Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
176-038
· #¿ /~*~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM SSION WELL COMPLETION OR RECOMPLETION REPORT AND L~ska Oil & Gas Cons. Commission Anchorage RECEIVED SEP 2 9 2006 1 a. Well Status: DOil DGas D Plugged 181 Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory 181 GINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic 181 Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/2/2006 176-038 306-258 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 05/08/1976 50-029-20210-00-00 4a. Location of Well (Governmental Section): 7. Date ToO. Reached 14. Well Name and Number: Surface: 07/10/1976 PBU NGI-07 216' FNL, 989' FWL, SEC. 12, T11N, R14E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 268' FNL, 1032' FWL, SEC. 12, T11N, R14E, UM 47' Prudhoe Bay Field 1 Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 272' FNL, 1042' FWL, SEC. 12, T11N, R14E, UM 7398 + Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 687182 y- 5972100 Zone- ASP4 8645 + 8644 Ft ADL 028302 TPI: x- 687227 y- 5972049 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 687237 y- 5972045 Zone- ASP4 2139' MD DYes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1900' (Approx.) 21. Logs Run: OIL, BHC, GR, CFD, CNL, Caliper, CBL, VOL, CCL 22. CASING, LINER AND CEMENTING RECORD . SETTING DEPTH MD SETTING DEPTH ¡Yb HOLE , ........ AMOUNT .' SIZE. Wr;PERFT. GRADE Top BOTTOM Top BOTTOM SIZE ..' . PULLED 20" 94# H-40 Surface 81' Surface 81' 32" 240 sx Arctic Set (ADDrOX.) 13-3/8" 72# MN-80 Surface 2725' Surface 2724' 17-112" 4800 sx Permafrost II 9-5/8" 47# MN·80 x S·95 Surface 7735' Surface 7734' 12-1/4" 750 sx Class 'G', 275 sx Permafrost" 7" 29# N-80 7446' 8639' 7445' 8639' 8-1/2" 250 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 124. '. ~. i'/ .ii. i< >. i<' ..... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 7" x 5-1/2", 29# X 17#, L-80 7436' 7399' MD TVD MD TVD (Chemically Cut at 3024') 25. Ad[)....· ..... ;;.. .1:1'2,» .. > ........ .' .' > .. ...\t,it.::C" c DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERiAl USED &./ ':.j/l;t'!t·,"<·;;",.,,, 7398' P&A with 50 Bbls Class 'G' 26. PRODUCTION TEST Date First Production~* ,.. . Method of Operation (Flowing, Gas Lift. etc.): Not on Injection N/A Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BsL CHOKE SIZE GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED OIL -BSl GAs-McF WATER-BsL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil. gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS BFt 0 Ci 0 3 2006 None Form 10-407 Revised 12/2003 . t CONTINUED ON REVERSE SIDE ORIGlr~A\L G', 28. GEOLOGIC MARKER 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Sadlerochit 8173' 8173' None Base of Sadlerochit 8588' 8587' 30. List of Attachments: Well Schematic Diagram and Pre-Rig Summary. 31. I hereby certify that the foregoing is true ançl correct to the best of my knowledge. Signed Sondra St Title Technical Assistant Date ~q - ZZ- OCp PBU NGI-07 Well Number 176-038 306-258 Permit NO.1 A roval No. Prepared By NameINumber: Drilling Engineer: Sondra Stewman, 564-4750 Barbara Lasley, 564-5126 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only TREE = GRA Y GEN 2 WELLHEAD = GRA Y ACTUA TOR = AXELSON KB. ELEV = 4T BF. ELEV = ? KOP = 2900' Max Angle = 2 @ 8200' Datum MD = 8849' SS Datum lVD = 8800' SS . NGI-07 . 113-3/8" CSG, 72#, N-80, 10 = 12.347" I Minimum ID = 4.455" @ 7424' OTIS XN NIPPLE IT' TBG, 29#, L-80, .0371 bpf, 10 = 6.184" H 1 TOP OF 51/2"1BG I 15-1/2" 1BG, 17#, L-80, .0232 bpf, 10 = 4.892" I 7436' 19-5/8" CSG, 47#, N-80, 10 = 8.681" I I TOP OF 7" LNR I 7446' PERFORATION SUMMARY REF LOG: BHCS ON 05/10176 A NGLE AT TOP PERF: 2 @ 8032' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8032 - 8090 S 09/03/06 3-3/8" 4 8094 - 8138 S 09/03/06 3-3/8" 4 8176 - 8201 S 09/03/06 3-3/8" 4 8201 - 8220 S 09/03/06 3-3/8" 4 8245 - 8260 S 09/03/06 3-3/8" 4 8288 - 8305 S 09/03/06 3-318" 4 8330 - 8342 S 09/03/06 3-318" 4 8350 - 8446 S 09/03/06 3-3/8" 4 8458 - 8464 S 09/03/06 3-3/8" 4 8464 - 8534 S 09/03/06 I 7" LNR, 29#, N-80, .0371 bpf, 10 = 6.184" I 8640' I TO H 8645' DATE 07/15/76 04/08/83 03/17/06 03/23/06 03/27106 08/27/06 REV BY COMMENTS ORIGINAL COM PLErION LAST WORKOVER KSBITLH FISH PULLED (03/12/06) DFRlPJC IBP SEr @ 7423' RPl-VPJC WAIVER SFTY NOTE DELETED GJF/PAG PULL BKR IBP OTE: THIS IS THE FIELD NGL DISPOSAL 2139' -- 7" OTIS RPB SSSV NIP, 10 = 5.963" I 3024' -- CHEMCUT(09/11/06) I -19-5/8" X 5-1/2" BAKER FB-1 PKR I 7424' -15-1/2" OTIS XN NIP, 10 = 4.455" I -15-1/2" WLEG I HELM TT LOGGED 06/30/90 I 8530' SLM - PBTO (CORRECTED 09/03/06) I DA TE REV BY COMMENTS 09/03/06 PBS/PA P&A 09/11/06 TEL/TLH CHEM CUT & FISH 09/15/06 TEL/TLH TBG PUNCH & TOC (09/07106) PRUDHOE BA Y UNIT WELL: NGI-07 ÆRMIT No: 1760380 API No: 50-029-20210-00 SEC 12, T11N, R14E, 4237.14' FEL & 272.21' FNL BP Exploration (Alaska) Digital Wellfile . Page 1 of 4 . Well Events for SurfaceWell - NGI-07 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS1 -> NGI -> NGI-07 Date Range: 22/Mar/2006 to 28/Sep/2006 Data Source(s): DIMS, AWGRS Description No summary information available in DIMS Run EZSV, Tst Csg, Chg & Test Rams, RIH cut 95/8", Cir out Artic Pac, POH, Disp Seawater Test Pipe Rams, Set Wear Bushing, Csg. Scpr. Run, Run Junk basket, Run USIT Test BOPE's, Pull TWC, Pull 7" tubing hanger, CBU, L/D 7" tubing, Flush stack RID freeze protect displacement lines, N/D XMAS tree/ repair bridge crane, N/U BOPE'S, Test BOPE's Finish rigging up over NGI-07A, Test tubing, IA & OA, pull BPV, RlU test manifold to displace MW, Test all lines & valves, Displace 60/40 MW freeze protect out of well Move Rig from DS15-39A => NGI-07A Rig released from 15-39A at 15:30 hrs. Pull out all modules P/U matting boards and herculite. SET BPV , PRE RIG T/I/O=vac!vac/O+. Temp=SI. WHPs (pre BPV,RIG). STRING SHOT FROM 3009' - 3025' WITH 3 STRANDS 80 GRAIN PRIMA CORD. LOST 6' OF 1-1/2" STRIP AND 1-11/16" BULLNOSE FROM BOTTOM OF TOOL. CHEMICALLY CUT 7" TUBING WITH 5-1/2" CUTTER AT 3024'. USED 2x 5-1/2" ANCHOR BODIES AND 3 CENTRALIZERS. ***Job complete*** AWGRS NGI-07 09/10/2006 Continued from 09-09-06 Circ out (Pre RWO) Rig down LRS 46 AWGRS NGI-07 09/09/2006 T/I/O=400/480/0 Circ out well (Pre RWO) Pumped 10 bbls methanol, 672 bbls 9.8 Brine, 137 bbls 60/40 methanol. Down Tbg, Let U-Tube 1 Hr. Bleed FWHP=0/0/100 AWGRS NGI-07 09/07/2006 WELL SHUT IN ON ARRIVAL. SHOT MEDIUM TUBING PUNCHER FROM 7378' - 7383'. FOUND TOP OF CEMENT AT 7398' CORRECTED TO SLM TAG DEPTH. NO PROBLEMS RIH OR POOH. FINAL T/ 1/ 0 = 500/500/ O. PSI. JOB COMPLETE. AWG.RS NGI-07 09/07/2006 ** WELL SHUT IN UPON ARRIVAL ** {pre rwo} SET 7" KEYLESS DSSSV SAT @ 2115' SLM. UNABLE TO GET MIT-T, IA TRACKING. PULL DSSSV BACK OUT & PERFORM CMIT TxIA TO 2500 PSI-PASSED.START T/I/O-2620/2550/0, 1st 15 MIN T/I/O- 2550/2550/0, 2nd 15 MIN T/I/O- 2530/2550/0. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** AWGRS NGI-07 09/06/2006 ** CONT FROM 9-5-06 WSR** (pre rwo) DRIFTED W/ 2' STEM, 3.80" CENT, SAMPLE BAILER TAG TOC @ 7398' SLM. SAMPLE BAILER CAME BACK EMPTY. CMIT TO 3000 PSI-FAILED ON 3 ATTEMPTS. BLED T/I/O BACK TO 1000/1000/0. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** ** WELL SHUT IN UPON ARRIVAL ** {pre rwo} DRIFTED W/ 5.88" DRIFT W/ SAMPLE BAILER TO 7378' SLM. ** CONT ONTO 9-6-06 WSR** ***CT-9** Continued from WSR 9-2-06 Continue RID ****Job Complete***** Plug and abandon Perfs ***CT-9*** continued from 9-1-06. RIH w/Cmt nozzle assembly, couldn't enter 7" liner. Change BHA. RIH. Dry tag TD at 8635' ctmd. PUH 10', correct to 8620' (ELM) and flag pipe. Well took influx of gas, got 3.5: 1 at 40 bbl OT. Re-kill well and cap with 250 bbls diesel. Pump 50 bbls 15.8 ppg "G" cement. Est TOC at 7200'. Contaminate and clean out to 7390'. Freeze protected to 2500' w/50/50. SSSV & BOP's jetted. Well S/I with 495 psi on Tubing. ***Continued on 9- 3-06 WSR**** Continue L&K w/ CTU. Offload excess 75 bbls 1% KCL PM. CTU #9. MIRU, M/U Cmt'g nozzle assembly. Kill well / RIH for Cmt job. Continued on ****WSR 9-2-06**** LOAD & KILL JOB. Assist Coil Plug and abandon perfs (Side Track) Pumped 15 bbls diesel to pressure up IA to 500 psi Continued on 9-02-06 T/I/O=SSV/1910/280. Temp=S!. TBG & IA FL (pre Coil). Unable to get SSV open due to work being done on pad. IA FL @ surface. IBP MONTHLY RENTAL FOR 06/23/06 - 08/23/06. MO 4 & 5. NOTE IBP SET 03/23/06 Events Source Well Date mMS NGI -07 09/28/2006 DIMS NGI-07 09/27/2006 DIMS NGI -07 09/26/2006 DIMS NGI -07 09/25/2006 DIMS NGI-07 09/24/2006 DIMS NGI-07 09/23/2006 DH':'!S NGI-07 09/22/2006 DJMS NGI-07 09/21/2006 AWGRS NGI-07 09/12/2006 AWGRS NGI-07 09/11/2006 8WGR5 NGI -07 09/10/2006 AWGRS NGI -07 09/05/2006 AWGRS NGI -07 09/03/2006 AWGRS NGI-07 09/02/2006 AWGRS NGI -07 09/02/2006 AWGRS NGI-07 09/01/2006 AWGRS NGI -07 09/01/2006 AWGRS NGI-07 08/30/2006 AWGRS NGI -07 08/29/2006 http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 9/28/2006 Digital Wellfile . . Page 2 of 4 NOTE: IBP PULLED 08/28/06 AWGRS NGI-07 08/28/2006 *** CONT FROM 08-27-06 WSR *** ( pre p&a rwo) DRIFTED W/ 3.50 CENT, TEL & SAMPLE BAILER, TAG HARD BOTTOM 8530' CORR ELMD (8516' SLM) (BTM PERF 8534'- 4' FILL), EMPTY BAILER RAN SBHPS PER PROGRAM (SEE DATA TAB). *** WELL LEFT SI *** AWGRS NGI-07 08/27/2006 ***WELL S/I ON ARRIVAL *** (pre p&a/ rwo) DRIFTED W/ 5.97" G-RING TO TOP OF DSSSV. PULLED DSSSV @ 2114' SLM. EQUALIZED & PULLED 3" BAKER IBP FROM 7405' SLM, ( BOTH ELEMENTS RECOVERED) *** JOB IN PROGRESS/ CONT ON 08- 28-06 WSR *** AWGR$ NGI-07 07/17/2006 T/IA/OA = SI/0/125 PPPOT-IC = PASSED PPPOT-T = PASSED Bled casing hanger packoff void to 0 psi. Functioned lockdowns screws, rigged up test equipment, pressured up void to 3,800 psi. for 30 mins. = Passed Bled tubing hanger void to 0 psi. Functioned lockdown screws, rigged up test equipment and tested to 5,000 psi. for 30 mins. = Passed AWGRS NGI-07 06/23/2006 IBP MONTHLY RENTAL FOR 04/23/06 - 06/23/06. MO 2 & 3. NOTE IBP SET 03/23/06 AWGRS NGI-07 05/14/2006 T/I/O=SSV/720/330. LNFT-IA - PASSED. (New Waiver). IA FL near surface. Bled lAP from 720 psi to 0+ psi in 1 hr (1.5 bbls). During bleed OAP decreased 50 psi. Opened IA bleed to calibrated bucket, no liquid returned for 10 min. Final WHP's = SSV/0+/280. ** CONT FROM 5-12-06 WSR** RIG DOWN S/L. