e'nj-! .... !''T-V-D- I ' I Tubing l .... I ' "1' "i I'"~'~1 '..' . ITypet~,l' , IT"~I , ',1 Ca~"gl., ,, ! ! I I PF .I . IType'nJ-I IT-v-D- I .... l'Tub~l" I ' !' ' i" I'""""~1 ....... I T~tl , ,' IT~"~I ,I ,C~.'~ I, ,' ,, I , I, ~ ~ e/~ ~ ' ' I Type Inj. I iT~V.D. I '!Tul~ngII' I" I li"t"~l" ' ITy,e~l' IT~,~I ', l Ca~,~l '1 ,'1 I I P/F I, Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Intemal 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 [traVeled to BPXs Flow Stations 1 & 3 and witnessed the 4 year MIT on wells PWDW 1-1 & PWDW 3-1. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with both wells demonstrating good mechanical integrity. M.I.T.'s performed: 2 Attachments: Number of Failures: _0 Total Time during tests: 2 hour cc..: MIT rePort form 5/12/00 L.G. MIT PBU PWDW 1-1 PWDW 3-1 9-19-01 CS.xls 10/1/01 PWDW3-1 Current plans are to drift and tag the well. Dat.___ge O2/26179 01/12/88 04/15/88 O9/05/88 01/02/89 02/20/89 02/27/89 O3/04/89 09/15/89 07/06/91 11/15/94 12/05/96 12/11/96 12/14/96 01/16/97 O2/11/97 O3/03/97 Well Event Shot 100' of initial perforations (5540'-5565', 5640'-5650', 5658'-5673', 5690'-5705', 5725'-5735', 5852'-5867', 6020'-6030'). SBHPS- 2496 psig @ 5625'. Ran a spinner survey. Indicated a 310' channel up to 5230'MD and all injection going to the to perforations. SBHPS & TEMP - 2448 psi @ 5425'MD. Replaced existing 4-1/2" tubing and 7" circulating string with 7" tubing and tree. Attempted a TEMP. Sat down on tubing tail @ 5363'MD. Washed fish (tubing tail) to 5918'CTM. TEMP - Indicated channel to 5200'MD. TEMP- Channel unchanged, up to 5220'MD. Well passed pre-state-witnessed MIT. SBHPS- 2704 psi @ 5500'. Well failed MBA. Well passed tubing x inner annulus casing mechanical integrity test to 3000 psi. Ran a leak detection log. Indicated tubing hanger leak. Annular communication test indicated leak at bottom of pup joint below hanger. Well passed outer annulus MIT (MITOA). Well passed MITOA to 2000 psi. Tubing changeout complete. Still using same sizes. Passed state- witnessed MITIA to 3550 psi and MIT-tubing to 3700 psi. RECEIVED JAN '12_ ~999 AI~I~ 011 & Gas 00ns, Anchorage ,"'-'~ STATE OF ALASKA ~-"~ ALASKA ulL AND GAS CONSERVATION CO~vlMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska Inc. [] Operation Shutdown [] Stimulate i~ Plugging i--1 Perforate ~-1 Pull Tubing I--I Alter Casing [] Repair Well I--] Other Type of well: 6. [] Development 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. 4. Location of well at surface 413' SNL, 576' EWL, SEC. 3, T10N, R14E, UM At top of productive interval 413' SNL, 576' EWL, SEC. 3, T10N, R14E, UM At effective depth 413' SNL, 576' EWL, SEC. 3, T10N, R14E, UM At total depth 413' SNL, 576' EWL, SEC. 3, T10N, R14E, UM Exploratory Stratigraphic [~Service Datum Elevation (DF or KB) RKB = 78' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number PWDW 03-01 9. Permit Number / Approval No. 78-39 10. APl Number 50-029-20312 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical ' Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 6150 feet Plugs(measured) 6150 feet 6050 feet Junk (measured) 6050 feet Length Size Cemented M D TVD 80' 20" 370 sx Arctic Set 123' 123' 2737' 13-3/8" 5040 sx PF II 2737' 2737' 6102' 9-5/8" 500 sx Class 'G', 510 sx PF 'C' 6131' 6131' Perforation depth: measured true vertical 5540'-5565', 5640'-5650', 5658'-5673', 5690'-5705', 5725'-5735', 5852'-5867', 6020'-6030' 5540'-5565', 5640'-5650', 5658'-5673', 5690'-5705', 5725'-5735', 5852'-5867, 6020'-6030' Tubing (size, grade, and measured depth) 7", 26#, L-80 to 3720'; 5-1/2", 17#, L-80 3720' to 3807'; 5-1/2", 17#, L-80, 3799' - 3819'; 4-1/2", 12.6#, L-80 from 3819' - 3924' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) TIW HB-BP-Tp packer at 3720'; 7" HES 'MBR' SVLN at 2130' .... ORIGINAL ,..,i;, Treatment description including volumes used and final pressure ' ~ch'orage 14. Prior to well operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation: 5. Attachments 116. Status of well classifications as: ~ ~Co.,pie~s of L.ogs. a...nd,, S..urvey..s run'1 [--I Oil [] Gas I--I Suspended ~.u uauy Nepor~ eT weu uperauons ~ I 7. I h'~reby certify that t~e'~fo~going is~,~e and correct to the best of my knowledge Signed . Dan Stoltz ~ ~-~-~ Title Senior Drilling Engineer Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Service Produced Water Disposal Terrie Hubble, 564-4628 Submit In Duplicate ~' Facility Date/Time 23 Feb 97 24 Feb 97 25 Feb 97 26 Feb 97 27 Feb 97 28 Feb 97 01 Mar 97 Progress Report EX PW-3-1 Well PW-3-1 Rig Nabors 2ES Page 1 Date 16 June 97 06:00-16:00 16:00-17:00 17:00-19:00 19:00-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-06:30 06:30-17:00 17:00-20:00 20:00-02:00 02:00-06:00 06:00-07:00 07:00-08:00 08:00-12:30 12:30-16:00 16:00-17:00 17:00-18:00 18:00-20:30 20:30-23:30 23:30-01:00 01:00-01:30 01:30-04:30 04:30-06:00 06:00-07:30 07:30-08:00 08:00-09:30 09:30-12:00 12:00-17:00 17:00-18:00 18:00-20:30 20:30-22:00 22:00-06:00 06:00-08:00 08:00-15:30 15:30-20:30 20:30-21:00 21:00-00:30 00:30-03:00 03:00-06:00 06:00-08:00 08:00-08:30 08:30-12:30 12:30-13:30 13:30-18:30 18:30-19:30 19:30-21:00 21:00-22:30 22:30-01:00 01:00-02:00 02:00-03:30 03:30-05:30 05:30-06:00 06:00-07:30 Duration 10hr lhr 2hr 5hr 1/2 hr 1-1/2 hr 4hr 1/2 hr 10-1/2 hr 3hr 6hr 4hr lhr lhr 4-1/2 hr 3-1/2 hr lhr lhr 2-1/2 hr 3hr 1-1/2 hr 1/2 hr 3hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 5hr lhr 2-1/2 hr 1-1/2 hr 8hr 2hr 7-1/2 hr 5hr 1/2 hr 3-1/2 hr 2-1/2 hr 3hr 2hr 1/2 hr 4hr lhr 5hr lhr 1-1/2 hr 1-1/2 hr 2-1/2 hr lhr 1-1/2 hr 2hr 1/2hr 1-1/2 hr Activity Rig moved 100.00 % Fill pits with Brine Removed Hanger plug Circulated at 3742.00 ft Held safety meeting Circulated at 4500.00 ft Circulated at 4961.00 ft Circulated at 3742.00 ft Circulated at 4961.00 ft Circulated at 3742.00 ft Bullhead well Bleed down well Bleed down well Serviced Block line Monitor wellbore pressures Bullhead well Flow check Installed Accessories Removed Xmas tree Installed BOP stack Removed Accessories Installed BOP test plug assembly Tested BOP stack Removed BOP test plug assembly Removed BOP test plug assembly Tested Wellhead connector Removed BOP test plug assembly Installed Drillpipe retrieval string Pulled Tubing on retrieval string to 3742.00 ft Circulated at 1500.00 ft Pulled Tubing on retrieval string to 1500.00 ft Worked on BOP - Top ram Bullhead well Bullhead well Bleed down well Bullhead well Tested Top ram Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Rigged up sub-surface equipment - Cementing packer Ran Drillpipe to 3735.00 ft (5in OD) Tested Casing - Via annulus Pulled out of hole to 0.00 ft Made up BHA no. 2 Bullhead well Made up BHA no. 2 R.I.H. to 3734.00 fi Milled Tubing at 3734.00 ft Pulled out of hole to 344.00 fi Pulled BHA Made up BHA no. 3 R.I.H. to 3734.00 fi Milled Tubing at 3734.00 ft Pulled out of hole to 320.00 ft .0il & Gas Cons. Anchorage Facility EX PW-3-1 Progress Report Well PW-3-1 Rig Nabors 2ES Page Date 2 16 June 97 Date/Time 02 Mar 97 03 Mar 97 07:30-08:30 08:30-09:30 09:30-10:30 10:30-11:00 11:00-13:00 13:00-14:30 14:30-15:30 15:30-16:30 16:30-20:00 20:00-20:30 20:30-21:00 21:00-23:00 23:00-00:30 00:30-01:00 01:00-01:30 01:30-02:00 02:00-06:00 06:00-15:00 15:00-17:00 17:00-20:00 20:00-22:30 22:30-23:30 23:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 Duration lhr lhr lhr 1/2 hr 2hr 1-1/2 hr lhr lhr 3-1/2 hr 1/2 hr 1/2 hr 2hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 4hr 9hr 2hr 3hr 2-1/2 hr lhr 4hr 1/2 hr lhr lhr Activity Pulled BHA Made up BHA no. 4 R.I.H. to 3738.00 fi Functioned downhole tools at 3738.00 ft Pulled out of hole to 312.00 ft Laid down fish Made up BHA no. 5 R.I.H. to 3794.00 fi Milled Downhole equipment at 3813.00 ft Laid down 600.00 ft of 5in OD drill pipe Serviced Block line Laid down 3000.00 ft of 5in OD drill pipe Pulled BHA Held safety meeting Removed Wear bushing Rigged up Tubing handling equipment Ran Tubing to 2100.00 ft (7in OD) , Ran Tubing to 3807.00 ft (7in OD) Installed Tubing hanger Rigged down BOP stack Rigged up Wellhead primary components Retrieved Hanger plug Circulated at 3720.00 ft Set packer at 3720.00 ft with 2400.0 psi Tested Tubing _.ox Rigged down Drillfloor / Derrick ~"-~ Anchorage ' ' STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION COM~vi'iSSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 413' SNL, 576' EWL, SEC. 3, T10N, R14E, UM At top of productive interval 413' SNL, 576' EWL, SEC. 3, T10N, R14E, UM At effective depth 413' SNL, 576' EWL, SEC. 3, T10N, R14E, UM At total depth 413' SNL, 576' EWL, SEC. 3, T10N, R14E, UM J5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RKB = 78' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number PWDW 03-01 9. Permit Number 78-39 10. APl Number 50-029-20312 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 6150 feet true vertical 6150 feet Effective depth: measured 6050 feet true vertical 6050 feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Size Cemented MD TVD 80' 20" 370 sx Arctic Set 123' 123' 2737' 13-3/8" 5040 sx PF II 2737' 2737' 6102' 9-5/8" 500 sx Class 'G', 51RsEI~ ~'1VE D6131' 6131' FEB 1 1 1997' ORIGINAL Commission 'Alaska 0il & Gas Cons. Perforation depth: measured 5540' 5565', 5640' 5650', 5658'"--5-673', - - 5~,~101~§5', 5725'- 5735', 5852'- 5867', 6020' -6030' true vertical 5540' - 5565', 5640' - 5650', 5658'- 5673', 5690' - 5705', 5725' - 5735', 5852' - 5867, 6020'- 6030' Tubing (size, grade, and measured depth) 7", 26#, L-80 to 3790'; 5-1/2", 17#, L-80, 3790' - 3819'; 4-1/2", 12.6#, L-80 from 3819' - 3924' Packers and SSSV (type and measured depth) 9-5/8" x 5-1/2" Baker FB-1 packer at 3799'; 7" Camco BaI-O SSSV at 2192' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation February 13, 1997 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Produced Water Disposal Contact Engineer Name/Number: Winton Aubert, 564-4825 Prepared By Name/Number: 17. I hereby certify that th.e'fS~e.