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** T/I/O = 3000/750/350. WSR Continued 5/12/06. Final WHP's = 3000/750/350. T/I/O = 3850/880/350. MIT T to 4600 psi. (PASSED). AOGCC witness wavered by Chuck Scheve, witnessed by BP rep. Marvin Zimmer and Danny Felder. Pumped .5 bbls meoh to achieve test pressure. Lost 0 psi in the 1st 15 min and 10 psi in the 2nd 15 min, for a total loss of 10 psi in 30 min. Bled back to 3000 psi. Final WHP's = 3000/750/350. AWGRS NGI-07 05/12/2006 ** WELL SHUT IN UPON ARRIVAL ** {secure well} PULLED 7" DSSSV @ 2106' SLM. SET 7" DSSSV (COLLETTS-NO LOCK, 2 STACKS PKG TOP W/ 2 DOWN -4 UP,BTM 4 DOWN -WI 2 UP) @ 2106' SLM. MIT-TTO 3800 PSI, GOOD TEST W/ TRI-PLEX, GET PUMP TRUCK TO TAKE UP TO 4600 PSI. LRS MIT-T TO 4600 PSI, GOOD TEST. ** CONT ONTO 5-13-06 WSR** AWGRS NGI-07 05/11/2006 ***Continued AWGRS from 5-10-06*** TjljO=200/250jO MIT T to 4600 psi (FAILED) MIT OA to 4600 psi (PASSED) (PC waiver compliance) Pressured up TBG to 4600 psi with 5.5 bbls neat methanol. First test MIT T lost 375 psi in 1st 15 minutes and 275 psi 2nd 15 minutes. For a total of 650 psi in 30 minutes. IA increased by 250 psi in 30 minutes. Second test MIT T lost 300 psi in 1st 15 minutes and 250 psi 2nd 15 minutes. For a total of 550 psi in 30 minutes. IA increased by 300 psi in 30 minutes. Bled TBG pressure to 200 psi. Pressured up OA to 4600 with 3 bbls neat methanol. MIT OA lost 220 psi in 1st 15 minutes and lost 30 psi 2nd 15 minutes. For a total of 250 psi in 30 minutes. Bled OA pressure to 0 psi. Final WHP's=500j580/0 AWGRS NGI-07 05/11/2006 ***Continued AWGRS from 5-10-06*** T/I/0=200/250/0 MIT T to 4600 psi (FAILED) MIT OA to 4600 psi (PASSED) (PC waiver compliance) Pressured up TBG to 4600 psi with 5.5 bbls neat methanol. First test MIT T lost 375 psi in 1st 15 minutes and 275 psi 2nd 15 minutes. For a total of 650 psi in 30 minutes. IA increased by 250 psi in 30 minutes. Second test MIT T lost 300 psi in 1st 15 minutes and 250 psi 2nd 15 minutes. For a total of 550 psi in 30 minutes. IA increased by 300 psi in 30 minutes. Bled TBG pressure to 200 psi. Pressured up OA to 4600 with 3 bbls neat methanol. MIT OA lost 220 psi in 1st 15 minutes and lost 30 psi 2nd 15 minutes. For a total of 250 psi in 30 minutes. Bled OA pressure to 0 psi. Final WHP's=500j580/0 AWGBS NGI-07 05/10/2006 MIT T to 4600 psi (PC waiver compliance) ***Continue AWGRS on 5-11-06*** AWGRS NGI-07 05/10/2006 *** CONT FROM 05-09-06 WSR *** (trblsht, ibp, dsssv) MIT-T TO 3500# ( PASSED). SUSPECT CONTROL LINE PROBLEM IN TREE. CONTROL LINE TRACKED TUBING PRESSURE IMMMEDIATELY WHEN MIT-T WAS DONE. BALANCE LINE TRACKED IA. NOTE: C/L & B/L WERE BLOCKED @ TREE ON ARRIVAL. RDMO AWGRS NGI-07 05/09/2006 *** WELL SI ON ARRIVAL *** TAGGED TOP OF IBP W/ 3.50 CENT & 3.25 LIB @ 7399' SLM ( IMPRESSION OF F.N). IBP DOES NOT APPEAR TO HAVE MOVED *** JOB IN PROGRESS/ CONT ON 05-10-06 WSR *** AVVGRS NGI-07 05/09/2006 *** Continued from 5-08-06 WSR*** MIT T FAILED to 4600 psi. (PC Leak Waiver) Pressured up Tubing wi 21.5 bbls neat. 1st test lost 1400 psi in 15 min, 2nd 15 min lost 880 psi with a total of 2280 psi in 30 min test. Bleed down all pressures. Final WHP's= 10/220/50 AWGRS NGI-07 05/13/2006 AWGRS NGI-07 05/13/2006 AWGRS NGI-07 05/12/2006 http://digitalwellfile. bpweb. bp.comIW ellEvents/Home/Default.aspx 9/2812006 Digital Wellfile . . Page 3 of 4 AWGRS NGI-07 05/08/2006 T/I/O= 0/40/30 MIT T to 4600 psi (PC Leak Waiver) ***Continued on 5-9-06 WSR*** AWGRS NGI-07 05/08/2006 T/I/O= 25/55/30. Temp= 51. Bleed tubing pressure to 0 psi (re-set BPV, PT tree). Injection line is blinded & 0+ psi on line. 3" integral on IA casing valve. Bled tubing pressure from 25 psi to 0 psi in 30 minutes. During bleed lAP decreased 5 psi. Monitored for 30 minutes. Tubing pressure increased 5 psi. Continued to bleed tubing pressure until valve crew shows up on location. Final WHP's= 0/50/30. AWGRS NGI-07 05/08/2006 SIMOPS with Schlumberger slickline unit on NGI-08. Rig up valve shop BPV lubricator. Set Gray BPV. Set PT dart into BPV. Pressure test tree to 4000 psig with diesel using small tri-plex. 15 minute PT Pass. Pull dart. Pull BPV. Rig down lubricator. Turn well over to fullbore for MIT-IA. AWGRS NGI-07 05/06/2006 T/I/0=1+/72/18. Temp=SI. Bleed TP, assist Valve Shop (for Wellhead Repair). Injection line P=l+ psi. Bled TP from 1+ psi to 0 psi in 3 minutes. Bled Injection line P from 1+ psi to 0 psi in 5 minutes. Assist Valve Shop as needed w/tree repair. Final T/I/0=0/72/18. AWGRS NGI-07 05/06/2006 SET BPV FOR TREE REPAIR, PULLED BPV WHEN THJE JOB WAS DONE AWGRS NGI-07 05/05/2006 T/I/O= 780/620/80. Temp= 51. Bleed Tubing <300 psi (PC leak waiver, pre-wing repair). TP decreased 40 psi, lAP decreased 50 psi and OAP unchanged overnight. Initial Tbg FL @ 426' (15.8 bbls). Bled TP and flowline from 780 psi to 130 psi in 120 minutes. 51 master valve and continue bleeding flowline from 130 psi to 0 in 60 minutes. SI wing valve and opened master. Tbg pressure fell off 30 psi during flowline bleed. Indicating that the master valve was leaking by. Bled TP from 100 psi to 0 psi in 100 minutes. SI master and opened wing to check for pressure build up in flowline. Flowline pressure had increased to 5 psi during Tbg bleed. Bled flowline to o psi. Notified valve crew and DSO that the lateral valves on the flowline may be leaking by. IA has a 1502 integral flange. Final WHP's= 0/80/22. T/I/O=820/670/80. Temp=SI. WHP's & TBG FL. (PC leak waiver, Pre-wing repair). TBG FL @ 420' (16 bbl). Integral flange installed on IA casing valve. T/I/O= 1060/940/280. Temp= SI. Bleed tubing < 500 psi (PC leak waiver, pre-wing repair). Rig camp in wind direction, unable to bleed tubing pressure. T/I/O= 1120/940/300. Temp= SI. WHP's (post-blind). Tubing pressure decreased 440 psi. lAP decreased 310 psi. OAP decreased 130 psi. T/I/0=1560/1250/430, Temp=SI. Bleed TBGP < 2000 psi (PC leak waiver) problem well day 27. TBG FL @ 426' (16 bbls), IA FL @ Surface. Lateral line blinded @ lateral valve. Did not bleed TBGP. TBGP decreased 180 psi, lAP decreased 440 psi, OAP increased 180 psi from 4-13-06. Balance line = 1500 psi, Controlline= 1100 psi. S- riser= 3700 psi. AWGRS NGI-07 04/13/2006 T/I/0=1740/1690/250. SI. WHP's TBG FL (Post bleed & MIT-T). S-riser=3880 psi. TBG FL @ 252' (9 bbls). TBG pressure increased 30 psi, lAP increased 30 psi, OAP increased 180 psi and S-riser increased 280 psi overnight. AWGRS NGI-07 04/12/2006 T/I/0=1710/1660/70. 51. WHP's TBG FL (Post bleed & MIT-T). S-riser=3600 psi. TBG FL @ 234' (9 bbls). 8WGRS NGI-07 04/12/2006 ***Continued from 4-11-06 WSR*** T/I/O= 500/150/0 Temo=S/I MIT T FAILED to 4600 psi. Pressured up the tubing w/ 64 bbls 60/40 meth. 1st test lost 1280 psi in 10 rninutes. MIT OA PASSED to 4000 psi. Pressured the OA to 4000 psi w/ 6.8 bbls 60/40 meth. 1st test lost 350 psi in 15 min, 2nd 15 min test lost 30 psi with a total of 380 psi in 30 minutes. Bled OA to 0 psi. Final WHP's= 1400/1350/0 AWGRS NGI-07 04/11/2006 T/I/O= 500/150/0 Temp=S/1 MIT T to 4600 psi. (POST IBP) *** Continue on 4-12- 06 WSR*** AWGRS NGI-07 04/11/2006 T/I/O=1280/610/0+. Temp=SI. Bleed WHP's & S-riser <500 psi (eval IBP & Wing holding) problem well day 18. T FL @ 1944' (75 bbls). Flowline P @ 3900 psi. TP increased 40 psi, lAP increased 90 psi, OAP remained the same, Flowline P increased 2660 psi overnight. Bled TP from 1280 psi to 350 psi in 1 hour, 40 minutes (all gas). lAP decreased from 610 psi to 100 psi during TP bleed. Flowline P remained the same during TP bleed. Bled Flowline P from 3900 psi to 40 psi in 2 hours, 30 minutes. TP increased from 350 psi to 400 psi during Flowline bleed. lAP & OAP remained the same. Monitored 15 minutes. TP, lAP & OAP remained the same. Flowline P increased from 40 psi to 130 psi during monitor. **Note** Changes in T FL may be due to a lack of jewelry to estimate speed changes due to pressure / density changes, requiring the use of a 600 fps standard. IA integral installed. Slop trailer bull-plug was handy w/3 threads in. Final T/I/0=400/100/0+. 8wGR,S NGI-07 04/10/2006 T/I/O/Riser = 3900/2220/0+/3900. Temp = 51. Bleed WHP's & Riser < 500 psi (eval 8wGRS NGI -07 05/04/2006 AWGRS NGI -07 04/25/2006 AWGRS NGI -07 04/21/2006 8WGRS NGI-07 04/20/2006 http://digitalwellfile. bpweb. bp.comIW ellEvents/Home/Default.aspx 9/28/2006 Digital Wellfile ., I J, . Page 4 of 4 . IBP or wing holding) prob well day 14. TBG FL @ 1200'. IA & OA FL @ surface. Bled TBGP and Riser pressure (simultaneously) from 3900 psi to 2740 psi in 1.75 hrs. Monitored for 30 mins. TBG/riser pressure increased 20 psi. Monitored 30 more mins. TBG/riser pressure unchanged. Bled TBG/riser pressure from 2760 psi to 1200 psi in 3.25 hrs. TBG FL dropped 1425' to 2625'. lAP decreased 1700 psi, OAP unchanged during bleed. Monitored 30 mins during RD. TBG/riser pressure increased 40 psi. FWHPs = 1240/520/0+ 8WG,RS NGI-07 04/09/2006 T/I/O/s-riser = 3940/2290/10/3960. Temp = SI. WHPs and s-riser (eval IBP or wing holding). S-riser pressure is 20 psi above TBGP making it uncertain as to whether or not the IBP is holding pressure. TBGP increased 900 psi, lAP increased 720 psi, OAP unchanged overnight. AWJ:iRS NGI-07 04/08/2006 T/I/O=3560/1660/10 Temp=S/1 Bleed WHP's and S-riser<500 psi(Eval IBP or wing leaking) Tubing FL=1200'. IA & OA FL's at surface. Bleed TBP to tank from 3560 to 2900 psi in 40 min but TBP would start to climb as soon as bleed was shut in. S-riser = 3600 psi. Swap bleed to S-riser and bleed to 2400 psi. TBP increased 140 psi during re-rig up to S-Riser. TBP remained at 3040 psi and Inj. line increased to 2700 psi and climbing. Indicating a leak from lateral valve. lAP dropped to 1570 psi during TBP bleed. FWHP=3040/1570/10. AWGRS NGI-07 04/03/2006 T/I/O=3850/2500/10, Temp=SI. TBG, IA & OA FL's (pre MIT's). TBG FL @ 1158' (43 bbls), IA FL @ Surface, OA FL @ Surface. TBGP increased 30 psi, lAP remained unchanged, OAP remained unchanged from 4-1-06. IA has integral flange. T/I/O= 3820/2540/10. Temp= SI. Monitor WHP's (Post Oper Bleed) Call in. TP decreased 20 psi, lAP and OAP unchanged overnight. IA has an integral flange. TIO = 3840/2540/10. Temp = SI. Monitor WHP's (Post bleed, for secure). T/I/O=3800/2700/10. Temp=SI. Monitor WHPs (post Oper. Bleed). T/I/O=3260/2830/10. Temp=SI. WHPs post-bleed. TBGP increased 110 psi, lAP increased 1530 psi, no change in OAP over night. T/I/O=2250/2250/10. Temp=SI. Bleed lAP, TBG & IA FL's, (post MIT). TBG FL @ 276' (10 bbls). IA FL @ surface. Bled lAP from 2250 psi to 170 psi in 30 min, TP decreased 50 psi during IA bleed. Monitored for 30 min, lAP increased 1130 psi and TP increased 20 psi. Final WHP's=2220/1300/10. (Note: grease crew tried to grease lock wing valve, wing valve is not holding). AWGRS NGI-07 03/25/2006 T/I/O=600/600/0 MIT TBG to 4600 psi=FAILED. Pressure IA to 3000 psi with 3.4 bbls neat. Pressured Tbg to 4600 psi with 8.1 bbls neat. T/I pressure losses every 15 min.=830 psi! 200 psi, 450 psi! 20 psi, 140 psi! 100 psi, 30 psi! 80 psi. Bled TBG pressure down IA pressure was tracking. Final WHP= 500/700/50 AWGRS NGI-07 03/24/2006 T/I/O=2220/2210/30. Temp=SI. Bleed TBG & lAP below 300 psi. Initial TBG FL @ 1722', IA FL near surface. Bled lAP from 2210 psi to 160 psi in 1 hr (fluid & gas mix) (11 bbls). During IA bleed the TBGP dropped from 2220 psi to 1340 psi. Bled TBGP from 1340 psi to 180 in 1.5 psi hrs (all gas). SI monitor, lAP increased 10 psi during monitor. Final WHPs.180/170/30. AW.J;ì.RS NGI-07 03/24/2006 T/I/O= 2160/2210/30. Temp= SI. Tubing FL, (pre-Mm). Tubing FL @ 1722' (64 bbls). AWGRS NGI-07 03/23/2006 T/I/O=400/150/0 Assist Slickline MIT-T (Update to new waiver policy) Pumped 7.8 bbls DSL to pressure up to 3000 psi. MIT-PASSED on fifth attempt. Lost 100 psi in first 15 minutes, 50 psi in the second 15 minutes. FWP's= 1000/150/0 AWGRS NGI-07 03/23/2006 ***WELL SHUT IN UPON ARRIVAL*** {pre mit} SET 7" DSSV @ 2106' SLM, { COLLETTS, NO LOCK W/ 2 STACKS PKG} PRE- MIT -3000# GOOD. *** WELL LEFT SHUT IN****PRE-MIT. SET BAKER 3" IBP MID ELEMENT 7422.5' MID 10' PUP. 1.75" FISHING NECK LOCATED 7415' WITH TWO 6" SEALS. WELL SHUT IN T/I/O=1900/275/0 Load TBG for E-Line IBP Set (reg. compl) (Shut In) Loaded TBG w/ 10 bbls 60/40 meth, 453 bbls 1% KCL water and 110 bbls 60/40 meth. FWHP's=0/250/0 AWGRS NGI-07 03/22/2006 ***WSR CONTINUED FROM 3-21-2006*** PULLED PRONG FROM 7,386' SLM. PULLED 5 1/2" PX PLUG BODY. ****LEFT WELL SHUT-IN FOR UPCOMING WELL WORK**** AWGRS NGI -07 04/01/2006 AWG_RS NGI-07 03/31/2006 AWGRS NGI -07 03/30/2006 AWGRS NGI-07 03/27/2006 8.\N.GßS NGI -07 03/26/2006 AWGRS NGI-07 03/22/2006 AWGRS NGI-07 03/22/2006 http://digitalwellfile.bpweb. bp.comIW ellEvents/Home/Default.aspx 9/28/2006 . . FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer SP Exploration (Alaska) Inc. PO Box 196613 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PSU NGI -07 Sundry Number: 306-258 r :~~ Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thiS¥- day of August, 2006 Enc!. rt& -D3~ . C(l~ ~"3"'~Þ ~f¿ f / J / tJ6 STATE OF ALASKA I ALASKA Oil AND GAS CONSERVATION COMM ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes 181 No . 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028302 47' Prudhoe Bay Field / Prudhoe Bay Pool · "."'.i' ·i<,./· ...... .(;'i.... '. . i.. ......../,¿/... . ...·.·Xi..······· " .... ...... '·'~,"I.i' .'i.· / ;</.,............./;.'...;/..//.........;;/..).;).....;(; ./ Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8645 8644 I 8640 8639 7423 None Casino Lenoth Size MD / TVD Burst CollaDse Structural Conductor Surface Intermediate Production Liner 13. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for / ) Commencina Ocerations: Septembef1,..2006 17. Verbal Approval: Date~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~e Wesley Title Senior Drilling Engineer Signature ß.:~ >J-- Phone 564-5153 Date ?þ"joro , /I \.../ v Commission Use Only ~~ 1. Type of Request: 181 Abandon o Alter Casing o Change Approved Program o Suspend o Repair Well o Pull Tubing 81' 2725' 7735' 20" 13-3/8" 9-5/8" 1194' 7" Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 8032' - 8534' / 8031' - 8533' Packers and SSSV Type: 9-5/8" x 5-112" Baker 'FB-1' packer ~traE1~ JUL 3 1 2006 Alaska Oil & Gas Cons. Commission A o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Re-Enter Suspended Well o Other 4. Current Well Class: / o Development 0 Exploratory o Stratigraphic 181 Service 5. Permit To Drill Number 176-038 / 6. API Number: 50-029-20210-00-00/ 8. Well Name and Number: PBU NGI-07 / 81' 2725' 7735' 81' 2725' 7734' 1530 5380 6870 520 2670 4760 7446' - 8640' 7445' - 8639' 8160 7020 Tubing Size: / Tubing Grade: Tubing MD (ft): . 7",29# x 5-112",17# L-80 7436' /' I Packers and SSSV MD (ft): 7399' ~.. 14. Well Class after proposed work: o Exploratory 0 Development 181 Service 16. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ / o Plugged OWINJ 181 Abandoned o WDSPL Contact Barbara Lasley. 564-5126 Prepared By Name/Number: Terrie Hubble, 564-4628 I Sundry Number: .." fU. ¿). ~ Conditions of approval: ~otify Commission so that a representative may witness - rØ'PIUg Integrity [ÿ( BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: T-e <; t- fS 0 PE to 4-ðOO V' ~ Subsequent Form Required: \ 0 -(/j /(t¡ V '""-/ OR\G\NAL Approved By: Form 10-403 Revised 06/2006 RBDMS BFL AUG 0 4 2006 COMMISSIONER APPROVED BY THE COMMISSION Date ø-tf_t)b Submit In Duplicate . . 'Obp GL~., To: Winton Aubert - AOGCC Date: July 31, 2006 From: Barbara M. Lasley - BPXA GPB Rotary Drilling Subject: NGI-07 Application for Sundry Approval - P&A for Sidetrack Operations ,,- Approval is requested for the P&A of PBU well NGI-07. Well NGI-07 is an Ivishak gas cap injector currently shut-in due to a slow production casing leak and tubing x inner annulus communication via an SSSV balance line. The well has been shut in and secured with an inflatable bridge plug set at 7,422' MD (3/22/06). NGI-07 was drilled and completed in July 1976 and started injection in June 1977. The original completion was 4 W' tubing and 112' was perforated. A RWO was done in April 1983; the 4 W' tubing was replaced with 7" tubing and a 5 W' tailpipe assembly. The RWO was followed in July with add perfs. NGI-07 was returned to full-time injection. A matrix mud-acid stimulation was done in January 1989. Benefit was limited. Add perfs were shot in June 1990. Well Integrity (WI) issues first surfaced in August 1990 when a possible 9 5/8 casing leak was noted. The leak-off rate was small enough that the well would pass AOGCC test criteria. The well remained on injection. Tubing x inner annulus communication was identified' 99 -1997. The first GX Sealant treatment of the {iSs éÒ trol and balance lines was done in 1998. Chrontd TxlA communication through the SSSV nipple rsiste and is the primary problem at this time. R teâ failure of the SSSV packing has resulted in high A ssure (lAP) requiring frequent bleeds to keep the lAP below maximum allowable pressure (MAP). This / has been managed within Well Integrity guidelines in the past; however, it is becoming more difficult to get the SSSV packing to seal. The plan to repair well NGI-07 includes the following. The existing 7" tubing string will be pulled to -3000' MD. The 9-5/8" casing will be cut and pulled to -2474' MD, above the full opening valve at 2491' MD. An EZSV and whipstock will be run to allow kick of in the 13-3/8" casing at -2450' MD. The well will be drilled to the 12-1/4" TD at 8122' MD. A 9-5/8" production casing will be run and cemented to the window, and freeze protected to surface. The production zone will be drilled to 8717' MD and completed with 7" slotted liner. A 7- /' 5/8" internally plastic coated tubing string will be run for gas injection. The NGI-07A sidetrack is currently scheduled for Nabors 27E beginning the first week of October, 2006. pre-rig work for this sidetrack will be priority scheduled once Sundry approval has been obtained. Estimated Pre-Rig Start: 09/01/06 Estimated Spud Date: 1 &96 The ~j~;Þ4 ~I Rotary Drilling Engineer Office: 564-5126 Cell: 240-8044 CC: Well file Terrie Hubble / Sondra Stewman NGI-07 Application for Sundry · . NGI-07 A Operations Summary Current Status: ~ Inflatable bridge plug at 7422' MD. ~ Slow production casing x formation communication. ~ Tubing x inner annulus communication via an SSSV balance line. Pre-Ria Operations: 1. SLlCKLINE: PulllBP at 7422' MD. 2. WIRELlNE: Run static pressure survey to determine BHP for~ro W during drilling operations. 3. COIL TUBING: Plug and abandon the open perforations wit -46 bb s of 15.8 ppg cement, leaving the TOC just above the 7" x 5-1/2" crossover. Cement volume bas", e following calculations: ~ 1194' of 7" liner (cap. = 0.0371 bbl/ft) = 44.3 bbls ~ 10' of 9-5/8" casing (cap. = 0.0732 bbls/ft) = 0.7 bbls ~ 41' of 5-1/2" tubing tail (cap. = 0.0232 bbl/ft) = 1.0 bbls 4. SLICKLlNE/WIRELINE: Drift tubing to estimated TOC. Tag cement to verify TOC depth. / 5. WIRELlNE: Jet cut the tubing in the middle of the full length tubing joint at -3000' MD. 6. Circulate the well to seawater through the tubing cut until returns are clean. 7. Bleed casing and annulus pressures to zero. Freeze protect to -2,200' MD with diesel. 8. Function all tubing and casing lock down screws. Repair and replace as necessary. Test 9-%" packoff to 5,000 psi for 30 minutes. /' 9. Set a BPV. Remove well house and flow line. Level the pad as necessary. 1 Ria Operations: 1. MIRU Nabors rig 27E. 2. Pull BPV. Circulate out freeze protection and displace the well to seawater. 3. Run and test TWC to 1000 psi ~/".~' 4. Nipple down tree. Nipple up and test BOPE ~o f6~g¡J high, 250 psi low. Pull jt'C. a. Ensure one set of rams are eqUlpþè"ð to close around 7" tubulars. 5. Unseat the hanger. Pull and lay down the 7" tubing from the cut at -3000' MD. 6. Change out 7" BOP rams to accommodate 9-5/8" casing. Test. 7. Rig up E-line. 8. Make up gauge ring / junk basket to drift 9-5/8" casing for EZSV. RIH and tag tubing stump at -3000' MD. POH. 9. Make up USIT / CCL logging tools. RIH. Log from tubing stump to surface. POOH. 10. Pick up 9-5/8" EZSV. RIH and set EZSV above tubing stump at 3000' MD. // 11. Rig down E-line. 12. Make up casing cutter for 9-5/8" 47# casing. RIH to 2474' MD, picking up singles. 13. Cut casing at -2474' MD. Establish circulation behind 9-5/8" casing. POOH. 14. Spear casing. Circulate out Arctic Pack. 15. Pull and lay down 9-5/8" casing. 16. Change rams back to variables. Test. 17. PU 13-3/8" casing scraper and mill assembly. Cleanout to surface shoe at -2700' MD. POOH. LD assy. /' 18. Make up 13-3/8" EZSV on drill pipe. RIH. Set EZSV at 2460' MD. POOH. 19. Test EZSV and 13-3/8" casing to 3500 psi for 30 minutes. Chart test. 20. Pick up and RIH with 13-3/8" Baker bottom-trip anchor whip stock assembly. Shear off. 21. Displace the well to 9.3 ppg milling fluid. ~ ~ ~ N"> ~ ~ c - V' :J \- NGI-07 Application for Sundry , 22. Mill window, pius 20' beyon!e middle ot the window. Circulate well clef 23. Pull up into casing and conduct an FIT/LOT, targeting minimum of 11.0 ppg EMW. POH. 24. Make up 12-1/4" drilling assembly with Dir/GR/Res. RIH. 25. Drill the 12-1/4" intermediate section with 9.3 ppg fluid to -7800' MD, just above the top HRl. 26. Prior to penetrating the top HRl, weight up drilling fluid to 9.6 ppg. 27. Drill ahead to TD in the base HRl at 8122' MD with 9.6 ppg drilling fluid. 