~oing is t.rue a)~t correct to the best of my knowledge Signed /~~~~_~/ DanStoltz Title Senior Drilling Engineer Commission Use Only Terrie Hubble, 564-4628 Conditions of Approval: Notify Commission so representative may witness l Approval No.',.~ Plug integrity_ BOP Test ,,'" Location clearance __ Mechanical Integrity Test --0rtginal ,.,8_ubsequent form required 10- ~gnea ~ w. oh.s o. Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Approved CoPY , Rett~ec~ Submitlln TriPlicate ~ Objective PWDW 3-1 RWO Summary PWDW 3-1 is one of four EOA Cretaceous disposal wells having no alternative dis- posal options. Excess water not injected into the Cretaceous must be over-injected into the Sadlerochit, as excess water can not economically be shipped outside the Flow Station 3 area. Long term over-injection is not a viable option, and reducing water production to eliminate excess water would result in a direct oil loss of 5000 BOPD. A 2.6 gpm leak was recently discovered in the top five feet of tubing, and outer annulus pressure indicates possible 9-5/8" casing problems. Injection is continuing under a state regulation waiver; on March 16, 1997 the well must be shut in or a waiver extension requested. A rig workover to restore tubing and casing integrity will allow unimpeded produced water injection. Timing This workover is scheduled to begin about Feb. 20, 1997. Pre-Rig Procedure · . . 4. Drilling Rig Procedure 1. MIRU drilling rig. ND tree, NU and test BOPE. 2. Pull 5 1/2"x 7" tubing from cut above packer. 3. Mill over and remove packer and tubing tail. . , . , Rig up electric line unit with chemical cutter for 5-1/2" tubing. RIH and cut 5-1/2" tubing just above packer @ 3198' MD. Test 9-5/8" packoff and service LDS. Release pressure on tubing and IA. Circu- late tubing and IA with clean SW through cut. Freeze protect with diesel to ___2,000' M D. Install BPV. Remove wellhouse and flowlines, level pad, dig out cellar. RIH with RTTS packer to 4000' and test 9-5/8" casing to localize leaks, if any. Depending on depth of leak, install scab liner or casing patch in 9-5/8" casing to repair leak. Run new 7", L-80 tubing and packer assembly with 'XN' profile. Freeze protect well, set packer, set BPV, ND BOPE, NU and test tree, RDMO. ;rationsWDrilling Engineer ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 December 17, 1996 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: PWDW 3-1 Variance for continued Injection - until repair can be effected. Dear Mr. Wondzell: Attached is a State sundry application form (10-403) for well PWDW 3-1. This application requests approval for continued injection of produced water until an effective repair can be implemented. At this time we believe this will require a Rig Workover and a complete tubing replacement. However, other options are under review. Our expectation is to begin repair operations in less than three months, but we are requesting this length of variance to provide sufficient time to review several cost effective options for repair. Attached are supporting documents which outline the condition of the well and support the justification for this variance. If you require any additional information or clarification, please feel tree to contact either Dave Smith or Richard Ortiz at (907) 659-5102. Very Truly Yours, R. M. Lemon Well Services Superintendent DDS/RAO Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: ~ Suspend Operation shutdown__ Re-enter suspended weil~ Alter casing. Repair Well ;X; Plugging_.. Time extension __ SlJmulate~ Change approved program m Pull Tubing Variance X Perforate~ Olher 2. Name of Operator ARCO Alaska Inc. 3. Address PO Box 100360 Anchorage, Alaska 99510-0360 4. Location of well at surface 413' FNL, 576' FWL, Sec. 3, T1 ON, R14E, UM At top of productive interval 413' FNL, 576' FWL, Sec. 3, T10N, R14E, UM At effective depth 413' FNL, 576' FWL, Sec. 3, T10N, R14E, UM At total depth 413' FNL, 576' FWL, Sec. 3, T10N, R14E, UM ii , 12. Present well condition summary Total depth: measured 6150' MD true vertical 6150' TVD 5. Type of Well: Development Exploratory__ Stratigraphic__ Service feet Plugs (measured) feet , 7. 8. 9. 10. 11. 'o None Datum elevation (DF or KB) 76' RKB feet Unit or Property name Prudhoe Bay Unit Well Number PWDW 3-1 Permit number 78-39 APl number 50-029-20312 Field/Pool Prudhoe Bay Oil Pool Effective Depth: measured 6050' MD feet Junk (measured) true vertical 6050' TVD feet Fish @ 5,991' 4 1/2" Tubing Tail Fish @ 6,004' Perf Gun Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" Surface 2737' 13-3/8" Production 6102' 9-5/8" 370 sx Arcticset 123'MD 123' TVD 5040 sx Permafrost II 2737' MD 2737° TVD 500 sx Class G & 6131' MD 6131' 'I'VD 510 sx Permafrost C Perforation depth: measured 5540'- 5565', 5640' -5650', 5725' - 5735', 5852'-5876', 5658'-5673', 5690'-5705' 6O2O'-6O3O' true vertical 5540'-5565', 5640'-5650', 5725'-5735', 5852'-5876', 5658' -5673 6020'-6030! 5690'-5705' Tubing (size, grade, and measured depth) 7", 26#, L-80, (0 to 3,790') / 5 1/2", 17#, L-80, (3790' to 3,819') / 4 1/2", 12.6#, L-80, (3,819' to TT at 3,924') Packers and SSSV (type and measured depth) Baker FB-1 pkr @ 3,799°, Camco 7" BaI-O 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation ~ 16.Status Of well classification as: ASAP for Injection - Repair, no later than 3/16/97. I 15. If proposal was verbally approved Oil Gas Suspended Name of approver Blair Wondzell Date approved 12/16/96 I Service , Yv~ 7. I hereby certify that the foregoing is true and correct to the best of my knoWledge Signed ~~ /t.~7~-~--~.~ Title ~H~juc~_ ~--~,,,.~o~,o~.~ C~c[~z_ Date i FOR COMMISSION USE ONLY Conditions of approval:Plug integrityN°tify commission so commission representative may witneSSBoP/~Test__ Location clea~,nce_..~ I Appr°val N°"~ ~-~ L// Mechanical Integrity Test U~Subsequent form required 10-/~~ ~.~ ~f Oc~Z~ ,z~~ ' [Approved by order of the Commission David W ,J'°hnston ~ Commissioner Date//~ . Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PWDW-3-1 Request for Operational Variance The following is an outlined review of the critical information needed to clarify the current condition of PWDW-3-1. 1. A liquid leak rate of -2.8 GPM with a differential pressure of 2650 psi. was established on 12/6/96. 2. Extensive testing of the Wellhead, SSSV, balance and control line indicated this was not the problem area as originally suspected. 3. On 12/11/96, an IBP was placed in the seal bore across from the packer and the Tbg and IA were tested to 3000 psi, and PASSED. This Combination test lost only 90 psi in 30 min. (ARCO Test form attached.) 4. On 12/14/96, a LDL (Leak Detection Log) was run which clearly indicates that the leak point is in the pup jnt just below the hanger. (Copy of Log section with indications attached.) In order to handle the excess water production that is necessary to maintain oil rate, water was temporarily diverted to Sadlerochit injection wells thus causing temporary over injection in those patterns. Extended over injection would probably result in displacement of oil outside the patterns that may not be recoverable later. For this reason we requested and received verbal approval to resume injection, pending review of this sundry. We are now requesting a Variance to continue Produced Water Injection in this well until 3/16/97. It is our belief that this will provide us sufficient time to implement a cost effective repair, without significant risk. ANNULAR COMMUNICATION TESTING MECHANICAL INTEGRrFY TEST DATE: 12/11/96 WELL: PWDW 3-1 TYPE: INITIAL PRESSURE DATA MIT: PASS , ,, Well Status: INJ TYPE: TBG.' 300 IA: 320 OA'. CONTROL: 3400 BALANCE: 100 PRE-TEST PREPARATIONS BLED IA OA FROM TYPE OF FLUID AND VOLUME BLED: HRS PSI TO PSI TBG & IA TEST PRESSURES TIME TBG IA OA COMMENTS MIN FL @ Surface 16:15 300 320 0 START PUMPING TIME ' 17:00 1980 1980 0 START TEST , , 17:15 1930 1930 0 PASS ,, 17:40 3020 3020 0 START TEST ,, 17:55 2970 2970 0 18:10 2930 2930 0 PASS , START TEST ,,, , · , TOTAL VOLUME PUMPED: 7 BBLs of METHANOL ,, FINAL PRESSURES TBG: 65o IA: 650 OA: 0 OBSERVATIONS / COMMENTS FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! i X ' I - FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION - FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING: ~ - NOTIFY DRILL SITE OPERATOR OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: KP/ME WTEP[.5 lJ_DEGF~ WTEP[3 I(DEGF) CCLC[3](V ) ,. 200,00 1.0000 0.0 DOWN PASS GRADIO v'VFDE[5 ](G/C.3) . BASE, LINE PASS WTEP[3 ](DEGF) 30.000 _ _ _DQ.W~ ~TEMP WTEP[5 ].J_DE_GI:) 30.000 I 2.0000 6ql, O ,0~), I ii CP 42.2 FILE 11 14-DEC- 1996 16:44 5 / 100' BOP'S LEAK 100 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9134 Company: 12/5/94 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 3-7 _ _ PERF RECORD (11-20-94) I 1 D.S. 3-10 ~ G-oz-/ INJEC PROFILE (11-17-94) I 1 D.S. 3-32A (2/~ G/-7/~- d ,~-- ~7/ PROD PROFILE (11-14-94) I 1 D.S. 4-19 ~ ~'-~, -O '~-I' DUAL BURST TDT-P (11-21-94) I 1 D.S. 7-19 ~'2-,-~-j7 CNL ((11-13-94) I 1 D.S. 9-21 /'/ ~- ~ - ] ~. O LEAK DETECTION (11-11-94) I 1 D.S. 9-21 4~ ~ '-- / 4 c) TUBG PATCH RECORD (11-22-94) I 1 D.S. 9-47 .~ 4),-' ]</~ PROD PROFILE (11-15-94) I 1 D.S. 9-49 (~,, G _"P--~- [,~ ~ PROD PROFILE (11-14-94) I 1 D.S. 11-31~ ~.