28. Condition hole and circulate bottoms up. POOH, lay down 12-1/4" drilling assembly. 29. Change out upper BOP rams to accommodate 9-5/8" casing. Test. 30. Run 9-5/8" 47# production casing with ES Cementer at 6650' MD. 31. Cement production casing in two stages, utilizing the ES Cementer. 32. Change rams back to variables. Test. 33. Make up 8-1/2" drilling assembly with Dir/GR. RIH to the ES Cementer. 34. Test to 4000 psi for 30 minutes, chart same. 35. Drill out ES Cementer. RIH to the landing collar. 36. Test to 4000 psi for 30 minutes, chart same. 37. Drill out the 9-5/8" float equipment and cement to the shoe. 38. Displace the well to 8.6 ppg solids free Flo-Pro drilling fluid. 39. Drill out the shoe plus -20' new formation. 40. Conduct FIT, targeting 10.0 ppg EMW. 41. DrilltoTDat8717'MD. 42. Circulate well bore clean, short trip to shoe, circulate. POH. 43. Pick up 7" slotted production liner. 44. RIH to TD. Set the liner top hanger/packer. Release from the liner. POOH. 45. Change out upper BOP rams to accommodate 9-5/8" lubricator. Test. 46. Rig up E-line, including 9-5/8" lubricator. 47. Run USIT log to confirm cement behind 9-5/8" casing. Rig down E-line. 48. Change out upper BOP rams to accommodate 7-5/8" tubing. Test. 49. Make up and run 7-5/8" internally plastic coated (IPC) completion string. a. Each connection will be torque-turned and externally pressure tested to 4000 psi. NOTE: This is 84% of the connection collapse rating. 50. Reverse circulate corrosion inhibitor and diesel freeze protection. Ensure volume of diesel pumped is equivalent to the annular volume to 2200' MD. 51. Drop the ball and rod. Set the packer and immediately bring tubing pressure up to 4000 psi. Chart this test for 30 minutes. Bleed the tubing pressure to 2000 psi. Increase the annular pressure to 4000 psi. Chart this test for 30 minutes. Notify the AOGCC to witness tubing and annular pressure test. 52. Bleed the annulus pressure to zero. Bleed the tubing pressure to zero. 53. Set and test a TWC to 1000 psi. 54. Change rams back to variables. Nipple down the BOPE. 55. Nipple up and test the tree to 5000 psi. Lubricate out the TWC. 56. Rig up slickline. Pull the ball and rod. Rig down slickline. 57. Bullhead diesel freeze protection fluid down the tubing, sufficient to freeze protect 2200' of 7-5/8" tubing. 58. Secure the well with a BPV. RDMO. Post-RiQ Operations: 1. Set SSSV injection valve. 2. "S" Riser will require modifications to fit new tree. 3. Install well house and instrumentation. NGI-07 Application for Sundry NGI!ft7A Proposed TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= Gray Gen II Gray Axelson 47' ? 2900' 2 @ 8200' 8849' ss 8800' ss I Baker WS for 72# csg, KOP in 13-3/8" l-t 2450' ,I n - ~/t ~EZSV ~vA- I 2460' I 2474' 195/8" OJt 13-3/8" CSG, 72#, N-80, ID= 12.347" -t 2725' Top of 7" Minimum ID = 5,770" @ 7965 7" HES RN NIPPLE TOPOF7" LNRH 7446' 19-518" CSG, 47#, NT-80-S, ID = 8.681"-l 7736' ÆRFORA TION SUMMARY REF LOG: BHCS 05/10/76 ANGLEATTOPÆRF: 8@8032' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 7" LNR, 29#, N-80, .0371 bpf, ID 6.184" 8645' DATE 07/15/76 04/08/83 03/17/06 03/23/06 03/27/26 REV BY COMM8\/TS Original Com pletion Last Workover KSB/TLH Fish pulled (03/12/06) DFRlPJC IBPset at 7423 RPHlPJC Waiver safety note deleted AFETY NOTES: This is the field NGI W!posal well ** 2060' 7 5/8" x 7" XO 7" CAMCO DB SSSV NIP, ID - 6.0" TC-II TO VAM TOPHC X-OVER 7" x 7 518" XO 75/8" 1BG, 29.7#, L-80-IPC, V AM TOP HC, ID = 6.875", 0.04591 BBUFT 6650' 95/8" HES CEMENTER W/ x- aver TC-II TO BTC 7930' I 7940' H 7955' I 7965' H 75/8" x 7" 26# TC-II TO V AM TOP HC XO 7" R Nipple, ID = 5.963" 9 5/8" x 7" Baker S-3 A<r, 7" 26# TC-II, ID = 6.059" 7" RN Nipple, ID = 5.770" 7" HMC Liner hanger/ ZXP 7970' Packer w /10' 1BS (7.5" ID) 26# BTC 7" 26# TC-II WLEG '8 \ \ \ \ \ ~ I 8717' H 95/8" CSG, 47#, L-80, TC-II, ID = 8.681", 0.07321 BBUFT 7" 26# L-80 Slotted PBTD 7" 26# TD DATE PRUDHOE BA Y UNfT WELL: NGI-07A ÆRMfT No: "1760380 API No: 50-029-20210-01 SEC 12, T11N, R14E. 4237.14' FEL & 272.21' FNL REV BY COMMENTS BP Exploration (Alaska) TREE = GRA Y GEN 2 ~E4LH~D = GRAY ACTUA TOR = AXELSON KB. ELEV = 47' BF. ELEV = ? KOP = 2900' Max Angle = 2 @ 8200' Datum MD - 8849' SS Datum 1VD = 8800' SS . 113-3/8" CSG, 72#, N-80, 10 = 12.347" H 2725' J- Minimum ID = 4.455" @ 7424' OTIS XN NIPPLE 7"TBG, 29#, L-80, .0371 bpf, ID=6.184" H 1 TOP OF 51/2" TBG H 7395' 7395' / 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 7436' TOPOF 7" LNR I 19-5/8" CSG, 47#, N-80, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 05/10/76 ANGLE AT TOP ÆRF: 2 @ 8032' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8032 - 8090 0 07/01/90 3-3/8" 4 8094 - 8138 0 07/01/90 3-3/8" 4 8176 - 8201 0 01/11/77 3-3/8" 4 8201 - 8220 0 07/23/83 3-318" 4 8245 - 8260 0 07/01/90 3-318" 4 8288 - 8305 0 07/27/83 3-318" 4 8330 - 8342 0 07/01/90 3-3/8" 4 8350 - 8446 0 07/27/83 3-3/8" 4 8458 - 8464 0 07/01/90 3-3/8" 4 8464 - 8534 0 07/27/83 17" LNR, 29#, N-80, .0371 bpf, ID = 6.184" I 8640' 1 TD H 8645' DATE 07/15/76 04/08/83 03/17/06 03/23/06 03/27/06 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER KSBITLH FISH PULLED (03/12/06) DFRlPJC IBP SET @ 7423' RPHlPJC WAIVER SFlY NOTE DELETED DATE NGI-07 . SAF TE: THIS IS THE FIELD NGL DISPOSAL WELl. 2139' -17" OTIS RPB SSSV NIP, ID = 5.963" I 7395' - 7" X 5-1/2" Xol 7399' -19-5/8" X 5-1/2" BAKER FB-1 PKR I 7423 ELMD - 3" BAKERIBP(03/23/06) I /' 7424' -15-1/2" OTIS XN NIP, ID = 4.455" I REV BY COMMENTS 7436' 7428' -15-1/2" WLEG I HELM TT LOGGED 06/30/90 I PRUDHOE BA Y UNrr WELL: NGI-07 PERMrr No: "1760380 API No: 50-029-20210-00 SEC 12, T11N, R14E, 4237.14' FEL & 272.21' FNL BP Exploration (Alaska) e /{f¿ 0/¢~ e ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 May 22, 2006 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 ::}CA~~Í\~EÜ ._~' ". .;, C1 "" {J Subject: NGI-07 (PTD 1760380) Application for Cancellation of Sundry #303-132 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 303-132. The sundry was for approval to operate the well with TxlA communication and a PC leak. The well will remain shut-in in preparation for a rig sidetrack. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. :;;P~11h Anna Dube, Well Integrity Coordinator Attachments Application for Sundry Cancellation form 10-404 17~ -03 <¡( STATE OF ALASKA MAY 3 0 2006 ALAe Oil AND GAS CONSERVATION COM.ION . REPORT OF SUNDRY WELL OPERATION~lasJca 01' & Gas Cons. Commission o Stimulate 0 Other ../ I Sundry o WaiverD Time Extension 0 o Re-enter Suspended Well 0 5. Permit to Drill Number: 176-0380 6. API Number: 50-029-20210-00-00 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 47 KB 8. Property Designation: ADL-028302 11. Present Well Condition Summary: . i Total Depth measured 8635 true vertical 8634.11 ¡ Effective Depth r ï L , Casing Conductor Surface Production Liner measured 8640 true vertical 8639.11 Length 80 2694 7706 1194 Size 20" 94# H-40 13-3/8" 72# N-80 9-5/8" 47# N-80 7" 29# N-80 Perforation depth: Measured depth: 8032 - 8534 True Vertical depth: 8031.28 - 8533.13 ¡Tubing: (size, grade, and measured depth) L I Packers and SSSV (type and measured depth) J2. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: ¡Copies of Logs and Surveys Run \ ~~ ,~(7)aily Report of Well Operations Oil-Bbl o o x Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG GINJ PI Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic feet feet feet feet MD 32 - 112 31 - 2725 30 - 7736 7446 - 8640 7"29# 5-1/2" 17# 5-1/2" Baker FB-1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Anna Dube / Joe Anders p,;,ted Nam~be r Signatu ~L-~ Exploratory Service 9. Well Name and Number: NGI-07 10. Field/Pool (s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Plugs (measured) 7423 Junk (measured) None TVD Burst Collapse 32 - 112 1530 520 31 - 2724.93 5380 2670 30 - 7735.33 6870 4760 7445.35 - 8639.11 8160 7020 L-80 L-80 30 - 7395 7395 - 7436 7399 RBDMS 8Ft ,¡UN 0 7 2006 Tubing pressure o o Service PI WINJ PI WDSPl Sundry Number or N/A if C.O. Exempt: 303-132 Title Well Integrity Coordinator Date 5/23/2006 Phone 907-659-5102 Form 10-404 Revised 04/200 Submit Original Only . STATE OF ALASKA e ALASKA OlPlND GAS CONSERVATION COMMISSION Mechanical Integrity Test ,---, ..-/\ 1110& ì \trt 'J Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / NGI 05/12/06 Anna Dube pfð.. .......Ih~ ..... .... j..;"" ø -Ât... ....~ \S·\~ ,.",'i.~ illJ::¡- CA· Packer Depth Pretest Initial 15Min. 30 Min. WeIlINGI-07 I Type Inj. I N TVD I 7,398' Tubing 175 500 500 500 Interval! V P.T.D.11760380 I Type test I P Test psi I 1855 Casing 250 580 580 580 P/FI P Notes: Required MIT -OA for Sundry #303-132 OA 100 4600 4380 4350 Weill I Type Inj. I I TVD I Tubing I Intervail P.T.D.I I Type test I I Test psil Casing I P/F! Notes: OA I Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type testl I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing . Interval I p.T.D.1 I Typetestl I Test psil Casing P/F! Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA I TYPE INJ Codes D = Drilling Waist G = Gas 1 ;:: Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1105 TYPE TEST Codes M ;:: Annulus Monitoring P = Standard Pressure Test R;:: Internal Radioactive Tracer Survey A;:: Temperature Anomaly SUlVey 0;:: Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T;:: Test during Workover 0= Other (describe in notes) SCA~'Nfr. ç .._ u 2006-0512_MIT_PBU_NGI-07 _MITOA.xls · STATE OF ALASKA e ALASKA OI~ND GAS CONSERVATION COMMISSION . /(. . I"" Mechanical Integrity Test 'I; /. /~. £:1 (1 Uy e6ï Email to:winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.uS;Jim_Regg@admin.state.ak.us;Tom_MauderJ.admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay 1 PBU 1 NGI 05/12/06 Anna Dube h\J-T - '-,&u?lrJ' Packer Depth Pretest Initial 15Min. 30 Min. WeIlINGI-07 Type Inj. I N TVD I 7,398' Tubing 3,760 4,610 4,610 4,600 Interval I V P.T.D.11760380 I Typetest I P Test psil 1855 Casing 880 990 990 990 P/FI P Notes: Required MIT-T for Sundry #303-132 OA 350 350 350 350 AOGCC representative declined to witness Weill I Type Inj. I I TVD I Tubing Interval I P.T.D.I I Type test I , Test psil Casing P/FI Notes: OA Weill , Type Inj.1 I TVD , Tubing I Interval P.T.D.! I Type test I Test psi I Casing I P/F Notes: OA I Weill I Type Inj.1 TVD I Tubing I Interval p.T.D.1 I Type test I I Test psi Casing ! P/FI Notes: OA I Weill I Type Inj.1 , TVD I Tubing Interval' P.T.D.I , Typetestl I Test psi! Casing P/FI Notes: OA I TYPE INJ Codes D = Drilling Waist G = Gas ! :::; Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R:::; Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) ~CANNEr> JUN 'j i;; 2006.0512_MIT _PBU _NGI-07 _MITT xis RE: NGI-07 e 4-'> ~$- J7Ç;;, '-035 Hi Jim, The wing valve on NGI-07 was found to be leaking by. The line has been blinded in preparation for the wing valve to be replaced, hopefully this week. The DSSSV will also be changed out to address the slow TxIA communication. Once this is complete, plans are to re-MIT the tubing. An AOGCC inspector will be notified. The well remains shut-in and secured with an IBP. Please let us know if you have any questions. Thank you, Anna Dube -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Friday, April 14, 2006 3:47 PM To: NSU, ADW Well Integrity Engineer Cc: Winton G Aubert; Louis R Grimaldi Subject: NGI-07 ~ Inspector witnessed MIT on NGI-07 on 3/19/06; results of the test were inconclusive and he requested fluid level shot (copy of inspection rpt attached). Results of fluid level? The well is currently covered by sundry approval 303-132 for IAxOA communication; requires annual MITOA, and MITT every 4 years. Email dated 4/1/06 reported the well is exhibiting signs of TxIA communication with 2540 psi in the IA. What is BP's plan for this well? Is it shut-in/secured or continuing to inject? Jim Regg AOGCC 1 of 1 4/26/2006 1: 16 PM NGI-07 e e Pm l7b-Q3B Inspector witnessed MIT on NGI-07 on 3/19/06; results of the test were inconclusive and he requested fluid level shot (copy of inspection rpt attached). Results of fluid level? The well is currently covered by sundry approval 303-132 for IAxOA communication; requires annual MITOA, and MITT every 4 years. Email dated 4/1/06 reported the well is exhibiting signs of TxIA communication with 2540 psi in the IA. What is BP's plan for this well? Is it shut-in/secured or continuing to inject? Jim Regg AOGCC Content-Type: application/pdf 2006-0319 MIT PBU NGI-07.pdf b - - - Content-Encoding: ase64 ¿flfì'P. ~ " -'; e), 1'1.)\) N'1o.'¡:iI,,\ /ì,DP; . '1.1 U ' .'; ,,-.,. A ~:~~~"~', t,,~. . 'J; "J,,, ~\!ff~' ~ ,~, 1 of! 4/14/20064:02 PM MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ,\) . f<é'ft' 4- 1141 C& DATE: Friday, April 07, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-07 PRUDHOE BAY UNIT NGI-07 Src: Inspector ~., 03~ \1 FROM: Lou Grimaldi Petroleum Inspector Well Name: PRUDHOE BAY UNIT NGI-07 API Well Number 50-029-20210-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060319145952 Permit Number: 176-038-0 Inspection Date: 3119/2006 Rei Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I NGI-07 !Type Inj. I N i TVD i I ! I ! I I 7473 IA 1820 2190 2170 ! 2150 I I P.T. i 1760380 !TypeTest i SPT I Test psi I OA I 0 I ! 0 I 1868.25 0 i 0 , I I i I /ç' I I ! í Interval REQVAR P/F Tubing] 1900 ! 4610 4570 4540 I Notes 1st Part of2 part test for variance compliance. PXN plug set in tubing below packer. During Bleed-off gas was vented ITom tubing. Requested fluid level be shot. PBU East trouble wells will contact us with results. C tlt{.,'fd resuJt +v -rL;1 rjL-tebkd r::, k'v"'\.''ßf 4/14/00 I I vlhJ NON-CONFIDENTIAL Reviewed By: P.I. Supl'vúBt2-- Coml1l ''-o({~ Á iío.1Nr;:::n ì::'!J"",I'tD1J ~.." .; 6} 0nnr¡ \} qJ (..'~VJ Friday, April 07, 2006 Page I of I NGI-07 (PTD #-1760380) Internal Waiver Cancellation - Trouble Well e e Subject: NGI-07 (PTD #-176(380) Internal Waivcr Cancellation - Trouble Wcll From: "NSU, ADW Well rntcgrity Engineer" <NSUADWWellTntegrityEnginecr@BP.com> Date: Mon, 27 Mar 2006 13:27:00 -0900 . r::!VbtO~ To: "AOGCC - Winton Aubert (E-mail)" <wintoll_aubert@admin.state.akus>, ~1 ")l jimJegg@admin.state.ak.us, "NSU, ADW Well Operations Supcrvisor" <NSUADWWcI10pcrationsSupcrvisor@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "GPB, FSl/Srp/STP Area Mgr" <GPBFSITL@BP.com>, "Kurz, 10hn" <john.kurz@BP.com>, "GPB, FSl/SIP/STP Area Mgr" <GPBFSITL@BP.com> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "NSU, ADW WI Tech" <NSUADWWITech@BP.com>, "Schmoyer, AI" <AI.Schmoyer@BP.com>, "Winslow, Jack 1.,," <Lyonsw@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "Anders, Joe L" <anders22@BP.com> All, An internal waiver was issued for a Production Casing leak on well NGI-07 (PTD #1760380) on 09/15/03. The well does not currently meet waiver requirements and therefore the waiver is cancelled. The well is currently shut-in with plans to evaluate options to prove tubing integrity. If successful, the well will again be evaluated for PC leak waiver. AOGCC Sundry #303-132 will either be revised to a Request for Administrative Approval or cancelled depending on the evaluation results. The well is reclassified as a Trouble well. Please remove all waive red well signs and the laminated copy of the waiver from the well house. Thank you, }lnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ;;..;Æ" ~"Ij..l t::'f\ n D j') " ~ '" r· fì è ;":v.iJ',..~a~l.J {'.~ j J~' j{~~ .'J,J fJ " 1 of 1 3/28/2006 12:44 PM RECEIVED SEP 2 6 Z005 ) STATE OF ALASKA '\ ALAS. . Oil AND GAS CONSERVATION COMM.__JION REPORT OF SUNDRY WELL -OPERATIONS Stimulate 0 Alas:k1aEÜit§ Gas to"a. Cð(t1Rd6it n Waiver 0 Time Extension 0 Anchorage Re-enter Suspended Well 0 5. Permit to Drill Number: 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 47 KB 8. Property Designation: ADL-028302 11. Present Well Condition Summary: Total Depth measured 8645 true vertical 8644.11 Effective Depth measured 8640 true vertical 8639.11 Casing Conductor Surface Production Liner Length 80 2695 7707 1199 Size 20" 94# H-40 13-3/8" 72# N-80 9-5/8" 47# N-80 7" 29# N-80 Perforation depth: Measured depth: 8032 - 8090 8330 - 8342 True Vertical depth: 8031.28 - 8089.27 8329.19 - 8341.19 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Lags and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Class: Development Stratigraphic feet feet feet feet MD 31 - 111 30 - 2725 29 - 7736 7446 - 8645 8094 - 8138 8350 - 8446 8093.27 - 8137.26 8349.18 - 8445.16 7"29# 5-1/2" Baker FB-1 Packer Exploratory [] 176-0380 Service M 6. API Number: 50-029-20210-00-00 9. Well Name and Number: NGI-07 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Plugs (measured) Junk (measured) 7335 7425 TVD Burst Collapse 31 - 111 1530 520 30 - 2724.93 5380 2670 29 - 7735.33 6870 4760 7445.35 - 8644.11 8160 7020 8176 - 8220 8458 - 8534 8175.25 - 8219.23 8457.15 - 8533.13 8245 - 8260 8288 - 8305 8244.22 - 8259.22 8287.21 - 8304.2 L-80 29 - 7395 7399 5CANNEJ) NO\~ 0 9 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 108340 180 o 151381 0 15. Well Class after Droposed work: Exploratory r Developmentr 16. Well Status after proposed work: Oil r Gas r WAG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal / Signat~ 4J~-ZJ.::I Form 10-404 Revised 04/2004 RBDMS 8Ft SEP 2 8 2005 Tubing pressure 3522 3451 Service ~ GINJ ~- WINJ r WDSPlC Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 9/23/2005 ORIGINAL Submit Original Only ) ') NGI-07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/29/2005 CORRELATED TO SWS IBP SET RECORD DATED 2-MAY-2004 SET IBP AT 7335 FT TO AVOID SETTING DOWN ON FISH. FLUIDS PUMPED BBLS 1 Diesel 357 1 % KCL 168 50/50 Meth 526 TOTAL ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION II ./ Mechanical Integrity Test ~é'1( c¡ b b S Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / NGI 09/01/05 Donald Reeves Packer Depth Pretest Initial Well NGI-07 I Type Inj. IN TVD I 7,398' Tubing 2,260 2,260 P.T.D. .1760380 Type test P Test psi 2000 Casing 1,480 2,000 Notes: MITIA for waiver compliance OA 30 30 _ Tbg pressure increased during test due to leaking wing valve (tree frosted) we1l1NGI-07 I Type Inj. IN I TVD I 7,398' Tubing 2,400 2,530 P.T.D. 1760380 Type test P Test psi 4550 Casing 2,000 1,965 Notes: MITOA for waiver compliance OA 30 4550 Tbg pressure increased during test due to leaking wing valve (tree frosted) weill I Type Inj·1 I TVD I Tubing P.T.D. Type test Test psi Casing Notes: OA weill Type Inj. I T:~PSil Tubing P.T.D. Type test Casing Notes: OA weill Type Inj./ I TVD I Tubing P.T.D. Type test Test psi Casing Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differentìal Temperature Test IÎÆ'-3~ 15 Min. 30 Min. 2,310 2,390 Interval 0 2,000 2,000 P/F P 30 30 2,540 2,570 Interval I 0 1,900 1,850 P/F P 4350 4320 Interval P/F Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) ~NEC 'NOIJ (1:;\\ 2.1)()5 MIT Report Form BFL 9/1/05 MIT PBU NGI-07 9-01-05-1 xis BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp April 24, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7~ Ave. Anchorage, Alaska 99501 Subject: NGI-07 (PTD 1760380) Application for Sundry Approval Dear Mr. Aubert: Attached is the Application for Sup. dry form 10-403 for well NGI-07. This request i~s for approval to continue gas injection into a well with a slow production casing leak.- Attached is a description summary of proposal, wellbore schematic and a completed MIT form. If you require any additional information or clarification, please contact Harry Engel at 564-4194, or John Cubbon or me at (907) 659-5102. Sincerely, J~e Anders, P.E. Well Integrity Engineer Attachments RECEIVED APR Alaska 0il & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: VARIANCE GAS INJECTION Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing_ Variance _X Perforate_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 215' FNL, 4291' FEL, Sec. 12, T11N, R14E, UM At top of productive interval 270' FNL, 4246' FEL, Sec. 12, TllN, R14E, UM At effective depth 270' FNL, 4258' FEL, Sec. 12, T11N, R14E, UM At total depth 272' FNL, 4237' FEL, Sec 12 T11N, R14E, UM Other _ 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X (asp's 687182, 5972101) (asp's 687229, 5972047) (asp's 687216, 5972047) (asp's 687237, 5972045) 6. Datum elevation (DF or KB feet) RKB 47.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number NGI-07 9. Permit number / approval number 176-038 / 10. APl number 50-029-20210-00 / 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 81' 20" Surface 2697' 13-3/8" Intermediate 7707' 9-5/8" Liner 8612' 7" 8645 feet Plugs (measured) Fish (parts of packing & O-ring) @ 7425' 8644 feet RECEIVED 7425 feet _Jun ( a r ) .003 APR 3 0 2003 Cemented Measured 0il & i0n 240 sx Arcitc Set 109' Anchorage9, 4800 sx PF II 2725' 2725' 750 sx Class 'G', 275 sx 7735' 7734' PF II 250 sx Class 'G' 8640' 8639' Perforation depth: measured Open Perfs 8032'-8090', 8094'-8138', 8176'-8220', 8245'-8260', 8288'-8305', 8330'-8342', Open Perfs (continued) 8350'-8446', 8458'-8534'. true vertical Open Perfs 8031'-8089', 8093'-8137', 8175'-8219', 8244'-8259', 8287'-8304', 8329'-8341', Open Perfs (continued) 8349'-8445', 8457'-8533'. Tubing (size, grade, and measured depth 7", 29#, L-80 TBG @ 7395'. 