---/'2_7 R.O.P.E. PERF RECORD (11-14-94) I 1 D.S. 11-32 '~2~ "~'G/'.-{,~J R.O.P.E. PERF RECORD (11-15-94) I 1 D.S. 15-41 / "~P.~--- ~Y? GR-CCL (11-11-94) I 1 D.S. 16-21 ~-.,¥'--~/"/_:. LEAK DETECTION (11-22-94) I 1 D.S. 17-7 ,P-{---d&~ LEAK DETECTION (11-16-94) '1 1 D.S. 17-13 /~ ~--/~ ~ LEAK DETECTION (11-16-94) I I SIGNED: ~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA r'---"--LkW~ ALASKA OIL AND GAS CONSERVATION COMMISSION - COMPLETION OR RECOMPLETION REPORT AND LOCI 1. Status of Well Classification of Service Well Prudhoe Water Disposal Well OIL ~ GAS ~ SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska. Inc. 78-39 3. Address ' 8. APl Number p n R,,v lnn~n ~n,-h ..... ~ qq~ln-n~n 50- 029-20312 4. Loc~t](:;r~ o~-~11 'a~ ~Jr~;~e .......... =-~ 9, Unit or Lease Name 413' FNL, 576' FWL, Sec. 3, T10N, R14E, UR Prudh°e Bay Unit .. At Top Producing Interval 10. Well Number 413' FNL, 576' FWL~ Sec. 3, T10N, R14E, UM PWDW 3-1 At Total Depth 11. Field and Pool 413' FNL, 576' FWL, Sec. 3, T10N, R14E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 78'I ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 05/13/78 05/19/78 05/27/78*I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 6150'MD/TVD 6050'MD/TVD YES [] NO []I 2192' feet MDI 1900' (approx) 22. Type Electric or Other Logs Run D IL/SP/BHCS/GR, FDC/GR/Cal, 4-Arm Cal, GR/CBL/VDL/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" 94.0# H'40 ~,,~f 17~' ~3" ~70 _~× ~rct~c_~et 13-3/8" 72.0# N-80 .~,,~f 77:~7' 17-1/?,, 50~_0 s× PF !! 9-5/8" 47-0# ~l-RO/.c;J-cJr~ ~,,r'f ¢,13,1, !2-!/4" 500 Sx C!-~ss C & 5!0 :.x .~'FC 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) Perforated w/4 spf 7"/4-1/2" 3924' 3799' , ,I 5540 ' -5565 ' MD/TVD 5640'-5650'MD/TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5658'-5673'MD/TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5690 ' -5705 ' MD/TVD N/A 5725' -5735 'MD/TVD 5852' -5867 'MD/TVD 6020 ' - 6030 ' MD/TVD 27. N/A pRODUCTION TEST Date First Production ! Method of Operation (Flowing, gas lift, etc.) i Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATEDi~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl {tort) Press. 24-HOUR RATE =Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneP ECEIV£D ~aska .Oil & * NOTE: Perforated well 2/26/79. Workover performed 1/2/89. CO[['"'~O'~~t~~'~'' Form 10-407 Submit in duplicate Rev. 7-1-80 WC5/077 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERs FORMATION TESTS " · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , . · Top Cretaceous 5540 ' 5540' N/A Base Cretaceous 6030' 6030' 31. LIST OF ATTACHMENTS None 32. i hereby certify that the foregoing is true and correct to the best of my knowledge Signed -~. ~ Title Regional Dri 11 ing En~iD~t~ ~/~ 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 (D.F, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 10~07WC5/077 ADDENDUM WELL: 12/24/88 P~W3-1 RU Camco S/L. Tst lubr to 2000 psi. RIH w/3.625" OD GR to 3920' SLM thru "D" nipple @ 3885' SLM, POOH. RIH w/blanking plug; plug stopped and set in 3.687" ID SSlv @ 3765' SLM, POOH. RIH w/retrv'g tl &retrv DB lock and plug. RU Gearhart electric line, tst lubr to 3000 psi. RIH w/3" OD Magna-range tbg BP and set in 4½" tbg tailpipe @ 3928' ELM. Pressure 4½" tbg to 3000 psi & tst BP. Bleed pressure to 9 psi. RI 3-1/8" perf gun, perf 4½" tbg @ 3779' ELM in middle of first full jt above pkr. Pressure tbg to 500 psi; saw slight pressure response on 7" and 9-5/8". Pressure 9-5/8" to 1000 psi; saw tbg press incr to 1350 psi. Bleed 9-5/8" to 9 psi; tbg pressure dropped to 350 psi. SI well. RD Gearhart. D r il~l--i~g Supervf~/ '-- ARCO ALASKA, INC. P,O. BOX J00360 ANCHORAGE, ALASKA 995J0 DATE- J~-6-89 REFERENCE: ARCO CASED HOLE FINALS t-t7 9-t 7-89 PRODUCTION PROFILE RUN J, 2-4 9-t6-89 TEMF'/FLUID DENSITY RUN 1, S-5 9-i3-89 F'RODUCTION PROFILE RUN i, 4-3 9-i9-89 DEPTH DETERNINATION RUN J, 5-t 0 9-t6-89 GR/CCL RUN t , 6-6 9-26-89 COLLAR RUN i , 6-ii 9-24-89 PERF RECORD RUN t, 7-8 9-2-89 EPILOG RUN t , t~-28 t(~-t-89 PRODUCTION F'ACKER RUN i, ~4-28 9-~7-89 STATIC TEMP SURVEY RUN ~, ~4-~5t 9-t4-89 PRODUCTION F'ROFILE , RUN t, t5-~5 9-iS-89 TEMP SURVEY '- RUN ~ ~ tS-S 9-t8-89 LEAK DETECTION SURVEY RUN t, F'WDWS-~ 9-~5-89 TEMP/FM SURVEY RUN ~, PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA RECEIVED BY HAVE A NICE SALLY HOFFEC AT0-~529 -- ocT1 K~ ~ · _ Oil l Gas Cons. commm u, TRANS~ 8~ ~- Anchorage 5' 5' 5' 5' 5' 5' 5" 2'&5' 5' 5' 5' 2'&5' CAMCO CAMCO CAMCO YCH CAMCO ATI_A~ SCH A'TLA~ ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES ." PHILLIPS CHEVRON F'.B WELL FILES D & M R & D EXTENSION EXPLORATION ~' BPX EXXON ~' STATE OF ALASKA MARATHON '~ TEXACO MOBIL * THE CORRECTED AF'I~ FOR 5-t0 IS 50-029-20263. ARCO ALASKA, INC· ,~-. F'.O· BOX t00360 ANCHORAGE, ALASKA 995t0 DATE~ 3-2?-89 REFERENCE: ARCO CASED HOLE FINALS 2-7 3-2-89 3- t ~ 3-3-89 5-~ 0 3-~ 7-89 5-~ '? 3-4-89 9- ~ ~ 3-5-89 ~ ~-~ ~ 3-~ ?-89 ~ ~-~ 3 3-6-89 ~ ~ -~ 6 ~-~ 4-89 ~ 2-29 ~-~ 6-89 PWDW~-~ ~-3-89 PWDW3-~ 3-4-89 F'ITS INJECTION PROFILE PITS PRODUCTION PROFILE TEMP SURVEY TEMP SURVEY PRODUCTION PROFILE TEMP PITS TEMP SURVEY STATIC TEMP SURVEY PLEASE SIGN AND RETURN THE ATTACHED COPY RUN t, RUN t, RUN ~, 5" RUN t, 5" RUN ~, 2"&5' RUN ~, RUN t, 5' RUN ~, RUNS t-6, RUN t, 2" RUN ~, 2" AS RECEIPT OF DATA. CAMCO CAMCO OTIS CAMCO CAMCO OTIS CAMCO OTIS OTIS CAMCO CAMCO RECEIVE~ BY HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 APF'ROVED _~___ DISTRIBUTION CENTRAL FILES ~ PHILLIF'$ CHEVRON PB WELL FILES D&M R&D EXTENSION EXPLORATION ~ ~ SAF'C EXXON ~ ~ STATE OF ALASKA MARATHON ~ TEXACO MOBIL ** THE CORRECTED API~ FOR THIS LOG IS 50-029-20263. ARCO ': P ~ 0 ,. BOX t '.'.::' (:) S 6 :.:;' ANCHORAGE., AI..AS'K A 995i DATE ' t -.3t -89 REFERENt'.;E' ARCO CAS'ED HOLE FINALS' i -i S i -6-89 * i '-i 6 i -4-89 ""-":' i - i '~ -89 3-i6' t '2-2.S-88 4-i2 i-i"'_;.-.89 4-i..,~ t -i ..,.':"- 8~, 4-i 5 i -i 9-89 5-6 t-!9-89 ** 5-9 i -2i -89 7-Se t -6'-89 t i --i 'i -i `3-89 t_,-':'--i 4 I -9-89 t 6-2t t --t 0-89 PWDW2-t i-iS-89 PWDW2-'i i'-t9--89 PWDW"Z- t t PRODUCTION PROFILE COLLAR/f"ERF PF:.:ODUCTI ON PROFILE COLLAR/F'ERF F'RODUCTION F'ROFILE D IFFEREN'i' I AL 'f'EMP TEMP COLLAR/PERF COL. LAR/PERF LEAK DETECTION DIFFERENTIAL 'f'EMP PRODUCTION PROFILE F'RODUCTION PROFILE FLOWMETER LEAK DETECTION TEMF' COI_LAF:/r"F R F-- ':,S'E T PLUG RUN RUN I, 5' RUN ~ , .5" R(JN ~'.; RUN i ,.,"~" RUN i RUN i ,~"~'" RUN RUN i ..5 RUN i, ,;.'"'&.5' RUN t, 2" RUN RUN RUN RUN t, 5" RUN t, F:'LFASE SIGN AND RETURN THE AT fF.~..,HED COPY F~E.L;E:.IP ~.~ T 01:'" DATA. iS A r'i C 0 H L '? C A M C: t] G E A R C A r~ C O CAMCO CAMCO ~.~ I I_r.~. CA¢iCO C A M C 0 C A M C 0 CAMCO CAMCO GEAR RECEIVED BY._ HAVE: A NICE DAY! SALLY i'-tOFFECK ER ATO-i 529 TRAN~ ~ 8 9,.':) ~ APPROVFZD k;~ Oil & Gas Cons. Commission Anchorage DISTRIBUTION CENTRAL FILES CHEVRON DAM 'EXTENSION EXPLORATION EXXON MARATHON MOBIL '"- RHILLIF'$ F'B WEI_L_ F'IL.E,., R & D ~ ~'APC ~ ~'T'A'¥E OF' ALASKA ~- TEXACO * HL:7 (I-IALI..IBLIRTON LOGGING SERVICE~) IZ:: THE NEW NAME: FOR GIEARHAF;,'T ** THE API $ ON THIS LOG I$ INCORRE~F; IT ~'HOULD BIZ ~e-e",'::;.-",,:',",'~4 STATE OF ALASKA AL~,,-.,~, OIL AND GAS CONSERVATION COMMI$,.,,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging Pull tubing __ Alter casing __ Repair well __ Perforate __ Pull tubing ~ Other ¢-' We rkover 2. Name of Operator ARCO Alaska~ Inc. 3. Address P,O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 413' FNL, 576' FWL, Sec. 3, TION, R14E, 'UM At top of productive interval 413' FNL, 576' FWL, Sec. 3, TION, R14E, UM At effective depth 413' FNL, 576' FWL, Sec. 3, TION, R14E, UM At total depth 413' FNL, 576' FWL, Sec. 3, TION, RI4E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 78' 7. Unit or Property name Prudhoe Bay Unit 8. Well number PWDW 3-1 9. Permit number/approval number 78-39/8-_3?_2 10. APl number 50-- 029-20312 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 6150 'MD feet Plugs (measured) 6150 'TVD feet None Effective depth: measured 6050 ' MD feet Junk (measured) true vertical 6050 'TVD feet ish.~ 6004 ' perTora~;1 ng gun) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 20" 370 sx Arcticset 2737' 13-3/8" 5040 sx PF I I '6102' 9-5/8" 500 sx Class G & 510 sx PFC 2368 ' ' 7" N/A Measured depth 123'MD 2737 'MD 6131 'MD 2394'MD measured 5540'-5565' 5640'-5650', 5658'-5673', 5690'-5705' 5725'-5735', 5852'-5867', 6020'-6030' truevertica~540'-5565', 5640'-5650', 5658'-5673', 5690'-5705' 5725'-5735' 5852'-5867' 6020'-6030' Tubing(size, grade, and measureddepth) 7"/4-1/2", L-80, tbg w/tail ~ 3924' PackersandSSSV(typeand measureddept~ Baker 'FB-I' per ~ 3799' & Camco 'Bal-0' SSSV @ 2192' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including vol.umes used and final pressure True vertical depth 123 'TVD 2737 'TVD 6131 ' TVD 2394 'TVD RECEIVED 14. N/A RePresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run u Daily Report of Well Operations v" 17. I hereby certify that the foregoing is true and correct to the best of mY knowledge. Signed Title Regional Dri 11 ing Engineer ~ *Form 10-404 Rev 06/15/88 Workover Wel 1 Hi story (Dani) SW04/006 Serv~c~Oduced Water Disposal / SUBMIT IN/DUPLIC^IE ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "initial Re, ri" on the first Wednesday after a well is spudded or workover operations ara sta~led. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. psrisl~ or borough ! ARCO A~ASKA INC. .. I NORTR SLOPE Field JLease or Unit PRUDI-]O~- BAY' I AD~.: 28312 Auth. or W.O. no. ~Titl~ As~ 432. I WO~KOVER ?wow ~,;~ IWell no. API: 50-029T20312 Operator ARCO Spudded or W.O. begun [Date IHour ACCEPT . ~2/29/88 0430 HRS Date and depth Complete record for each day reported as of 8:00 a.m. 12/30/88 ( TD: 6150 PB: 6050 SUPV:CD SUPV:CD 12/31/88 ( TD: 6150 PB: 6050 SUPV:CD 01/01/89 ( 6150 6050 SUPV:CD IARCO W.I. · 21,, oo0o IPrior status if a W.O. NORDIC i LD 4.5" TBG. MW: 8.6 SSEAWATER ACCEPT RIG @ 0430 }iRS, 12/29/88. CHECK WELL PRESSURE, CIRC WELL W/ SEAWATER, BLEED TBG, CIRC WELL, SET BPV, ND 4.5" McEVOY TREE, NU 13-5/8" BOPE, TEST SAME, PULL BPV, MU LD JT, ENGAGE HGR, PU 60,000) , LD HGR, PREP TO PULL 4.5" TBG. DAILY:S59,138 CUM:$165,428 ETD:S165,428 EFC:$482,000 CHANGE 9 5/8" PACKOFF. MW: 8.5 SSEAWATER SERVICE RIG, POOH LD 4.5" TBG, CHANGE TO 7" RAMS AND TEST, COULD NOT SCREW INTO 7" TBG HANGER, SPEAR 7" TBG HANGER, POOH LD 7" TBG, ATTEMPT TO TEST 9 5/8" CSG, WING VALVE LEAKING, SET RTTS AND STORM VALVE AT 40', ND BOPE, V REMOVE ?" SPOOL, CHANGE OUT TOP SPOOL WING VALVE, CHANGE SEAL ON 9-5/8" PACKOFF. DAILY:S29,016 CUM=$194,444 ETD=S194,444 EFC=$482,000 LD DRILL COLLARS. MW: 8.5 SSEAWATER REDRESS TBG SPOOL, NO TBG SPOOL AND BOPE, PACKOFF WILL NOT TEST, ND BOPE AND TBG SPOOL, R~PLACE TBG SPOOL, NU ATTEMPT TEST PACKOFF, WILL NOT TEST, ND SPOOL , INSTALL PACKOFF IN SPOOL, NO SPOOL, TEST TO 3000 PSI FOR 30 MIN, O.K., NU TEST BOPE, RETRIEVE RTTS AT 40', LD 4-3/4" DC. DAILY=~42,295 COM:$236,739 ETD:S236,739 EFC=$482,000 9 EIVED Alas Oil & 8as Cons,, .C0mmis i0r ,, Nmh0rage The above is correct ~ Signs ",'- %, .... |O sFeoer ,cern ~'epareti ....~ diEt'bunion: ~' ~, Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D i~umber all daily wall history forms consecutively as they ara prepared for each well. jPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ~:~CO A~AS~.A INC. tC°unty°rt~r~H SLOPE Stat%K ] Field [3RUDHOE BAY Lease or L,t~L: 28312 P~:)W 3-1 war no. Auth. or W.O. ~2432 ITitle WORKO~'"~R I API: 50-029-20312 Operator A~CO I A.R.Co. V~_, 0000 Spudded or W,~ JDate 12/29/88 I otal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our 0430 ERS IPrlor status if a W.O. I Date and depth Complete rec~'61~f~ch1,:lay reported as of 8:00 a.m. 01/02/89 ( TD= 6150 PB: 6050 SUPV:CD RELEASE RIG. MW: 8.5 SSEAWATER LD 4-3/4" DC, TEST 9-5/8" CSG TO 2500 PSI, RUN 7" COMPLETION, DISP WELL W/ TREATED SEAWATER AND FREEZE PROTECT W/ DIESEL, STING SEALS INTO OLD PKR, LAND TBG, TEST TBG TO 3000 PSI, TEST ANNULUS TO 2500 PSI, ALL O.K., ~I~TF~$ OF ANNU S ~ ND BOPE, NO 7" TREE, TEST TREE TO 5000 PSI, SECURE WELL, RELEASE RIG AT 0600 HRS ON 01/02/89. NOTE: CAMCO 'BAL-O' SSSV @ 2192', BAKER 'FB-i' PKR ~ 3799', & TT @ 3924'. DAILY:S48,613 CUM:$285,352 ETD:S285,352 EFC:$482,000 Old TD New TD Released rig Date IPB Depth Kind of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Producing method IOfflcial reservoir name(s) I Potential test data Well no. Date Reservoir ! Producing IntervalO11 or gasTest time Productloll Otl on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected For form preparation and distributio[1, j v . see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all dally well history forms consecutively aa they are prepared for each well. iPage no. DlvlllO- of AtlantlcRichfleldComl~my DATE ' i i -i '3-88 ¢ "" ":' i 4-3.-88 CNI -[.;AMHA · :;.:. .... :-:, ...... ' ::2-.,:'.I. 'i ,?)-24-',:-'::8CC:L ' '._:.:""9 t i -"~'-8::'3 CNL-t'.'i:Ai'4HA · 2-'i 8 'r i -S-88 CNi..-(;i-AHMA · .a .~ .i r':, 'i 4 .... ;'""'; F:'F;.'.ODijCTiON i::'Rr'~F']:L.t:_:J ,"" , ~ ,.-'" ,:3 ,.;:." .... e ':'~,'"i i i '-'": ..... , _... - }4 H C N L.. - (.~ A M fd f-"~, · .a .... -'"- i i '=' ':'--", R C: N I...--C- A H M A ~ ,-*. .... ~ '::' i ;'.'~ '- '~ :5 .... 8,q ]: N ,.J E" C T I d"' "'l', r:, F;' n ~' ]: i i::' · '?i ..."' ;.,'i .-' . . ~ '. '--' ~ ~... ~ 4 ..... i 7 i '9- i 2-- >38 i N....i E C: T i 0 N F;' R 01::' i L.. E · 4'-2? i i -,,i.-::,':::~, CNL-C, Ai'4MA · 5 .... 3 i i .... 2-88 CNL...---(:i-AMMA Il ~:-._ .. ..;. i S i ] .... ")-q'::' ;"NL--C-.AMMA ,~'.. ~... %/ .%,. . · e 9 .... ?. :3 i i -:¥.';'- 88 T U B I N 6 C: U T T E R. '~g"-"~'-; 'i ,':'~--'~ ,4--8lq r',,-, i) 'f']:C~N , . L..E-(;.;.AMMA ........ ," r,.r') U C ... F:'F;; 0 l:: '[ ~1 'J.,-..") .... 3 'J () -' 'i· ¢~-r "" ~..,° ,,;::,.., J'""' F;.'. I.:'1. j:'"., I .... il"', "J" ]'. 0 J"J. i:;' R 0 i;:' '[' L.. E ,'-":,' U l:;..' V E '¥" · 'j "':',;.. ..... ,,.::" t ¢;'~.., -' i ..'5 .... i::: 8 e J:;.'. 0 ,..,i~ U C. 'T', Ti 0 i'J. e R i.J 1::', .,.T L · i 2 '"' i ;:"',, 'i ;:'",, -' i .,... ''''~ - ,.., (:~ ,..: '::~ ,i::' ]: T,E:, · i 4 - i 5 i (:) -. i 5 - S 8 i N J E C' T Z 0 i"~ F:' F;.: 0 F' i i_ E · 4. a ...'~ -.' 'i ,':',- 3 i -E', 8 C B : ~ ...~ ! ....- · i 4'-;"~7 i '9--',_'5,.i -88CET , , ..-.';:' o ..: '-' ,::.,-..'::, C B e" '~4-- ,.::.., I¢:; ::"~i '":'"" "I" _i 4 .-:?'", !::-: i ,'.;,- ::~ 'i'- 88 C E T · 'i :'.".; -- 25: i ,:'::, -'-2 (') .... 88 C: E: i_ - C-' A M M A J! 6--'7 i O -"22"- 8 iii F' F;.: 0 g U C f' :1:0 N i:'R U i::' .!: L. E ~ i ~:::=-- :,..:. 'i '":; .... 2 3 .... 8 iii :"' ~'''' ~ · ,: :.... :.... I.. Pt.,JDt,.J:;~- i i ,:i::, .... ! :~;.-88 (-;-AMh~ F;.:AY F:'!... Iii; A 2 E ,'.":.' i (;. N A N D F;.:ETLjRN 'i"I"!,E ATTACHED COi::'"f A;ii: " .... r'"" I V liE. I-,,1:: .... ::. D BY i-.iAVE A NiCF£ DAY'! '-'/'A- i i "" ,.~ ~"t ,.... ,.. 'f g 0 F:' i:-' E C K F l;-'. ~'::','T' 0 .... i ii: 29 & 6~ C0~, ~mm~551ot~- .. ~ ;P, nchora~S A F:' F:' R 0 V E D .......... ~'~ .................................... D I :-i' 'f' R :r B i.j T :[ 0 N R E: C: t::. :1: F'T DA'T'A ,. A f' !... A,'.'? C A r-i C 0 A f' L.. ~'::~ 2 A 'i'i_ A ;:-? C: A r~ C u A T L A 2 A'T' i... A 2 C A M ('.:: C) C: A M C A T t.. A 2 A 'i"L A 2 A'f' L.A;;i: (3 A M C: 0 C A t'i C 0 CAi'~CO C A H C ~'3 CAMCO SCH ,S' C H ,.~ C H' I:.; A M t::: O C A i,i C 0 C A M C 0 ARCO ALASKA, INC. p.O. BOX t00S6~ ANCHORAGE, ALASKA DATE' ii-t~-88 REFERENCE' ARCO PRESSURE DATA i-i i 0-'24-88 t -t 9 i C~-2'8-88 2-4 i ~-'*'- 4-88 4-i '7 i '3-~ 2-88 4-3~ . 9-2~ -88 4"'~2 9-2J -88 5-~ ~ ~ e-~ 9-88 5-~ ~ t ~3-~ 9-88 5-~ 5 ~ ~-j 9-88 6-~ 7 ~ ~9-~ ~-88 7-2 ~ ~-9-88 7-8 4 ~-9-88 9-5 ~ ~-5-88 9-29 8-~o-8 ' - ~'8--88 ~2-~ ~ (~-~ 4-88 i 2-6 ~ ~-~ '~-88 t n--t 6' t (~-4 2-88 q-? i ~ ~'- ~ 9-88 ~ 3-26 4 ~-6-88 ~ 3-28 ~ ~-6-88 i 4-t ~ 6-58-88 i 4-i 8 i t 4-32 i ~-7-88 i ~ ~ i ~-8-88 i 5-i ~ t ~-9-88 i 5-i 5 i ()-8-88 i 5-i 9 i i)-8-88 i5-22 t ~,-i ~-88 i 5-25 i ()-26'-88 t 6-7 i 0-22-88 BHP--STATIC GRADIENT BHF'--STAi' lC GRADIEN l' BHF'--STAI' lC GRADIENT BHF'--F'RESSURE FALL-OFF BHF'--STATIC GRADIENT BHP--STAT IC GRADIENI' BHP--STAT IC GRADIENT BHP--STATIC GRADIENT BHP--S'I'AT lC GRADIENT BHF .... STATIC GRADIENT BHF'--STATIC GRAD I EN'I" BHF'--STAT IC GRADIENT BHF .... FLOWING GRADIENT BHP--STATIC GRADIENT BHP--STATIC GRADIENT BHP .... FLOWING GRADIENT BHP--FLOWING GRADIENT BHF .... F'LOWING GRADIENT BHP--STATIC GRADIENT BHP--STATIC GRADIENT BHF'--STA'I'I C GRADIENT BHP--STATIC GRADIENT BHP--FLOWING GRADIENT BHF'--,.. TAT I C GRADIENT WHiZ,__STATiC BHp--.SI'ATI C GRADIENI' BHF'--SI'A'I' I C BHp-- STA'F I C B H P - - S '1' A T I C BHF'--STATIC BHP--STATIC GRADIENT GRADIENT GRAD£ENT GRADIENI' GRADIENT BHF .... STATIC GRADIENT BHF .... STATIC GRADIENT BHF,--FLOWING GRAD]lENT CAMCO C A M C 0 CAMCO CAMCO OT IS OTIS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO (;AMC(} CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO F'WD. W3-t i 0-i S-88 BHP--STA'I'IC GRADIENT PLEASE SIGN AND RETURN I'HE ATTACHED COPY AS RECE]If-"T OF' DAI'A, ATO-t 529 ' ': '~tJICliomget fRANS .,,.8 ~,o 4 ~. BUT I ON CEHTRAL FILES D & M E'XI'ENS I ON ELXPL..OI:~A"I" i EXXON MARATHON MOBIL AF'F'ROVE~-- -t- i::. Pi t L I... t; F' S ..,. 14,, ~ 'i", · ~ S A F' C .~ Si'ATE OF ~ TIE X A C 0 AI_A:~K A ARCO ALASKA, INC. P.O~ BOX 488368 ANCHORAGE, ALA£KA 99548 DATE: 9-4&-88 ~REFERENCE: ARCO PRESSURE DATA 3-4 9-4-88 BHP--FLOWING GRADIENT 3-22 9-t-88 BHP--FLOWING GRADIENT PWDW3-t 9-5-88 BHP--£TATIC GRADIENT PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA, CAMCO CAMCO CAMCO RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 TRANS APPROVED DISTRIBUTION CENTRAL FIL. E£ CHEVRON DiM EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS PB WELL FILES R & D SAPC STATE OF ALASKA TEXACO ARCO ~I.'..A~RA: I:NC~ ANCH£)RA~E, ALASKA D~'I'D: 4-26-BB R~.:CF'ER.F. CNCF...;: ~RP.,O CA2ED HOI_,F.. .'.?.'.9 4-~ 6"-88 PROD,.PRF'I..~.r./F'I...I) DEN..~ Tm1~'~' 4.-. ~ ;.~..-. ~ ~...1 H .T 2i?. ,. ~ 4 t (:)-.RJ!l I .... I...-TF. HF'FRATIII::.'.F.' I.. F:'I..r...:A.S'F:: .~,"l:r;N nNI) RE:TI.IF.~jTHF'. ~.~1::1.-I [-". !) r;rH"~..' RECF..'.TF'T .......... ..... FIF' RI.IN RI. IN RI.IN Al::' F:' R f) V r...'. I) ............. _.~ .......................................... I') I ,T'I' I~' T I'.]U.II' T I1N 17. ~ M r'. n .~ .P, ENTR~I...F T I....F.S' ~ F'H II..I... T F'2 f .P..HEVRDN F'FI W.F'.I... I.. F 'r I. I) & H R A D · ,~ EX'FEN2I[!N. E×F'L. DR~T.IHN .," 2~F'C ~ EXXON ~ ,~I'AI'E ElK MAR/~'I'HON. .,,. '"' T .F.'. X A .~,O · ,,.'"' HOB I I... STATE OF ALASKA ALASK~A OIL AND GAS CONSERVATION COM~,..SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubingX Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 413' FNL, 576' FWL, Sec. 3,'TION, R14E, UM At top of productive interval 413' FNL, 576' FWL, Sec. 3, TI'ON, R14E, UM At effective depth 413' FNL, 576' FWL, Sec. 3, TION, R14E, UM At total depth 413' FNL, 576' FWL, Sec. 3, TION, R14E, UN 5. Datum elevation (DF or KB) RKB 78 ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number PWDW 3-1 8. Permit number 78-39 9. APl number 50-- 029-20312 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical 61 50 ' MD feet 61 50 ' TVD feet Plugs (measured) No ne Effective depth: measured 6050 ' MD feet Junk (measured) true vertical 6050 ' TVD feet feet Fish ~ 6004' (perforating gun) Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 370 sx Arcticset 123'MD 123'TVD Surface 2737' 13-3/8" 5040 sx Permafrost II 2737'MD 2737'TVD Production 6102' 9-5/8" 500 sx Class G & 6131'MD 6131'TVD 510 sx Permafrost C Circ. String 2368' 7" N/A 2394'MD 2394'TVD Perforation depth: measured 5540 ' -5565 ', 5640 ' -5650 ' , 5658 ' -5673 ', 5690 ' -5705 ', 5725'-5735', 5852'-5867', 6020'-6030' true vertical 5540'-5565'. , 5640'-5650' , 5658'-5673 'R ~t(~(~ ~j~0~ ~ 5725'-5735', 5852'-5867', 6020'-6030' Tubing (size, grade and measured depth) 4-1/2", CSCB, tubing w/tail ~ 3939' ~f~::;i:;~'~,~.