7" x 5-1/2" XO @ 7395'. 5-1/2", 17# L-80 TBG @ 7436'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker FB-1 Packer @ 7399'. 7" Otis RPB SSSV @ 2139' MD. 13. Attachments Description summary of proposal __X Detailed operations program BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal was verbally approved Name of approver Date approved Oil __ Service Gas __ Suspended __ Gas Iniection Well Questions? Call the Well Integrity Engineer (907) 659-5102. Date April 22, 2003 Prepared by DeWayne R. Schnorr 564-5174 17. I hereby c. ertify that the foregoing is true and correct to the best of my knowledge. Signed )(J~ ~ Title: Well Integrity Engineer Joe Anders, P.E. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity_ BOP Test __ Location clearance __ . Mechanical Integrity Test_ Subse,quent form required 10- ~ ~ ~ J .~ ~ Commissioner Approved by order of the Commission ~ ~ ~ ~ Date ~~~ ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE NGI-07 Description Summary of Proposal 04/24/O3 Problem: Gas Injector with Slow Production Casing Leak Well History and Status Well NGI-07 (PTD 1760380) is a gas injector that failed an MIT-IA on 04/10/03. The MITIA Io i at 15/30 minutes. The well is currently on gas injection. Recent events: > 06/01/02: MITIA PASSED to 2000 psi (AOGCC - J. Crisp) > 04/06/03: Set IBP above 7x5-1/2" XO' ~ > 04/10/03: MIT-T PASSED to 4320 psi. MIT-OA PASSED to 4320 psi. MITIA FAILED, Io~ses 80/100 in 15/30 minutes @ 3500 psi. > 04/11/03: MITIA to 2000 psi - PASSED f > 04/17/03: Pulled IBP, ran SSSV, POI This sundry request is to allow for continued injection of gas. The following supports the request: · 2 levels of protection are demonstrated by the MIT-Tubing passing to 4320 psi on 4/10/03 and the MITOA passing to 4320 psi on 4/10/03. · Pressures and injection rates will be monitored and recorded daily and checked for indications of ~'~ a tubing leak. · An MIT-OA will be conducted every year and an MIT-Tubing will be conducted every 4 years to ~ confirm 2 levels of protection. Proposed Action Plan 1. Allow well to continue gas injection. ~ Y 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. 4. IA fluid level will be monitored to ensure adequate IA fluid loading. 5. Perform MIT-OA every year. 6. Perform MIT-Tubing every4-years. 7. Stop injection and notify the AOGCC if there is any indication of loss of tubing integrity. TREE = GRAY GEN 2 WELLHEAD = GRAY~ ACTUATOR = AXELSON KB. B_EV = 47' BF. B_EV = ? KOP = 2900' Max Angle = 2 @ 8200' Datum rvD = 8849' SS Datum 'rVD = 8800' SS NGI-07 SAFETY NOTE POSSIBLE JAX?? FOI~¥1ATION COMMUNICATION. NOTE: THIS IS TIE RELD NGL DISPOSAL WELL. 2139' I--I 7" OTIS Rm SSSV NP, D :5.963" I IMinimum ID = 4.455" @ 7424' I OTIS XN NIPPLE 7" TBG, 29#, L-80, 0.0371 bpf, ID = 6.184" H 7395' TOP OF 5 1/2" TBG H 7395' 7395' H ~,,x~_~,~,,xo I 7399' H 9-5/8" X 5-1/Z' BAKER FB'I PKR I I 5-1/2" TBG, 17#, L-80, 0.0232 bpf, ID = 4.89Z' H 7436' I TOPOF 7"LNR H 7446' I o~5/8" CSG, 47#, N-80, ID = 8.681" H 7736' PERFORA'nON SUMMA RY REF LOG: BHCS ON 05/10/76 ANGLEATTOP PB:tF.' 2 @ 8032' Note: Refer to Production DB for historical perf data SIZE SFF INTERVAL OpnlSqz DATE 3-3/8" 4 8032-8090 O 07/01/90 3-3/8" ! 4 8094-8138 O 07/01/90 3-3/8" 4 8245-8260 O 07/01/90 3-3/8" 4 8330-8342 O 07/01/90 3-3/8" 4 8458-8464 O 07/01/90 ! 3-3/8" 4 8288-8305 O 07/27/83 3-3/8" 4 8350-8446 O 07/27/83 3-3/8" 4 8464-8534 O 07/27/83 3-3/8" 4 8201-8220 O 07/23/83 3-3/8" 4 8176-8201 O 01/11/77 7" LNR, 29#, N-80, 0.0371 bpf, ID = 6.184" H J TD H 8640' 8645' 7424' H 5-1/Z'OTISXNNP'ID=4'45F'I 7425' H PARTS OF PACKING AND O-RING I 7436' H I I742~' H ELMTTLOGGED06/30/~I DATE I REV BY I COM~NTS 07/15/761 I ORIGINAL COIVPLErlON o4/o8/83 J JLAST WOI~OV ER 07/17/01J RN/TP ICORRECTIONS I ,F yNOTEREVISDN 104/06/031CAC < I SET BKRIBP ~PULL BKR BP PRUDHOE BAY Ul~' WELL: NGF07 PERMIT No: 1760380 APl No: 50-029-20210-00 SEC 12, T11N, R14E, 4237.14' FB_ & 272.21' FN_ BP Exploration (Alas ka) i Maunder, Thomas E (DOA) From: Tom Maunder [tom_maunder @admin.state.ak.us] Sent: Thursday, April 24, 2003 1:44 PM To: Regg, James B (DOA) Subject: [Fwd: FYI: NGI -07 MIT Form] Attachments: FYI: NGI-07 MIT Form; tom_maunder.vcf FYI: NGI -07 MIT tom_maunder.vcf Form Jim, You are copied on this and I am tempted to send a reply to Joe, but I thought I would pass them to you so as not to muddy the water. I still do not understand what the leak mechanism is. The MIT -T validates the tubing, the MIT OA validates the OA, so it would appear that there is a production casing leak to the formation. Testing the OA to 4000 + psi would appear to have violated their problem well procedures. Hope this helps. Tom XAWDEt Pagel of 1 Maunder, Thomas E (DOA) ......... .... ....... ...... ....... ........................ From: NSU, ADW Well Integrity Engineer [ NSUADWWeIIlntegrityEngineer @BP.com] Sent: Thursday, April 24, 2003 9:25 AM To: Fleckenstein, Robert J (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); 'AOGCC Winton Aubert (E- mail)' Cc: 'Schmoyer, Al'; 'Engel, Harry R'; 'Rossberg, R Steven'; 'NSU, ADW Well Operations Supervisor' Subject: FYI: NGI -07 MIT Form Attachments: MIT PBU NGI -07 04- 10- 03.xis Hello all. Attached is an MIT form for MIT's performed on NGI -07. Let me know if you have any questions. Thanks! Joe Joe Anders, P.E. / John Cubbon Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work:(907) 659 -5102 Mobil: (907) 943 -1154 Pager: (907) 659 -5100, x1154 Email: NSUADWWeIIlntegrityEngineer @bp.com Maunder, Thomas E (DOA) From: Tom Maunder [tom_maunder @admin.state.ak.us] Sent: Tuesday, April 22, 2003 12:58 PM To: Regg, James B (DOA) Subject: [Fwd: FYI: NGI -07 Failed MITIA] Attachments: FYI: NGI -07 Failed MITIA; tom_maunder.vcf FYI: NGI -07 Failed tom_maunder.vcf MITIA You got a copy of this, but I have some observations to share. They mention setting an IBP and getting a tubing test. From their rece nt history it would appear that they have IA x OA communication although it is not really clear. 4320 for an OA test seems a little high based on what I remember from their policy. T /I /O plots and the history through the last year would be interesting to see. Oh, by the way, they intend to submit a variance request ? ? ?!!! This should be interesting, I don't think this is the only well out there with a likely communication problem. There will be severe production impact shutting down one of these big guys. Hope this helps. Tom ��. 2010 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWeIIlntegrityEngineer @BP.com] Sent: Tuesday, April 22, 2003 2:23 PM To: 'AOGCC Winton Aubert (E- mail)' Cc: 'Schmoyer, AI'; 'NSU, ADW Well Operations Supervisor'; 'Rossberg, R Steven'; 'Engel, Harry R'; Regg, James B (DOA); Maunder, Thomas E (DOA); 'GPB, FS1 TU Subject: REVISION: NGI -07 Failed MITIA Hi Winton. There is a typo in the below email. An MIT -T and MIT -OA passed on 4/10/03. I've corrected the text in the email. Thanks! Joe Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWeIIlntegrityEngineer @BP.com] Sent: Tuesday, April 22, 2003 12:52 PM To: 'AOGCC Winton Aubert (E- mail)' Cc: 'Schmoyer, AI'; 'NSU, ADW Well Operations Supervisor'; 'Rossberg, R Steven'; 'Engel, Harry R'; Regg, James B (DOA); Maunder, Thomas E (DOA); 'GPB, FS1 TU Subject: FYI: NGI -07 Failed MITIA Hi Winton, Well NGI -07 (PTD# 1760380) failed an MIT -IA on 4/10/03, loosing 80 /100 psi in 15/30 minutes at 3500 psi. This MIT was performed because there was a note in the well history mentioning a failing MI. An IBP was set and an MITIA & MITOA both passed to 4320 psi. Recent events: • 04/06/03: Set IBP. • 04/10/03: MIT -T PASSED to 4320 psi. MIT -OA PASSED to 4320 psi. MITIA FAILED, looses 80/100 in 15/30 minutes @ 3500 psi. > 04/17/03: Pulled IBP, ran SSSV. The well is currently on line and injecting gas, 189 MMCFD @ 3440 psi. Current plans are to submit a Sundry 10 -403 Variance request to continue injection with the failed MITIA. Please call Joe Anders or John Cubbon at 659 -5102 if you have any questions. Thanks! Joe Joe Anders, P.E. / John Cubbon Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work:(907) 659 -5102 Mobil: (907) 943 -1154 Pager: (907) 659 -5100, x1154 Email: NSUADWWellIntegrityEngineer @bp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein @admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT ! PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / NGI 04/10/03 John Cubbon Pretest Initial 15 Min. 30 Min. WelIINGI-07 Type Inj. P.T.D.11760380 Notes: MIT-Tubing, to eval possible failed MITIA. We, lNG,-07 ,nj.i i uo ol~,~"~'1 ~,~"~'1 Tubing] 20201 2020] 2040] 2040] IntervalI O P.T.D. I1760380 I Type Typetest I P I TestpsiI 18501 I casingl 16001 35001 34201 33201 P/FI F Notes: MIT-IA Failed, looses 80/100 psi in 15/30 minutes WelIINGI-07 Type Inj. P.T.D. 11760380 Notes: MIT-CA WellI Type Inj. P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU NGI-07 04-10-03.xls • • Page 1 of 3 r Thomas E DOA Maunde o From: Tom Maunder [tom_maunder @admin.state.ak.us] Sent: Tuesday, January 14, 2003 8:15 AM To: 'NSU, ADW Well Integrity Engineer' Cc: Regg, James B (DOA); 'Mike Bill' Subject: Re: Information concerning BP Internal waivers at NGI and WGI Attachments: tom maunder.vcf John, Thanks for the information. We are frankly surprised that any gas injection well would be operating on an "internal" waiver where to our knowledge the AOGCC has not been notified of the integrity loss that would require even considering a waiver. With some recent rare exceptions (NorthStar), and only after considering the information provided with a sundry application, the AOGCC has not granted waivers for gas (or MI) injection wells to remain in service with any integrity loss. BP should provide the necessary pressure testing (MITs) and history (TIO plots) information on NGI- 07, WGI -04, WGI -05 and NGI -11 that conclusively demonstrates the wells do not have any loss of integrity. If the available information on a particular well does not indicate that complete integrity exists, BP should immediately notify the AOGCC of such fact and provide an action plan to remedy the problem. Please be aware that if a gas injection well exhibits T x IA x OA communication, that well should be removed from service and secured. Please contact me or Jim Regg with any questions. Tom Maunder, PE 2 AOGCC DE L it ADW Well Integrity Engineer" wrote: Tom Jim, Please see the ' ormation that you requested concerning the gas injection wells with BP inte 1 waivers below. NGI -07: Waivered for pro tion casing leak on 10/23/90. Records indicate on 8/20/90, the IAP was pressure 2200 psi when it suddenly dropped to 2100 and started falling. A CMIT TxIA ducted 10/08/90 failed to hold 2500 psi. MITIA's routinely pass to 2000 psi, the ost recent was on 06/02. WGI -04: Waivered for slow IAxOA comm on 8/00. MITIA passed 10/02 to 2650 psi. OA re- pressure review conducted 12/02 indicat he IAxOA communication is no longer present. WGI -05: Waivered for slow IAxOA comm on 5/12/00. MITIA p ed 06/02 to 2060 psi. OA re- pressure rate not recently quantified. TIO trends indicate OA o`-Q �OF_ 12/22/2010 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWW ell IntegrityEngineer @BP.com] Sent: Sunday, January 12, 2003 7:54 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); 'NSU, ADW Well Integrity Engineer' Subject: Information concerning BP Internal waivers at NGI and WGI Tom and Jim, �R _. 