~ ~,' '"':' P~acMers and SSSV (type and measured depth) Ker FB-1 pKr L· 3801', Otis RQ SSSV ~ 221 8' Alast<a Oil & Gas C0ns~ Commissio~ Description Summary of proposal ~ Detailed operations program [] BOP sketch 12.Attachments 13. Estimated date for commencing operation June 1, 1988 Date approved 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and Correct to the best of my knowledge Signed (~7~o~ ~U.,L~ Title Associate Engineer Date ~)'I . Commission Use Only (JG) SA3/87 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI 'C_,/ ~,pproved Copy Returned ORIGINAL SIGNEDsMtTHBY -: ~-'~-~ .~/.~¢ by order of ~ ~,~ ~- _.,~) Approved by LONNIE C. commissioner- the commission Date/~! Form 10-403 Rev 12A-85 Submit in triplicate APPLICATION FOR SUNDRY APPROVALS PWDW 3-1 WORKOVER PROCEDURE OBJECTIVE: The purpose of this workover is to remove the existing 4-1/2" production tubing and 7" glycol/water circulating string and replace them with a 7" production tubing string and 7" 5M tree. The existing perfora- tions will be isolated via wireline set blanking plug in the existing packer tailpipe. The packer will not be replaced, however, the 9-5/8" wellhead packoff will be replaced. Perforations will be added within the existing perforated interval. 1) RU slickline. Pull the 4-1/2" SSSV. 2) RIH w/Camco DB-P blanking plug on DB-6 lock and lock plug in nipple at 3881 'MD. Pressure test plug to 3000 psi. 3) POOH, RD slickline. 4) RU electric line. RIH, perforate 4-1/2" tubing above Baker packer at 3780'MD. POOH, RD electric line. 5) MIRU. Displace the 4-1/2" x 7" x 9-5/8" annuli with seawater. Set BPV. ND tree. NU BOPE and test. Retrieve BPV. 6) Release 4-1/2" tubing from packer and POOH. tubing hanger. LD 4-1/2" tubing and 7) Pull 7" mandrel hanger packoff and engage 7" mandrel hanger. POOH, LD 7" hanger and 7" circulating string. 8) Close blind rams, pressure 9-5/8" casing to 2500 psi for 30 min. If 9-5/8" casing will not hold pressure, PU 3-1/2" DP and 9-5/8" RTTS and isolate 9-5/8" casing leak. Check FOs at 2356'MD and 2518'MD first. 9) MU 9-5/8" storm valve and RTTS and set same in top of 9-5/8". 10) ND BOPs, tubing head and 7" circulating string casing head. Replace the 9-5/8" mandrel hanger packoff. NU tubing head. Test the 9-5/8" and 13-3/8" packoffs to 3000 psi and 2000 psi, respectively. 11) NU BOPs and test. Retrieve RTTS and storm valve. 12) MU new seal assembly on 7", 26#, L-80 LTC 8rd tubing and RIH. Sting into Baker packer. Space out and land hanger. Test annulus and tubing to 2500 psi and 3000 psi, respectively. 13) Set BPV. ND BOP. NU new 7" 5M tree and test. i-~!~CEIV'E~) PWDW 3-1 WORKOVER PROCEDURE (cont'd) 14) RD, RR. Pull BPV. 15) RU slickline. Retrieve DB-P blanking plug. Run SSSV. 16) Production will add perforations after rig release. Bottomhole pressure: 2496 psi @ 5625'TVD (8.53 ppg) Workover fluid: Seawater DCS/23a 4/25/88 ANNULAR PREVENTER 6 TUBIN6 HEAD ;3 2 1. 13-3/8" CASING HEAD 2. 9-5/8" CASING HEAD 3. 5000 PSI TUBING HEAD 4. 13-5/8" - 5000 PSI BLIND RAHS 5. 13-5/8" - 5000 PS! PIPE RAMS 6. 13-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REHAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE HANIFOLD. 4. TEST ALL COHPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOP. 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOP, 10 HINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAH PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAH OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAHS. BACKOFF RUNNING JT AND PULL OIJ~ OF HOLE. CLOSE BLIND RAHS AND TEST TO 5000 PSI FOR I O~IlNUTES. BLEED TO ZERO PSi. 10. OPEN BLIND RAHS AND RECOVER TEST PLUG. HAKE SURE HANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION· 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUHP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORH. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE DOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY ~?~. ~'~ ~"~ ~ ~,/' ~:i:: ?i~ ANCHORA(;E., AI...A,~K A 99gi DATE · ! -??-,.qB RF-.FERE ...... ARf]f] PRE,~,~IRE f'~AT'A BNF-' FI...OIJTNf~ -r,.-,- - . f,, ,.; ~.-, f') '1' F i':J T R Pt F' - k- L (] L,I 'F i'-,! F, f~ K' A O T .F.-. ixl'F R I--I I:' - FI ,, 01~.1T N F. F. -F:A O T F: NT RNF'-,?TATT I~ f';RA]3'FP-I',IT c. T ~ T T C. I-~. P A 'f) T I::' i:,.J '¥ f:.: I-t I:' -.':. T:., T :"..' T !:;.' T f:-: ! i'T 'E I"! ,ARCO ~I...~,.~.~KA: Ti,If".. .. . , ~ l<' r~ ~NCHCIR'A~E ~I...AS: F' R" FI ..f) I.J E T T fi IxJ F' F,: fl F T I .. F.,,".'..,-' F' T N / T F' H P Pt IMF'- T F.J 'TFHr:'IZI:;.'ATI II.IF F:' T T *"' ;' T I:--_ H P Pt;.'f'lf). !Irt. TT~]i'g F'PF~F'FI F'F;; f't DI !CT T Fiiq F'F~'RI~I t Ft.T T f'lF-J I'kl. JFCT!TRN F'l:;.'f'lFl'l F' F' ~ F11~ ! I f't. T T 1-I t',,I r', F;.' fq F" '[ I F:' F-;.' Fl f) I !F;T'I'Fii'..I PF-<F,,F'TI. F'F;.:FIT~! IC'f"Ff3i"-..~ F'IRF1F:'TI. f'; ¢i M M ¢~ I:;.' ~ Y / 'f' T F:' .--- 1' F, ¢~ i"4 M r..% R~AY/T !'F'- T NI F / 14 I::' F H / f",, I;.' I:~' / f') F~ N.? T TY I'T'F:'H F' F/I--IF'FH / T F'HF' ¢'F, 1' NNF' .i.? F"/I-I F' F'-N-Idl-II IT F-- / .:.:.' F' T MN F'I;! I flf'; / F1F; f':, '[ ;,'7 T F,: 'r R! IT T T F"T FtF' I"~ ',-% H C f'i F'. ~, M f': F! C ~'~ ici C f'l f". A H f~ F1 I~.A MC f*l f': A H f". f'l I'~ A H I~. f'i f': A i'4 F: F1 f': A H f": f'i f":AM C f'l ALASKA O/L AND GAS COftSE£1/ATiOtV COiYIt~f/$SIOI~ December 3~ 1979 3'.?Fi ' PgA',2~,'PINE ORI '."[' AA,'('t-,'{)I?AG~, ALASKA 99.501 Ms. K. J. Sahlstrom AROOOil and Gas Company P. O. Box 360 Andlorage, Alaska 99510 Receipt is ackno,~ledged 'for the following Schl~,~berger tapes: P~CO Prudhoe Bay DS 1-18 ARCO Prudhee Bay~zn~ns. 2 & 3 'ARCO 'Prudhee Ba~ Sincerely, 7// ,'" William Van Alen Petroleum Geolegist March 50, 197.9 Reference' Enclosed are the following cased hole logs' ~S 5-9 Sonan 9/20./78 /,,,,¢/~S 5-1. Sonan 10/-22/78 2-~ 6oc log ~1/1~/78 (.5~...~_ 'mT 12/ 5/78 CCL 5/26/78 OiL l/ 8/79 Z/vq)S 13-2 OIL 2/ 4/79 ~-6 T~ 1.0/~7/77 ~V~s z-7 Spi~er z/zs/79 Please sign and retun~ the copy as receipt of data. Sincerely, V.G. ReSmers North Engineering Tt~YSMt'IT;~ ft 141 DISTRIBUTtOX North Geology Fxxon D~ill ing. blobil I'5ng. Manager Getty R & I) Sohio -. ..... Geology- , · ~a rathon State of Alaska" Phillips D & M Chevron Atl.anticRichfield company North American Producing Division North Alask~strict Post Office i. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 7, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject:~'Permit No 78-39 '~'Perm?t No. ~8-14 Dear Sir: Enclosed please find a Completion Report along with the Perforating History for the above-mentioned wells. Very truly yours, P. A.. VanDusen District Drilling Engineer PAV-cs Attachments Form P--7 .i ~: ..SUBMIT IN DU~r~ATE* STATE OF ALASKA i i' (Se~otherln- st ructions on OIL AND GAS CONSERVATION coMMITTEE : I I WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYP-IOF WELL: OIL (;AS [ ,,'ELL WEL~. ~ ' Da, Other=WaterDisposal We · b. TYPE OF COMPLETION: .~EW [~] WOnK ~ DEEP'F--]~IcKPLU~; [---] DIrt.nESVR. [--] Other: Perforated OVER EN WELL NAME OF OPERATOR Atlantic Richfield Company A~DRESS OF 'OPERATOR' I :1 ' ' ', ' ,"' Il' ]~"' I fi - I ' " P.O. Box 360 Anchorape, Alaska 99510 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 576'E & 413'S of NW cr Sec. 3, TlON, R14E, UM At top prod. interval reported below 576'E & 413'S of NW cr Sec. 3, TION, R14E, UM At total depth 576'E & 41 3'5 of NW cr Sec. 3, T1 ON, R14E, UM ~. AP1 NIYlVIII~CAL CODE 50-029-20312 6. LEASE DI!~IGNATiON AND SERLA.L NO. ADL 28312 .~F INDIA. H, ALLOTTEE OR TRIBE NAME 8. UNIT,F.~R1VI OR LEASE NAME Prudhoe Bay Unit 9. ~EL~ NO.. ~roouceo Water Disposal Well No. 3-1 lO.~m~a ~Dvrua.oe ~oo~, ~ ~CAT Prudhoe ~ ~00! 11. SEC., T., R., M., (BO'I'rOM HOLE OBJECTIVE) Sec. 3, TION, R14E, UM 12. PI~:I~IIT ~o. 78-39 ' I 13. DATE SPUDDED '[14. T)ATE T.D. F,~CI-IED 115.'DA;TE CO'MP SUSP ~-'A~. [1~.' ~EVA~ONS (DF, RKB, RT, OR, ~)* 17. ~. CASINGHEAD ~ 5/13/78I 5/19/78 { 5/27/78(Perf'd 2/26/~9) 78' RKB 18. T~ D~H, ~ & TVD~9. ~LUG, 6150'MD & TVD I 6050' MD & TVD I ~°~ffTe I ,o,,,~,oo=, A31 { c,,~,.oo~.~ SUrVeY ~AD~ Top Cretaceous 5540'MD & TVD ~ No Base Cretaceous 6030'MD & TVD 24.: TYPE ELECTRIC AND OTHER LOGS RUN ,. DIL/SP/BHCS/GR, FDC/GR/CAL 4-Arm Caliper, GR/CBL/VDL/CCL IU I 25. '~ CASING RECY)RD (Report all strings set in well) 20" 9~'# Welded| I-I-401 123'.' I 13-3/8" 72~ Bu~t / ~-80~ 2737' 117-1/2" 4900 sx ~ermafrost II cm 47~ Butt ~80&S0~5 61)1' [12-1,/4"' 500 sx Class ~ cmt ~ . Bo=o~ (~ SAC~S C~' ! ' ~8. PEI~ORATIONS OP~.-~I TO PRODUC~ON (Interval, size and number) ~6020-6030' ~ 8 ' '5 52-5867 ~'5725-5735' ~!5690-5705' S5658-5673' 5640.5650' 5540-15565' W/4 shO~ts.