7Z Z Please see the information that you requested concerning the gas injection wells with BP internal waivers below. NGI -07 Waivered for production casing leak on 10/23/90. Records indicate on 8/20/90, the IAP was pressured to 2200 psi when it suddenly dropped to 2100 and started falling. A CMIT TxIA conducted 10/08/90 failed to hold 2500 psi. MITIA's routinely pass to 2000 psi, the most recent was on 06/02. WGI -04: Waivered for slow IAxOA comm on 4/28/00. MITIA passed 10/02 to 2650 psi. OA re- pressure review conducted 12/02 indicates the IAxOA communication is no longer present. WGI -05: Waivered for slow IAxOA comm on 5/12/00. MITIA passed 06/02 to 2060 psi. OA re- pressure rate not recently quantified. TIO trends indicate IAxOA comm is still present. If you have any questions, or would like to discuss in greater detail, please let me know. Thanks, John Cubbon GPB Well Integrity Coordinator 1- 907 - 659 -5102 pgr. 659 -5102, x. 1154 - - - -- Original Message---- - From: Tom Maunder (mailto:tom maunder @admin.state.ak.us] Sent: Tuesday, December 24, 2002 9:41 AM To: Cubbon, John R Cc: Jim Regg (E- mail); NSU, ADW Well Integrity Engineer Subject _ Re: NGI -11 (PTD #1770800) OA pressurization John, We have received you message with regard to NGI -11. We are frankly surprised that you would propose to evaluate this well for an internal waiver. I seem to remember some discussions with regard to a couple of WGI wells that may have BP's internal waivers. Would you please provide a listing of the gas injection wells (NGI, WGI, AGI, LGI) that may have internal waivers and the reason a waiver is necessary. Although you indicate in your action plan that you plan to perform MITs and then evaluate the well for the internal waiver. We suggest that you also look into repairing the well. Tom Maunder, PE AOGCC " Cubbon, John R" wrote: > Hi Tom and Jim, • The NGI pad operator has notified us that the bleed frequency for the • OA 1 at > NGI -11 has increased recently. A brief history of events is as follows: > > 05/02/00: MITIA Passed to 3000 psi. > > 02/08/02: MIT IA Passed to 3000 psi. Investigate high IAP > > 10/19/02: DSO reported OA had jumped from 1600 to 2100 psi > > overnight. IA > gauge on wellhead shows 200 psi higher than test gauge. > > 10/20/02: PPPOT -T PASSED > > 12/22/02: PPPOT -IC PASSED > > 12/23/02: OAP increased 750 psi in 2 days. • As you can see from the attached TIO plot, since October 2002 the OA • repressurization rate for this well has increased. The source of the • pressure in the OA does not appear to be communication through the wellhead > (passing PPPOT -IC). > Our plan of action is as follows: > 1. MITIA to 3000 psi with the OA bled down to < 500 psi. > 2. MITOA to 3000 psi. > 3. Evaluate for an internal waiver to allow OAP to go to a maximum of > 2000 psi. • Please let me know if you would like us to procede in a different • manner or > if more information is required. > Thanks, • John Cubbon • GPB Well Integrity Coordinator • 1- 907 - 659 -5102 • pgr. 659 -5102, x. 1154 > «NGI -11 TIO.jpg>> «NGI- ll.pdf>> «NGI -II Inj. plot.jpg>> > ------------------------------------------------------------------------ > Name: NGI -11 TIO.jpg > NGI -11 TIO.jpg Type: JPEG Image (image /jpeg) > Encoding: base64 > Name: NGI- ll.pdf > NGI- ll.pdf Type: Acrobat (application /pdf) > Encoding: base64 > Name: NGI -II Inj. plot.jpg > NGI -II Inj. plot.jpg Type: JPEG Image (image /jpeg) > Encoding: base64 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector TO: Camille O. Taylor (~o~' DATE: June 1, 2002 Chair SUBJECT: Mechanical Integrity Tests --,~1~.~~ 07,09,13 & 14 Prudhoe Bay Field Prudhoe Bay Unit NON- CONFIDENTIAL WellI NGI-07 P.T.D.I 1760380 Notes: WellI NGI-09 P.T.D.I 1760680 Notes: WellI NGI-13 P.T.D.I 1780910 Notes: WellI NGI-14 P.T.D.I 1780920 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type lnj.I G I T.V.D. I 7398 I Tubingl 3360 I3360 I3360 I3360 I lntervall 4 ' ITypetestI P' ITestpsil 1850 I Casingl 280 I 2040 I 20301 2030 I PIE I P Type,nj.I G I T.V.D. 17510 I Tubing 13550 13550 13550 I3550 I'nterva'l 4' ITypetestI p ITestpsil 1878 I CasingI 300 I 24501 24501 24501 P/F I P Type,nj.I G I T.V.D. I~"~ I Tubing13550 13550 13550 I355° I'nterva'l 4" ITypetestI p ITestpsil 1836 ICasingI 80 I 25001 24901 25001 P/F I P I Type,,j.I G I T.V.D. I~ I Tub~ng13550 13550 13550 I355o I'nterva'l 4 I TypetestI p iTestpsiI 1793 iCasingI 50.I 2560I 2330I 2300I P/F I P Notes: Type testl 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= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature.Test Interval I-- Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BP's Prudhoe Bay Field NGI Pad to Witness 4 year MIT's. Good tests, no failures or problems witnessed. M.I.T.'s performedl :4 Attachments: Number of Failures: 0 Total Time during tests: 3 hrs. cc: MIT report form 5/12/00 L.G. MIT PBU NGI 06-01-02jc.xls 6/4/02 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser Commissioner THRU: Tom Maunder P.I. Supervisor FROM: Jeff Jones Petroleum InsPector DATE: August 20, 2001 SUBJECT: Mechanical Integrity Tests BPX NGI Pad NGI-06, 07, 08, 10, 12 PBU PBF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. w,~q .e~ iTypelnJ. I oIT-V-D-"I 7426ITubingI 345o I 345o I 345o I '~.50 l intervaq 4 'P.T.D.I 1760290 ITypetestl, P'" ITestpsiI 4~7 I C=~r~l o4O I 20~0 ,I 2°°°' I 2000I P/F I P I~les.- Pre-test.pressu .ms. monitored 30 minutes & ,stable.. ......... . w='l "~'~.~. i~,e'"j-I ~ I ~.v,o. I ~ I.?u="~ I ~ .I ~ I.~ I ~ I!"~='1 4 .P.T.D.I 4,7so3so ITypetestI P ITestpsil 48.50 I,Ca~.gl SO I 2040 I 204p I 2040 I,, P~F I E l~s: Pre-test pressures monitored 30 minutes & stable. ' w=,I ,~,~ I~e,.j.! ~' 'l'~.v:O. I~ I~u=.~l'~oo I ~o'I ~oo1~ I,.~,1 4 ,i P-T-D-I 1760520 IType,testl' P ITestPa, i, i'8'55 I Casi"gl'44o I 2045 '1 ,2o20 1'2m5 I P~F I E Neees: Pre-test pressures monitored 30 minutes & stable. w,,I -~,:~o I~,,~,.J.I ~ i ~.v.o. I ~=~ I~u""~l ,' P.T.D.i 1760690, IT~pet,estl P ITest~l !~2" lcfii 2S0 '1 2020.1 ,2O2O1202O1 P~F I Netes: Pre-test pressures monitored 30 minutes & stable. w~I ~:~2:l~nj.I' e I T.v.o-'l 7~ I T~a~J! 33501 337S I ~0 I ~ I'.te~q 4' "-~-~-I ~0~0 I~.e~l " I~=.s"l ~,' I C=~"~I Netes: Pre-test pressures monitored 30 minutes & stable. 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= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Monday, August ~ 2001: I traveled to BPX's NGI Pad to witness 4 year MIT's on wells NGI-06, NGI-07, NGI-08, NGI- 10 and NGI- 12. Scott Lyon (BPX representative) performed the tests today. The pre-test pressures were monitored for 30 minutes and observed to be stable. AIl five wells passed the MIT's and are suitable for continued injection. Summary.: I witnessed 5 successful MIT's at BPX's NGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: _.5 Number of Failures: _O Total Time during tests: 3.5 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU NGI-06,07,08,10,12 8-20-01 JJ.xls 8/27/01 Subject: NGI-07 Date: Sun, 24 Oct 1999 09:15:01 -0900 From: "PRB Problem Wells" <P 1041 @mail.aai.arco.com> T o: B lair_Wondzell@admin, state.ak.us Blair: The SSSV changeout was done on NGI-07. It appears the packing is holding good. Records show the SSSV requires changeout about every 3 months before the packing dries out and communication starts again. We will continue to monitor this well closely for any change in the frequency of $SSV problems. Jerry Dethlefs ARCO Problem Wells 1 of 1 10/25/99 7:59 AM Subject: NGI-07 Date: Fri, 22 Oct 1999 17:22:20 +0100 From: "PRB Problem Wells" <P 1041 ~mail.aai.arco.com> To: Blair_Wondzell~admin. state.ak.us, "Jerry L Brady" <JLBRADY~mail.aai.arco.com> CC: "Well Operations Supervisors AAI" <P2010@mail.aai.arco.com> Blair: I believe this has been reported to you in the past, but NGI-07 has tubing x IA communication via failed SSSV control lines. The well has passed all of its scheduled MITIA's with an SSSV in the well. This morning it was reported to me the IA is increasing in pressure, and I believe the packing on the SSSV is failing. The SSSV is to be pulled tomorrow morning and replaced. I will follow-up with monitoring wellhead pressures to verify the fix. Jerry Dethlefs ARCO Problem Wells 1 of 1 10/25/99 8:04 AM 995i0 P,O, BOX tOOS60- ANCHORAGE, ALASKA . , _REC. EI.VED: JUN t-1 lg-91- DATE: 6-t 3-9J . .. : . . ....~-:.,~ REFERENCE' ARCO CASED HOLE FINALS · ..... ~ 3-2A ........ 6-2-9~ ........ ---COLLAR-PERF..Z ................................... ~ ..........RUN 4., .-.5' A~'LA~ t 4"t--7f'; 5-i 6-9i "?~:;'~'INJ F'ROF - /~;..;~;?' "~;~'"" · RUN t, 5' CAMCO t 4-2~,-~,:---.5-i 6mgt...-~<;~.INd PROF'· ....... ~'~-':~:~ ' :"'~::':' ' ' -5' CAMCO .t4-25 -5-i6-9i . ':;;-~INJ P~OF-GR'.- '. ~??.._ RUN ~ 5' CAMCO ........ -sm ,.-s-t ? OF; ..................... .--S'- -, .......... -CA CO. t 5-i 5 5,t 7-9i '~:t~':PROD' PROF'' .... ~¥;:-.. ---,-':'.";~?::;-;.' RUN t, ~' CAMCO 5-23-9i.-.: .... ~.INJ.-PRO~ ..... ; ..... ; .................... L ..... z .............. RUN .t, -.5' CAMCO CAMCO ~1~46 ~ 5-23-9i PROD PROF ;. '._; .:-" RUN 9i' Z: ~' '' :": ..... i6-24 ......... 5-i 9- ,~ ..... ,=.F. ROD~.F-RO~-.-;'---""-~'--~;.-~z'~ .... "' "RUN -t :..:5 CAMCO ':'::.:~:j ?~2:rt"7.: s-m-mi ;:~':~;~;~LEAK.,:~ETE~ ~?~-:::-:~-::. :.: "; )-'-,.:~f~?:..:?.f;,"?~;=~U,' ~ :,':~'2' -'";~ :: :.CAMCO ..... '" i 7.'.f.'t :." 'L.'~5-27-~t '..::.:?~-~ LEAK Y'DETEC~:~:t:'~:-''':'~ "f-"' ' ;.: :"~7,:~}~?.-'-".'..~ :. RUN .-Yt , .. ...... ;--t-7.~:t:~.~ D..~.5 ~-i t - ~.~ .~..:~':~;PRO D _~'P ROF' ~-$.~ S,S..,L .} .... L'~-j~,--%~L...: 6' "~.~}:...R UN .~J. )';~ ~: ~,:?~:z::'~,L/~i~~ C AHCO .., _,. ;:: . - ~..~....,~t~ ~ ~_ _~, .-. _;..~;.