~er ft. ii PRODUCTION $C-T~EEN (MD) SIZE DEPTH SET (1V~D) [ PACKER SET (MD) '1 4-1/2" 3959' 3801' 29. ACID, St!OT, F~ACI'LrRE, CE,5IE:NT SQUEEZE, ETC. DI~PT'II INTIilRVAL (MD) AMOUNf ;~ID KIND OF MA~I~Ei:~IAL USED N/A DATE FIRST PRODUCTION DATE OF TruST, II, OURS TESTI!ID ~[CItOI{E SiZE [PROD'N FOR ~LOW, TUm~G' ICX~ P~S~ IC~~~ O~. [ 31. DISPOSITION OF GAS (~old, ~sed %or fuel, vented, etc.) 32. LIST 0~ ATTACHMENTS PI~oDucTION MEIHO'D (Flowh~g, gas lifl, pumping--size and type of pump) OIL--BBL. ,1- WELL STATUS (Producing or G~%S---1V~CF. WATEI~-BB,L. [ GAS-OIL RA.TIO WATER,--BBL. [ OIL GRAVITY-AP1 1 ITEST WITNESSED BY Perforatin9 HiStory ' 33. I hereb~ certify that t,~ foregoing and attached information Is complete and correct as determined from alFavallable records 8IONED ~ .~,. 7~/~~ TITLE District Drilling Engineer ~,T~ ~)))aJ~. _ _ /~./~ *(See Instructions and S~ces for AdditiOnal Data on Reverse Side) INSTRUCt'IONS General: This form is designed for submitting a complete an<J correct well completion report encl log on oll types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not o;herwise shown) for depth measure- ments given in cther spaces on this form and in any attach:.'nents. Items 20, and 22:: If this well is corr{pleted for separatc, production from more than one interval zone (multiple completion), so state ~n item 20, and in item 22 show the prcJuci~.g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce..'t, show- ing the additional data pertinent, to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 211: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). S4. SUMMARY,OF F~O~MA~ION T~STS IN(;LUDIN(; INTERVkL T~TED, ~R~URE DATA ~ ~OVERI~ OF 6I~'. GAS, WA~ AND MUD '. ~one lop Cretaceous" 5540 5540 Base Cregaceous .. 6030 6030 .. .. ., . · .' :~='""'~r~:"~"" ~' .,~,~.~~ ~~ .,o.~.~.~t.... · ' " " ""-' · ~ · }~ '.-.,'"' ....'.~' '"'z~z'~'::- .... . , . . .... ... None . . , ... , . ....... Produced Water Disposal Well #3-1 Perforating History API 50-029-20812, ADL 28312, Permit No. 78-39 Ri§ged up perf equip 2/23/79. Tstd BOP. Perf'd intervals 6020-.6030' & 5852-5867' w/4 shots/ft. Start out of hole & gun stuck in tailpipe. Pull out of rope socket. RIH'w/dummy gun. Stuck gun had fallen to bottom. Tagged 1st gun on bottom @ 6004'. POH. Perf'd intervals 5725-5735', 5690- 5705', 5658-5673', 5640-5650' & 5540-5565' w/4 shots/ft. All perf'd depths referenced to VDL/GR/CCL log dated 5/22/78. Began injecting into well. Shut down @ 300 bbls. RD perf equip. Install tree cap. Released well to Production Dept @ 0800 hrs 2/26/79. North Alaska District Engineering 'T ]lAN S M I T TA L i_ J. A. l~ochonf£. ~_,.. ~.o ~ cc cc'" 'l'ransmitted herewith are the following for the subject well' !~t~n No. Scale BHC Sonic/Caliper Log -'-7----BHC Sonic/Caliper - Gam~aa Ray Log ~ '~- ..... BHC Sonic/Gamma p~y Log - Caliper/CCL Cement Bond Log/VDL Con~ensated Formation Density Log Compensated Neutron-Fm~nation Density ...... Compensated Neutron Log Core ~nalysis - Interval - Core No. Core Description (SWC) - Interval Core Description (Cqnv.) - Core No. D.irectional Survey -' Gyro Single S]{6t ~l-tishot I)rill Stem Test - Test No. ,._/_ ..... ]~al Induction l,aterolog Formatior~ Density Log Fm.~at:ion Density Log/Ganm~a Ray (;mrna Ray/CCI, I,aterolog Location Plat Microlaterolog - ~,!icrolog ........ Hudlog - Inter~al Sample I,og. (A.R. CoV) "- ........ Synergetic Log TVD-DIL '' f ) .t . . 1 ~ D-t oros~.ty I,og --~, y~if-~ . ~(erox Sepia BL Line -/ _ / · ::~::c:e:~l)'t: Acknow].edged }:or: Date: ease ret:urn rcc:eipt to' North Alaska Engineering P. O. Box 360 lnr'%ar,,~a Ala~kn ()qNl fl Atlantjc~RichfieldCompany North Americaj3-P~roducing Division North Alaska ','i ict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 2, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Produced Water Disposal Well 3-1 Permit No. 78- 39 Dear Sir- Enclosed please find a Completion Report along with the As-Built Survey for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer FMB: j h Attachments V~,-m P--7 ~ ~' SUBMIT IN STATE OF ALASKA st ructions on 5. API N~CAL CODE reverse side) O~t AND OAS CONSERYAXION COMMITTEE 50-029-20312 $. WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ~.. zYe~. oF w~,,,L: o., []] ~s ~ ~r L_]' °th~Water Disposal Wei WELL WELL b. TYPE OF COMPLETION: BACK EESYR. ()%'ER I [ EN -- '"~:[~ ?rudhoe Bay [Init 2. N&ME OF OPERATOR At]antic Richfield Company .~' . 3. ADDRESS OF OPERATOR - P. 0. Box 360, ^nchorage, ^laska 99510 4. LOc^trax oF WeLl (Report location clearly and in accordance with any State requirement,)* At surface 11. SEC., T.0 R., M., (BOTTOM IrlOI.~ 576'F & 413'S of NW cr Sec. 3, 110~, R14E, [I~ OmE~VE~ At top prod. interval reported below 576'E & 413'S of NW cr Sec. 3, T10N, R14E, At total depth 576'E f 413'5 of NW cr Sec. 3, TiON, R14E, UM 78-39 5/13/78 [ 5/19/78! 5/27/78 ! ( 78' J~KB .. INTERYALS CABI,E TOOLS 6150'MD & TVD /60SO"MD & Tva I S~ngle I All 22, PRODUCING INTERVAL(S), OF THIS COMPL2gTIO~Nr~TO,P, BOTTOM, NAME (MD AND TV'D)* 123. WAS DIRECTIONAL - { SURVEY MADE No I LEASE D~'~GNATION AND SERI-~L NO. ADL 28312 IF INDIA. N, ALLO'i"rEE OR TRIBE NA.IViE roaucea:.4~ Disposal Well N(~. 3-!) 10. ~IELD..a. ND PQ-OIi~D~ ~VIi~kT ~ruqgoe ~ ~ela ~ruonoe u~] ~oo'~ Sec. 3, TION, R14E, UM 24. Th~PE ELECTRIC AND OTHE~ LOGS RUN DIL/SP/BHCS/GR, FDC/GR/CAL/ 4-Arm Caliper, GR/CBL/VDL/CCL 25. CA. SIg~G SIZE 20" 13,3/8" 9-5/8" 7" 26. LINER IREC Otq.l) 28. PERFORATIONS OP~.-2N TO PRODUCX*IOi~I (interval, size and number) N/A _ i i CASING RECORD (Report all strings set in well) IWEIGHT, LB/FT.~ GI:{~kDE I DEPTH SET (M-D) [ HOLESiZE CES~[LNTINGRECOHD ' A2~IOUNTPULLED 94# Welded/ H-40l' 123'' ' I 30" t 370 Sa Arcticset 'l 72# BUtt [ m-80] 2737' ] [17-1/2" 14900 sx Permafrost II cmtJ 47# Butt~ ~-80&S0~95 61~1' [12-1/4" 29# BUtt / MN-80[ 2394' 500 sx Class G cmt [ . Glycol c.irculatinq ~rinoJ I 27. iUBING RE C OP~D SC~[EEN (~(D) SIZE DEPTI{ SET (MD) ] PACKER SET (MD) . 4-1/2" 3939' 3R01' I ,! V .....- ' -6 197,3 *(See Instructions and Spaces I:or Additional Data on Reverse Side) PRODUCTION , . ~t[] G~s t.. i- · ' . roducin or DATE_. FIRST PXODUCTION [ ~ODUCTION MEi.[{O9 (Flowii~g, ga3 lif~, purnping~size and t}pe of p P I01~ ,,l. DISPOSITION OF G~S (80ldj a,ed ]oryuel, vented, etc.) ~TEST WITNESSED 32. LIST OF ATTACHMENTS Drilling HSstory 33. I hereby ce~y/~ that th~ foreg~ndat, tached_~.~ information ls complete and correct as determined from alVavailable records SiONEDT~~.A /~ TITLE District Drillinq Engineer v,T~s _~~ ........... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- meats given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate praduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc-Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seper~tely produced, show-- ing the additional data pertinent to such interval. · Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing anti the location of the cementing tool. . Item 28: Submit n separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. $UMMAItY OIP I~O~MA'F~ON TF_~TS INCL, UDIN(; INTERVAL T~TED, PROCURE DAT~ ~ ~OV~I~ OF OI~', GAS, ' ' ' ~'' WA~ 'AND MUD NA~ .... ., ~IEA~. D~ ~ V~T~ D~! =. - d ,i , ..... , , k '~,,~'- ~ ...... ,. ~: .. . . , . A,~ ~[f~Ei.) glIOWS OP OIh, GAS ~ W'A.~.. ' .... . '~ i i .... I J ' 'l Ii I- ' I -' f r'lllr" '1 ~ ' ' '. , ~,, , · ,, i , , ,. ,r~",,-~,, ,,. -.' .................................. ~: .. DRILLING HISTORY Produced Water Disposal Well No. 3-1 API 50-029-20312, ADL 28312, Permit No. 78-39 Spudded well @ 2100 hrs 5/13/78. Drld 17-1/2" hole to 2750', RU & ran csg 13-3/8" csg w/shoe @ 2737' FC @ 2656'. Cmtd w/4900 sx PF II mixed to 14.6 ppg. Installed & tstd pko~f. Drld shoe & 10' new form. Tstd form to 12.4 ppg equiv. Drld 12-1/4" hole to 6150'. Ran DIL/SP/BHCS/GR, FDC/GR/Caliper & 4-Arm Caliper logs. RU & ran 9-5/8" csg w/shoe @ 6131', upper FO @ 2356', lower FO @ ~_. Cmtd w/500 sx Class G cmt. Did downsqz thru lower FO w/210 sx PF cmt. Did Arctic Pack job thru upper FO. Displ mud w/wtr, displ wtr w/CaC12. Ran GR/CBL/VDL/CCL logs. Ran gauge ring & junk bskt. RU & ran 52 jts 23# 7" csg hung off guide Collar @ 2394.'. RU & ran 119 jts 4-1/2" tbg w/shoe @ 3939', pkr @ 3801'. Di'spl CaC12 wtr w/clr wtr displ clr wtr w/glycol wtr. Pulled dummy.-val.ve,-Ra.n-.dumm~-gun/CCL log. RU tree. Press tbg for long term tbg tst. Rel.eaSed rig @ 1800'hrS. 5/27/78.. TIlN T ION 4 34 PROTRACTED SEC. CORNER Y = 5 94~5 64634 X = 676 30§.47 LAT. 70° 15';~5.530"~1 LONG.148P$4 29.966 W I I0 POSITION OF WATER WELL Y = 5 945 246.90 xz 676 891.71 LAT. 70° 15 21.4~6 N LONG. 148 54 l;5.188 WATER DISPOSAL WELL NOTE5 Protracted Section Line N 88038'19'' E 5279.66 ALL BEARINGS AND DISTANCES ARE ALASKA STATE PLANE ZONE 4. REVISED WELL LOCATION SHOWN SUPERSEDES DWO. 39-FS $-78 DATED APRIL 1978. VICINITY MAP I". ~l:xx) ' CERTIFICA'rE OF' ~::;UHVEYOR ' ,,~ ~ ',.~. r,,:_~.~ t ,-',,,APT!CE_ AN. :".! ~¥'F ¥lNt i{~ d~ ,~' ~, ,iv[. h, 39A-FSi-'/8 ATL ANT 1.~ RICHFIFL~ AS - BUILT WATER DISPOSAL WELL 3-1 LOCATED IN N~ i/4 OF PROTRACTED ~CTION ~ T ION~RI4E~ U,M. HEwer~ v ~.C. UNSBUR~ & ASSO-' MAY 1978 i"= 300' PC Ben~ BOPE Tests - Arcx>'s 1~1~ 3-1 Joe ~, Arco ~ ~, am~ Jim ~at/~rly, Rogen Rig ~34 ~,~_~ .15~. ~.- m ~est completed or, Sohio's B-8, the subject Of a'~~e ~, ~to~,s ~ 3-1. Tests cm PW]W 3-1 began ~ 7:15 PM. Drillh~ f~ for Arco ~ ~ ~ ~am~er ~ ~ ~/g #35 was ~ A~sns. S~0e~ 13 3/8" was set at 2735'. Blh~ r~, bo~h ~ valves in t~ kill bot~.les ~ 2250, 2050, 2300, 2250 az~ 2250 psig. ~ pipe rams t~en ~ t~ 5000 ~ig. Upper pipe val~ in. ~ kill ~ ~ to 5000 p~ig. Ammlar preventer to 3000 psig. ~ 3-1 -2- ~ 22, 1.978 attl~~z~$~ omal~atl~45i~. I iel~~ 2.-00 PM ~ ~ ~ ~ at 2:35 Drlg. Permit No. ~-~'~ Opera tor_j~_~~- Satisfactory Type Inspection Yes No Item (~-)'~[ocation,General Al:i. .a Oil and Gas Conservation Commi Field Inspection Report ' Repres_ented by .~_~z~_~/ Name & Number.~_~/~_Z~_x.~./__ ~,/. Satisfactory Type Inspection Yes No Item (~:~tBOPE Tests (,~() (~)- ( ) (~() (~r ( ) () () () () () () () () ()' () 1. Well Sign 2. General Housekeepinq t. Reserve Pit-( )open( )filled 4. Rig - ( ) Safety Valve Tests 5. Surface-No. ~iells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos.~,_ ,__, 8. Hrs. obser , , , 9. BS&W _, , , 10. Gr. Bbls. ( ) Final Abandonm~-n~c 11. P&A Marker (~r() (~() (~- ( ) (~() (~)~() (A~() (~ () (~() (~)~ ( ) (~r() .15 '-~' Cas n ¢' 16 TesL fluid-( )wtr. ( )mud (~oil 12. Water well-( )capped( )plugged 13. Clean-up 17 18 19 20 21 22 23 24 25 26 27 28 29 30 () () () () () () ( ) ( ) 14. Pad leveled' (~r' ( ) 31 Total inspection observation time/-/,~'__hrs/~ Total number leaks and/or equip, failures Remarks Master Hyd. Control Sys.-_~'~mz~pSiQ ~'!2 btl s .~'~"'~,~2.~.,.7_L:~,, ~!~s i 9 ~ ~-~'~ Remote Control s ~ ~ ~'~ Drilling spool-__~ "outlets Kill Line-(~Check valve Choke Flowline ( ) HCR valve Choke Manifold No. valvs~flgs~ Chokes.-( ~mote( )Pos. (:~dj Test Plug-(~llhd( )cs~( )none Annul ar Preventer ~,pSiQ B1 ind Rams ~~siQ Pipe Rams ~.~siq ~) Kelly & Kelly-cock~,~psig Lower Kelly valve ~-~..psi~ Safety Floor valves-:(-'~ (~:Dart days or when ready F. M..~ Form 10-401 REV. 1ol-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL ]E:~] DEEPEN I--'] b. TYPE OF WELL SUBMI~ IN TRII-,._ATE (Other instructions on reverse side) API No. 50-029-20312 6. LEASE DESIGNATION AND SERIAL NO. ADL 28312 7. IF INDIAN, ALLOTTEE OR TRIBE NAME OIL GAS ~ Water DisposalSINGLE n WELL [] WELL ! I OTHER ZONE I I 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, AK 99510 4. LOCATION OF WELL At surface 370 'S & 567'E of NW cr Sec. At proposed prod. zone Same as surface 13. DISTANCE IN MILES AND DI~ION FROM NEAREST TOWN OR POST. OFFICE* Approximately 4.0 miles north of Deadhorse 3, TION, R14E, UM MULTIPLE ZONE 8. UNIT FARM OR LEASE NAME Pr,Jdhmo_ Rav 9. WELLNO. ProdUced Water Disposa Well No. 3-1 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, TION, R14E, 12. 14. BOND INFORMATION: ~EStatewide Sutetyand/orNo. Federal 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ff any) 370 Insurance Co. #8011-38-40 i l6. No. OF ACRES IN LEASE 19. PROPOSED DEPTH 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. In.excess of 15 5nn, to [ nearest salt wa~er alsposaT ~e¥¥ 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 6100' , :~ Lrct iyhL hole Amount $100,000 17. Ne. ACRES ASSIGNED TO THIS WELL 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START 5-1-78 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94# H-40 BO' bel pd. ]irc to surf, approx 500 sx 17-1/2" 13-3/8" 72# MN-80 2700' ]irc to surf, approx 5500 sx 12-1/4" 9-5/8" 47# . 500-95 6100' 3000+ .cmt column on 1st sta,qe &MN-80. ~pprox 1500 sx on 2nd stage 7" 29# MN-80 Surf to 2400' ~lycol circ strin.q 4-1/2" 12.75# N-80 3400'' Injection string SEE ATTACHMENT RECEIVED APR 1 8 1978 D',vision oi 0il and Gas (,.ns¢~-vation A~ohorag~ IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dixectionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. hereby certify that the Foregoing is True and Correct ~Aprit 14, 1978 TITLE District Drlg. Eng. (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~ NO DIRECTIONAL SURVEY REQUIRED, CONDITIONS OF APPROVAL, IF ANY: PERMIT NO.. APPOVED BY MUD LOG [] YES ~N0 OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE APPROVAL DATE April 25, 1978 · TITLE DATE , ' *See Instruction On Reverse Side Atlan~i~LRichffeldCompany North American Producing Division North Alaska/~,trict Post Office Bc,~.. 360 Anchorage. Alaska 99510 Telephone 907 277 5637 April 19, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Produced Water Disposal Well #3-1 Dear Sir' Enclosed please find three copies of the As Built survey for the above mentioned well. Very truly yours, Engineering Associate Enclosure RECEIVED APR 2 0 i918 A,lchor,~.,~e TION 'T II N 33 -4 34 I0 PROTRACTED SEC. CORNER Y = 5 945 646.34 X = 676 5_0,5_.47 ,, LAT. 70° 15 25.530 N LONG. 148° '34. '29.966" W 566 FT P 0 S IT I 0 N OF WATER WELl. Y= 5 945 295,73 X~ 676 880°33 LAT. 70° 15'21.948"N LONG. 148054' 15. 486" W Protracted Section Line WATER DISPOSAL WELL I N 88°38'19'' E I t 5279.66 NOTE ALL BEARINGS AND DISTANCES ARE ALASKA STATE PLANE ZONE 4. RECEIVED 34 2 TIIN T IO'N VICINITY MAP I" = 2000' APR 2 0 Division oi Oil ~n~i (~; Aii~hora CERTIFICATE OF SURVEYOR ~ HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSEDTO PRACTICE LAND SURVEYING IN THE STATE OFALASKA AND THAT THIS PLAT REPRE - .SENTS A LOCATION SURVEY MADE ISq( MEOR UNDER MY S~JPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. D A'FE SURVEYOR ARCO No. HVL No.39-FS ;5- 78 uA NTIC RICHFIELD CO. AS-BUILT WATER DISPOSAL WELL 3-1 LOCATED I N N.W. I/4 OF PROTRACTED SECTION $ t T ION~RI4E~ U;M. PREPARED BY HEWITT V. LOUNSBURY 8~ ASSOC. 7£3W 61n. AVE., ANCHORAGE, ALASKA DATE APRIL 1978 SCALE I":~)0' CHKD. BY HPC FIELDEIK AtlanticRiGhfieldCompany North Amerip,~. Producing Division North Alaska. strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 19, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Produced Water Disposal Well #3-1 I DIR c. ~NG~ Dear Sir- Attached is the sketch of the BOPE hookup and the diverter system to be used on this well. A check with our North Alaska Land Department indicates that the DiviSion of Minerals and Energy Management has already issued a Lease Operation LO/NS #77-137 for this site. Please let us know if we can be of any further help. Very truly yours, Frank M. Brown District Drilling Engineer FMB/CJS/am Attachments cc' J.D. Carr- N. Land RECEIVED 9 19/'8 SURFACE ' O~VE~TER SYSTE~ Q. ® ® RE-CEIVE'D 4.PR .1 9 1. 20" BRADENHEAD DJvisiOI3 ¢~t Oil ~tri(/ (~ f;{msr~rv~/jon ' 2. 2o" 2000 PSI DRILLING SPOOL Anchorage 3. 20- 2000 PSI ANNU~R PREVENTER 4. 6" BUTTERFLY' VALVES 5. RIG DRILLING RISER 6. 6. LINES TO SUMP Prevailing Winds 100' minimum 2-8" diverter lines I ] 100' minimum REC, EIVED APR 1 9 1978 ¢i Oil Diverter Line Schematic for BOPE on 17-1/2" hole CRK/BDR February 1976 Atla~nticRichfieldCompany ~ North Amerie"~, Producing Division North Alaska J,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 18, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: PWDW #3-1 Dear Sir: Enclosed please find the additional copies necessary to process our application for Permit to Drill Produced Water Disposal Well #3-1. Very truly yours, K. K. Lenz Engineeri.ng Associate KKL/am Enclosure AtlanticRichfieldCompany · North Americ~a~.. ~ Producing Division North Alask i strict Post office Bo~( 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 17, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' Produced Water Disposal Well #3-1 Dear Sir- Please find enclosed our application for Permit to Drill along with the $100.00 filing fee for the above mentioned well. The required survey plat will be forwarded when it becomes available. For your information, as well as the State Department of Labor, this well is a straight hole with the surface and bottom hole location both on ADL 28312. This lease has an effective date of 10-1-65 and a termination date of 3-'27-84. Very truly yours, F. M. Brown District Drilli~ng Engineer FMB/CJS/am Enclosures RECEIVED 'APR i 8 19/'8 , 'T APPLICATIO~ FOP, ?ER~T-T TO DRILL OR DEEPEN producecl Water Bisposa~ J.~ll #3-1 i n the AtlantiC Richfield Company progoses to drill this well to will be 0-3/4" spherical BOPhol. Rna e~ to provide for produced water disgoSal straightus interval 3~00'-6000'- 5A8,2, 5000 Dsi spherical Cretaceo _ ~,, ~a,rtor. A 13- /_. -~ ~ -sea on the 13-3/$" seal on the_~u. ~"~: rams (RSRRA) w]t~ u: ~ ly u ' bl~no and v,w-- - '. ted weekly and oPerational 5000 ps} be pre_ssure._te~Sver selected inte. rval_.s~ and casing. The BDPE ~'ll - atin ethylene glycol will tested each tr~p. Logs w~l_l be ru~_u~ ~o ~D No coring ~ be 9-5/8" casing will be set trom surrey:" ' . , ~ ~,, :erin~ fo~ c~..rcul ~ g~-~- :tring comprisecl of anticipa~:?- ,~ ' %~- u~face. A comp/ea~u'~' ~ze,, fubinq. A non-freezing fluiC~ will be left in all annuli w~thin the interval- A 4" 5000 psi tree will be installedPand' the completed well will be perforated at a later ~ate over selected intervals between 34'00' and 6000'- ~his well will serve for disposal of all. produced water at Flow Station #3. RECEIVED APR 1 8 Ig78 Divisio~ o~ Oil :~nd G~s g(mscFv;~/ion A~q~h~rag~ CHECK LIST FOR ~-~ W~r,T, PERMITS Company Yes No Remarks 1.Is the pern~t fee attached ..................... Lease & Well No. /~ .~,,~_) I rem Approve Date -(1) Fee 2. Is well to be located in a defined pool .............. 3. Is a regisqered survey plat attached ......... ~,,~ tb~ ~' ~'~ / / -f . · ...... ~ 7,~, ~,~'~3~ UJ~ ,, ,~ ' ~ ~ / 4. Is well located pr~r dist~ frm Propert7 l~e ......... ~<~' _.. 5. Is well lccated proper distance from., other wells .......... 6. Is sufficient undedicated acreage available in this pool ...... ~ __ 7. Is well to be deviated ..................... , . (2) Loc. ?~0 < 8. Is operator the only affected party ................ 9. Can permit be approved before ten-day %~it ...... 10. Does operator have a bond in force . ,,. ~. 11. Is a conservation order needed ................... ?/~,m~ .... 12. Is administrative approval needed ................. ~+~3K,~ . 13. Is conductor string provided .................... 14. Is enough cement used to circulate on conductor and Surface .... 15. Will cement tie in surface and 'intermediate or production .strings 16. Will cement 'cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... 18. Will all casing give adequate safety in collapse, tension & burst (4) sg. 19. Does BOPE have sufficient pressure rating - Test to jDOO psig . /f~z; ,_. Y~ ~~~~,6~ ~ -(5) ~PE 20. Has D~ a?pr~ Pi~ of ~ra~on ................ ~ ~ ~,/~ ~~0'~~ ~t~ -(6) PI~ -- ~' ' ', ' ~pr~al Rec~nded: ' Ad~tional Re~r~nts$ ~~ ~~ ~ ~ ~ ~ ' _. ~, ~ ~ C~O!~: ~g~eer~g: _C~ ~~ ~~¥,~~ ~/;~/FF ~ ~ E ~ ~s~ 4/14/78 ......... Well History File APPENDIX Information of detailed nature that is not particulady germane to the Well Permitting Process · but is part of the history file. To improve the roadability of the Well History file and to simplify finding information, information of this nature is.accumulated at the end of the file under APPENDIX.' ., No special'effort has been made to chronologically '~.: organize this category of information. · VV VV EEEEEEEEEE RRRRRRR~ VV YV EE RR RR VV VV EE RB VV VV RE R2 RR VV VV EE R~ RR VV VV EEEEEEgE RR~RRRRR VV VV EE RR RR VV VV EE RR RR VV VV EE R,~ VV VV EE RR RR VV EEE;~EEE;E~E RR RR VV EEEEEEEEEE R~ RR 1Illii II ii i! I1 1i I1 ii 1I 1I 1i iIiIlI IIIIIl FF YY YY YY Y Y YY 000000 000000 666666 000000 000000 666666 O0 O0 O0 O0 66 O0 O0 O0 O0 66 O0 0000 O0 0000 66 00 0000 00 0000 66 00 00 00 00 00 00 60666666 O0 O0 O0 O0 O0 O0 66666666 00Q0 O0 0000 O0 66 OOOO O0 0000 00 66 O0 O0 O0 O0 66 O0 O0 O0 O0 66 000000 000000 666666 000000 000000 666666 66 66 66 66 ,$tARI'$ USER PCCC [1070o,53152] dOB SHiP SEQ. MC:IixlITOR $W$ KLJ. OE34 JUL' 79. *START* fILE.: DSKH:VERiF~.00~<05I>[10706 53152J C~;ATEO: PRINTED: 31--OCT 79 19:4~139 QUEUf~ SWITCHES: /f'iLE:FORT /COPIES:I /SPACING:I /LIM1T:6b /f'ORMS:mORmAL 164 D A'I~E ]1-OCT-79 31-OCT-79 19:39:23 19:~3:20 ,) PACI~IC CIOAST COMPUTING CENT~,R 10700,5_]152 LENG~BH: 132 BYTES REEL NAME: P.C.D.C. SERVICE NAME: EDiT REEL CONTINUATION NUMBER: O! PREVIOUS REEL NAME: COMMENTS: bls FORMAT CUSTOMER ]!APE DATE: 79/10/31 TAPE HEADER LENGTN: 132 BYTES TAPE NAME: 5~152 SERVICE NAME: ED1T TAPE CONTINUATION NUMBER: O! PREVIOUS TAPE NAME: COMMENTS: fiLE' HEADER LENGTH: 62 BYTES FiLE NAME: EDiT .001 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: DATE: 1024 BYTES WELL SITE INFORMATION RECORD LENGTH: COMPANY: ~ELL: ~' IELD: COUNTY: STATE: 142 B~TES ARCO PRODUCED WATER DISPOSAL #]-1 PRO DH,(]~', BAY NORTH SLOPE ALASKA [')A'£A FURMAT 8PEC1F'ICA~ri~JN LENGTit: ~)10 B~TE$ 0 SIZE 1 REP CUDE 66 D~I'UtV~ SPF.,CIi~ICATION 56UCKS: ENTRY lC TOOL SVO[~D# UNITS AP1 APl AFl AP.[ FILL~ SiZe, EXP PROC SAM REP OEPT DEPT SP DIL 1LD Dlb ILM DIL LLSU GB CmL CALl CNb DRHO ~'DC NPH! CNL RHO8 CNL NRAT CNL NCNL CNL ECNL CNL G~ BHC OT BHC FT 0 0 0 0 0 4 0 0 1 68 0 0 ~V 7 1 0 0 0 4 0 0 I 68 0 0 OHMM 7 12 46 0 0 4 0 0 1 08 0 0 OHM~ 1 12 44 0 0 ~ 0 0 1 6~ 0 0 OHM~ 7 22 8 0 0 4 0 0 1 68 O 0 GAP1 42 ]1 32 0 0 4 0 0 1 68 0 0 IN 42 28 1 0 0 4 0 0 1 68 0 0 G/C] 42 44 0 0 0 4 0 0 1 ~8 0 PU 42 68 2 0 0 4 0 0 1 68 0 0 G/C3 42 35 1 0 0 q 0 0 1 68 0 0 C/C 42 42 1 O 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 q 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 68 0 0 GAFf 60 31 32 0 0 4 0 0 1 68 0 0 U$/F bO 52 32 0 0 4 0 0 1 68 0 0 DEPTH 6180.000 6100.000 6000.000 5900,000 5800.000 5700,000 5600.000 5500,000 5400.000 5300.000 5200.000 M N ~ ~l U N 1 C SP RttOB SP GR RHOB GR SP SP GR RHOB SP GR IRHC)B GR SP GR RHOB GR 8P GR SP GR SP GR RiiOB SP GR SP GR RHOB GR VALUE -999.000 0.000 2.501 -999.000 83.316 bl.O00 2.372 13.267 40.884 63.600 2.461 13,133 ]4.644 83.500 2.404 13,167 75.329 50.600 2,293 12.800 77.825 49.000 2.251 12.867 55,860 59.400 2.242 13,100 61,101 54.000 2.290 13,000 10.1,83 91.200 2.410 13.43] 81.818 43.800 2.182 13.033 43.380 56,400 2.216 1~.267 tsMUN lC CALl UT ILD CALl NRAT DT ILD CALl NRAT DT ILD CALl NRAT DT ILD CAb1 NRAT DT 1LD CALI NRAT ILD CALl NRAT DT CALl NRAT DT ,ILD CALl NRAT DT ILD CALl NRAT DT ILD CALl NRAT DT .V Ab -999 0 -999-9gg 390 1-2 47 90 272 11 3~3 12 72 95 11 39 93 87O 11 44 i00 444 11 5.4 103 597 11 45 93 353 12 71 102 879 12 30 103 515 1.2 51 109 UE .000 .657 .000 .O00 .841 .117 .374 .392 .898 .959 771 :619 .558 .117 .482 .540 .232 .800 .362 .263 .964 .879 .813 .292 631 .919 .311 .905 .035 .998 061 :461 .183 .474 ,821 ,470 ,022 .117 ,525 .757 ,229 .236 .586 .499 MNkMUI41C ILM DRHO NCNb L)RHO NCNb DRHU NCNb NCNb IbM DRHO NCNb IbM DRMO NCNb ibm DRHO NCNb NCNb DRHO NCNb DRHU N C N b ibm DRHO NC N b VALU~ -999,000 0,000 -999,000 353.183 0.047 57.200 2bO.blS 0,070 75,000 322.107 0.044 86.000 642,688 0.048 49.000 787,046 0,033 49.300 424.620 0.034 08.200 501.187 0.047 51.300 331.131 0.066 86.900 809,096 0.049 40.500 478.030 0.032 58.900 MN~MON lC bbSU NPHi ~CNb bb8U NPHI FCNL bLBU NPHi FCNb bLBU NPH£ FCNb 6LSU NPfli FCNb LLBO NPHI bLBU NPHI ~CNb bLBU NPHi FCNL LL8U NPHI FCNL L68U NPH1 FCNL b L 8 U N P H 1 FCNL VAbUE -999.000 O.OOO -999.000 218.776 0.000 13.400 229.08/ 0.000 13.467 293.765 0.000 13.200 ~48.745 0.000 13.000 483.059 0.000 13.233 337.287 0.000 13.13.3 304.789 0.000 13.400 313.329 0.000 13.500 457.088 0.000 13.333 300.438 0.000 13.367 DEPTH 5100.000 5000.000 4900.000 4800.000 ~700.000 4600.000 4500.000 4400.000 4300.000 4200.000 4100.000 SP RHOB GR 8P GR SP GR R H O B OR SP GR R H 0 B GR SP GR RHUB GR SP GR RHOB GR 8P GR RnOB GR SP GR RHOB GR GR RH, OB GR SP GR RHOB GR SP GR G~ V Ab 44 72 2 13 6 51 2 13 38 102 2 13 .62 .80 .25 .30 .87~ .100 .148 .13,3 .637 .100 .361 .467 4i.133 92.b00 2.349 13.333 ]6.641 84.000 2.373 13.667 68.589 6].200 2.220 12.867 39.885 97.300 2.403 13.600 39.386 89.700 2.333 13.bO0 80.071 33.000 2.212 1,3.133 44.378 79.700 2.356 13.267 54.861 70.900 2.294 13.333 iq N CALl NRA~ DT ILO CALl DT ILD CALl NRAT OT ILD CALl NRAT CAI, I NRAT DT iLD CALl NRAT DT 1LD CALl NRAT DT CAbi NRAT DT iLD CALl NRAT DT CALl NRAT DT ILD CAL i NR AT DT VALUE 452.898 12.157 55.550 111.380 190.546 12.316 41.510 11b.429 356.451 12.395 85.449 107.123 29b.483 12.276 79.089 106.529 277.971 12.355 71.1.60 108.459 444.631 11.879 51.255 1.08.311 208.930 12.595 85.614 120.983 208.930 12.672 78.180 113.2bl 440.555 12.474 27 147:81 165.959 12.197 69.260 110.b37 197.697 12.23b 57.532 1.12.419 MNeMONiC DRHO NCNb DRHO NCNL DRHO NCNU i LM NCNL DRHO NCNb IbM DRHU NCNL DRHU NCNb IbM DRHO NCNb IbM NCNb IbM DRfiU NC N h VALUE 432.514 0.Obl 71.700 190.546 0.029 48.900 .340.408 0.036 99.700 246.604 0.039 95.300 200.615 0.081 84.200 420.727 0.018 62.800 197.697 0.096 92.800 201.372 0.078 90.100 390.841 0.100 32.300 159.956 0.047 81.700 188.799 0.020 14.000 MNEMONIC bLSU NPHi FCNL LLSU NPHI FCNi; LLSU NPHI FCNb LLBU NPHI FCNb bbSU NPHI FCNL bhSb NPHi FC N b LbSU NPHI FCNh i~PHI FC NL LLSU ,NPH1 FCNb LLSU NPHI LLSU NPHI VAbUk 0.000 13.~00 185.353 0.000 13.333 $07.610 0.000 13.533 220.98~ 0.000 13.500 233.340 0.000 13.13,3 340.408 0.000 12.80'7 1'10.608 0.000 13.~00 192.309 0.000 13.733 307.610 0.000 13.867 154.170 0.000 13.I33 1:'13.780 0.000 13.233 DLPTH 4000,000 ~900,000 3800.000 3700.000 3600,000 3500,000 3400,000 3300.000 320O,O0O ,31 O0. 000 3000,000 M~bMONIC GR GR GR RhUB GR SP GR GR SP GR GR SP GR GR SP GR R GR SP GR 8P RHOB GR GR RHOB GR 8P GR SP GR RHOB GR VALLE 55.860 80.800 2.326 13.200 51.806 78.700 2.305 13.067 50.369 91.000 2.338 13.333 59.105 83.200 2.344 1,2.967 71.834 57.800 2.247 12.967 68.839 78.700 2.27.3 i3.067 73.831. 66,500 2.238 13,067 77,5'15 63,700 2,130 13,400 48.871 92.200 2.214 13.1.67 70.836 72.800 2.209 13.267 75.828 62.700 2.100 1.3,000 CALl DT iLO CALl NRAT DT lbD CALl NRAT DT CAb 1 NRAT DT CALl NRAT DT 1 LD CALl i~RAT DT CAb i NRAT DT iLD CALl NRAT DT iLD CAbI NRAT DT iLD CALl NRAT DT lbo CAll I NRAT DT VAbUE 155.597 12.236 65.709 114.399 178.649 12.078 67.774 119.003 131.826 12.316 69.591 117.072 133.045 12.038 63.311 11t.795 197.697 11.879 44.483 117.815 147.231 12.1.57 58.689 115.]40 169.044 12.276 53.403 116.132 263,027 1,2.078 54.311 131.724 255.S59 12.157 73.225 lt0.931 307,610 12,236 55.881 134.249 534.584 12.236 50.429 141.179 MNLMUN lC iLM Ol~tto NCNb IbM NC NL IbM D RH 0 ~4CN6 iLM DRHU NC N 6 IbM DRHO NCNb NCNb ibM DRHO NC N ~ IbM DRHU NCNb IbM DRHO NCNb DRHU NCNb l bM DRHO NCNb VAbUE 154.170 0.029 71.500 170.608 0.026 76.200 I 3 1. 826 0,031 88.300 129.420 0.063 72.600 187.068 0.037 50.800 143.219 0.011 80.800 I65.959 0.003 03.200 258.226 0.024 59.300 255.859 0.053 81.400 04.789 0.031 74. lO0 519.996 O.05O 59.200 MNeMONiC 6680 NPHI FCN6 668U NPHI FCNb 668U NPH 1 FCN6 6680 NPHi FCNL 668U NPHI FCNL bbBU NPHI FCNb 6680 NPHi FCNb 668U NPHI FCNb 6680 NPHi ~CNL bL8U NPHI FCNL 6680 NPHI ~'CNb VALUk 144.544 0.000 13.333 149.908 0.000 13.300 133.045 0.000 13.500 130.b17 0.000 13.300 175.388 0.000 13.133 138.038 0.000 13,233 148.594 0.000 13.500 224.905 0.000 13,007 231.206 0.000 13.200 248.886 0.000 13.461 409.261 0.000 13.500 2900.000 2800.000 2700.000 2600.000 2530.000 MNLMONIC SP GR SP GR RHOB GR SP GR GR 8P GR RHOS GR 8P GR RHOB GR VALUE 70.586 64.400 2.275 14.733 72.58] 69.800 2.249 15.067 ;7.575 0.000 2.501 8.0O0 80.820 0.000 2.501 8.000 58.605 0.000 2.501 8.000 MN EMUNiC ILD CALl NRAT DT CALl NRAT DT CALl NRAT DT IbD CALl NRAT DT IbD CALI NRAT DT VA 28 1 5 12 LIJE 8.403 3.624 2.412 3.210 14 57 134 0 0 -1 65 0 0 -1 'l 4 0 0 -1 76 .228 .021 .863 .645 .006 .657 .521 .840 .006 .657 .521 .354 .006 .657 .604 .730 MNk, MONiC IL~ DRHU NCNb IbM DRHU NCNb DRHD NCNb NCNb DRHO t~CNb VAbUk 280.543 0.047 b3.700 307.610 0.004 66.200 343.558 0.000 0.000 343.558 0.000 0.000 343.558 0.000 0.000 bLeU NPHI FCNb bbSO NPHi f'CNb bbSU NPHI FCNb NPMI FCNL bbSU NPHI FCNL VALUE 283.139 0.000 15.033 242.103 0.000 14.333 580.164 0.000 8.000 580.764 0.000 8.000 580.764 0.000 8.000 SUMMAF~¥ [l~ DATA P~ECUb~D6 NIJMBI~ {]~ RI£CURD$: i~ENGI'H OF RECU~D,5: 966 BYqI:E$ ~'ILE LgNG'r~: 62 BYTES FiLg NAME: kDiT .OOl MAXIMUM PHYSICAL RECLIRD LENG~H: NEXT FILE NAMk: EOF TAPE TRAihER LENGTH: 132 TAPE NAME: 53152 SERVICE NAME: EDiT TAPE CONTINUATION NUMBER: 01 NEXT TAPE NAMe: COMMENTS: 1024 DATg: 79/10/31