~?:-~:..: :-,-: ... :;~-..:~.~.~ ..... ?.~.. -..:~. :~ .: . ,::. ~ .~..~-..,: .,~..-~. ---: NGI-._~:.?..:.5..t ~ 9t---.---?4INJ PROF.::: :,:,:-~--.:~::---:_:..~-.,- . .~:--.::. :,- ~.:,- .: ....: RUN ..~ :.~ J~.---WGI~5 ...... 5-i~-~i ........ INJ FROF .................... · ...... , ....... RUN t, 5 -....CAMCO ; .. PLEE,Az?E ,~IGN AND RETURN THE ATTACHED COF'Y A~ RECEIPT OF DATA, - "' - ' .-...~:. '_ .,': 'L : -:7 ' ' " . R~'C~IV~D~ ~ ._ BY' HAVE' A..: NiCE DAY I .... '-- ....... ... :._i'L;:~-::~...~:,:..:..~.~...~..:.....-....-~'~.~. ';. : .:~;-~',.,.~..~...:..~t~. ~ ., . :.:~ '~ 0 N ~ ~' ." ~ ~ L L A C E - ': ::-?~".'-:~.~:Y:~?:'~;r"-:':~-~ ~? tL:',~'?~':~?~'': ~":?'j':: ~ F' F~~~ .??'~'~?~-~,:¥ :,~' ':' ":': .: ~:". :' :: :'" -- .' --: ..... ./-.---~ ', ....-. ' ..--:~-"'.; .~'~'~:?'.:'-'-~.--:r,~ ~:-~,.:-":~'-:'?.~: '-'"- : ~'. ~~:~ ,~'-. '? 'r -' . ' "' ' '..- '--'?.-:"-~.-:.~ ;. ' -. ..~:~'..~.- ' '-' .--';: .... ~;~-' ' ' "' -. -- " :" -t~ .... ':'. ~ ' .:' -.' :' ' ' ' ..... · . ::::' :." .: ,':-W'- '. ,.. ' S:": '':? '~;'-"" .... ' --:';'""' '"':':" :~':;':':""'- '~' :'::~"' '"" -- ' ' ' ~ . " ' ... . .. ;% .. ..... "' -DJ ~-T-R~BUT[ ON ............ ~ ........ . - x.- ._ .,. ,~f/~ ..~- '- . - ;. . ~ PH[LLZP~ - ................... : .......... ~ -.. CENTR~L-.-.~[LE~-~ ..... ~ ......... ~ ........~ ............................... ..,. ~ CHEVRON '- -' .............. - F'B ~ELL:'F[LE~ , D & H ..... ~ .............................................. R & D ....... ~; ..................... ..................... ._. ' ~ EXTENSION EXPLORATION ~ BF'X . .EXXON MARATHON MOBIL ' .~ ...... ,-~ .... ~ ..... $]'.ATE.~.ALA~KA .......................................... TEXACO ' "' STATE OF ALASKA ~-' --' ~' ALASKA'~'NL AND GAS CONSERVATION C'F--',MI~ION REPORT' SUNDRY WELL OP _,' ATIONS" 1. Operations performed: Operation shUtd~vn Stimulate Plugging., Perforate Pull tubing Alter casing ~ Repair well Other --.. 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 216' S & 989' E of NWcr. Sec. 12, T11N, R14E, UM At top of productive interval 270' S & 1034' E of NW cr. Sec. 12, T11N, R14E, UM At effective depth At total depth 272'S & 1044' Eof NWcr. Sec. 12, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service :X 6. Datum of elevation(DF or KB) 47 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-7 9. Permit number/approval number 76-38/90-299 10. APl number 50 - 029-20210 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 8645 feet Plugs(measured) 8644 feet Effective depth: measured 8498 feet true vertical 8497 feet Fill (measured) 8498 Casing Length Size Cemented Measured depth True vertical depth Sudace 81' 20" 240 sx Arctic Set 81' 81' Intermediate 2678' 13-3/8" 4800 sx PF II 2725' 2725' Production 7688' 9-5/8" 750 sx CI 'G' & 275 sx PF II 7735' 7734' Liner 1194' 7" 250 sx 8640' 8639' Perforation depth: measured 8032-8090'; 8094-8138'; 8176-8265'; 8263-8342'; 8350-8446'; 8458-8534'; 8553-8565' true vertical 8031-8089'; 8093-8137'; 8175-8264'; 8262-8341°; 8349-8445'; 8457-8533'; 8552-8564; Tubing (size, grade, and measured depth) 7", 29#, L-80, PCT @ 7395' MD; 5-1/2", 17#, L-80, PCT tail @ 7436' MD Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 7399' MD; Otis RPB SSSV @ 2139~1t{~ ~1~,'~) 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Reoresentative Daily Averaoe Production or Iniection Da~,SY~ · ~)~ Reference OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 234M .... 39OO Subsequent to operation 234M .... 390O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas __ Suspended Service Gas InJection 17. I hereby ce~'fy ~ the foregoing is true and correct to the best of my knowledge. Signed ~~ ~//~%.~ Title Senior Area Engineer Form 10f~04 Rev 06/15/88 SUBMIT I1~' DUI~'LICATE' NGI-7 Work Summary On June 30, 1990 and July 1, 1990, the following perforations were added in Well NGI-7. Interval, MD (BHCS 06/10/76) Interval Length Formation Name SPF 8032-8090' 58' Put River 4 8094-8138 44' Sag River 4 8245-8265' 15' 4 ~,~t,,~l(.. 4 8330-8342' 12' 2 ~'~ ''~''d~ 4 8458-8464' 6' 2 ~v~l~,k. 4 ARCO AI_AS'KA, ZNC F'. O. BOX ANCHORAGE, ALA.gKA 995:i,:D DA TE ' '?-7-9¢° REF'E:RENCFZ' ARCO CA.S:ED HOLE F'INAL.? N(~- Z- i 6-28--9E:o COLLAF~,',"'F:'E:F;..'F: RUN i , 5; ' N(.;- i -'2 6-28-9;.-} COLLAlr</'I'"E-"RF-'' RUN i , ~5" N ..... 6; Z -- 3; 6 -- f:: c;., -.. o, ":'~._. C 0 L L A R ,," F:' E R F' R U N t , ..,.'::'" N(.;-I-,'4 6--29-9,E~ COLLAR/'F'Ei4F RIjN i '=" i'4(.5Z-6 6-,'3;:;-°;:''',. , ,, C'OLLAR/F'ERF' RLJN i , .,'r'~'" N(.;I'-7 7-i -9¢3 CC)I...LAR/F'EI;..'F RUN I , .5(" NC-;Z-8. 7-i _o. ,.:~, .., r':nl. .......... LP~F;.'/PF'RFr RUN i , ..,."~'" N (.; I - 9 '7- 2- 9 ,::} C: 01_ L A F;.: / P E F;.: F F;,' U N I , 5:' N.. E.; ]: - i 0 '7 - 4 --- 9 ¢:,_ C 0 L L A R /F' E t;.: F F;.: U N i , .,."~'" F'LIEA3?E ZIE-N AND tRE'¥UIRN THE ATTAC~F'Y A37 RECEIF'F OF DA'FA, HAVE A NICE DAY! ,'~ALL. ¥ HOF:FECKEF: ATO- i 5;'29 JUL 1 0 1990 · / · ~' :' ' 'r'~VE'I', .~ 41 .Oil & Cons. Commi ! ~ '"' .~c~ora~'8 · 1];.'. A N £' :,- 9 ~'2/'2/"/~' ,r- ' A'f'I..A.¥ ~':~ ! l_ A ;:-.)' A 'f' L A .:'7 ¢~ 'f'l_ A ;!;' r:~ f'L. AS A'f'L A.S' ¢-.I 'i- L. A I:':l "1' D I S T F;,' I BUT ]J ON "' C F_" N 'F t;:. A L FILl:.,. ~,-4"CHEVRON. . D * M J~ EXTEN,S: i CIN EXPL. OR~T'r ON · '" EXXON HARAI'HON · .- MOBIL · ,- F' lq I L L I F' 5' F'B WELL R & D ~ BF'X .~TATE OF ALAS'I< TEXACO STATE OF ALASKA ALAE"~'OIL AND GAS CONSERVATION )MMISSIO~ n ~ APPLI(.,, .TION FOR SUNDRY APPRO I .E$ G IN l. 1. Type of Req[~est: 2. Name of Operator ARCO Alaska, Inc. Abandon , Suspend Operation shutdown ~ Alter casing Repair well Plugging Change approved program Pull tubing Vadance 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 216'S & 989' Eof NWcr. Sec. 12, T11N, R14E, UM At top of productive interval 270'S & 1034' E of NW cr. Sec. 12, T11N, R14E, UM At effective depth At total depth 272' S & 1044' E of NW cr, Sec. 12, T11N, R14E, UM Re-enter suspended well Time extension Stimulate Perforate X O~h,;r 6. Datum of elevation(DF or KB) 47 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-7 9. Permit number 76-38 10. APl number 50 - 029-20210 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 8645 feet Plugs(measured) 8644 feet Effective depth: measured 8584 feet ;'~A¥ 0.~ ]9~i~~r true vertical 8583 feet Junk(measured) 'J~,;i~:~.,. 0JJ & Gas Con~. C0mr/lis,~io,~ Casing Length Size Cemented Measure~l:lll~jag~l'rue vertical depth Su dace 81' 20" 240 sx Arcticset 81' 81' Intermediate 2678' 13-3/8" 4800 sx PF II 2725' 2725' Production 7688' 9-5/8" 750 sx Cl 'G' & 275 sx PF II 7735' 7734' Liner 1194' 7" 250 sx 8640' 8639' Perforation depth: measured 8176-8245'; 8263-8330'; 8350-8446'; 8464-8534'; 8553-8565' true vertical 8175-8244'; 8262-8329'; 8349-8445'; 8463-8533'; 8552-8564' Tubing (size, grade, and measured depth) 7", 29#, L-80, PCT @ 7395' MD; 5-1/2", 17#, L-80, PCT tail @ 7436' MD Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 7399' MD; Otis RPB $SSV @ 2139' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May~90 Oil 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby~j~rtify that t.l.l.h,e foregoing is true and correct to the best of my knowledge. Signed ~//~~,~~"~ Title Operations Engineering Manager FOR COMMISSION IISI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- q~¥ 15. Status of well classification as: Gas Suspended J Approval No. ¢ ~ _.~ ,,~,,~ gas injection well Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston ..... ~ r,_,.,n~ommissioner ~---'-I -'=1,O Date SUBMIT IN TRIPLICATE NGI-7 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations in Well NGI-7. The proposed perforation intervals are as follows: Interval, MD Interval, MD Interval Formation (BHCS 6/10/76) (Tie-in) Length Name/Zone 8032-8[]90' 8032-8[390' 58' Put River ~~8138' ~ 8033:~ 38' 44' Sag River -~'"'~8245-8265' ::~ 8245-8260' 15' 4 8330-8342' 833G8342' 12' 2 8458-8464' 8458-8464' 6 2 A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with the wellbore loaded with sea water. After perforating, gas injection will resume with the wellbore load fluid being displaced into the wellbore formation. No flaring is anticipated. ARCO.Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 27, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS NGI-7 Approval No. 8-893 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JCB/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS NIG-7)W1-3 RECEIVED Alaska DJ/& Gas Cons. Commission WELLS3/102 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C . /~ / STATE OF ALASKA ' AL' ~IL AND GAS CONSERVATION COMMI. ON , REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation 8hutdown__. Stimulate ~ Plugging __ Pedorate __ Pull tubing ._. Name of Operator ARCO Alaska, Inc. Address P. O. Box 100360, Location of well at surface 216' S & 989' E of NW cr, At top of productive interval 270' S & 1034' E of NW cr, Alter casing __ ~ , Anchorage, AK 99510 Sec. 12, TllN, At effective depth Sec. 12, TllN, ~totalde~h 272' S & 1044' E of NW cr, Sec. 12, TllN, Repair well _._ Pull tubing 5. Type of Well: Development __ Exploratory __ Stratigraphic ~ Service ~ R14E, UM R14E, UM R14E, UM Other __ 6. Datum elevation (DF or KB) 47' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number NGI-7 9. Permit number/approval number 8-893 10. APl number 50-- 029-20210 11. Field/Pool Prudhoe Ba7 Oil Pool 12. present well condition summary Total depth: measured true vertical 8645 feet 8644 feet Effective depth: measured 8584 feet true vertical feet 8583 Casing ~ngth Size Surface 81' 20" Intermediate 2678' 13-3/8" Production 7688' 9-5/8" Liner 1194' 7" Plugs(measured) Junk (measured) Cemented Measured depth · True vertical depth 240 sx Arcticset 81' 81' 4800 sx PF II 2725' 2725' 750 sx C1 'G' & 7735' 7734' 275 sx PF II 250 sx 8640' 8639' 13. Perforation depth: measured 8176-8245'; 8263-8330' ;8350-8446'; 8464-8534'; 8553-8565' true vertical 8175-8244'; 8262-8329'; 8349-8445'; 8463-8533'; 8552-8564' Tubing (size, grade, and measured depth) 7", 29~I, L-80, PCT @ 7395'; MD; 5~", 17~t, L-80, ?CT tail Packers and SSSV (type and measured depth) Baker FB-1 packer @ 7~' MD; Otis RPB SSSV ~ 2139'. MD Stimulation or cement squeeze summary Attached Intervals treated (measured) Treatment description including volumes used and final pressure @ 7436' MD JAN _~ 1 ]!9.gq Aias.~ 0il & Gas Cons. ,Commission ',.i ~ch0rage ~ 14. Representative Daily Average I:'~:~e~e. or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 167M -- 0 3900 -- 214M -- Subsequent to operation 15. Attachments ] 16. Status of well classification as: Copies of Logs and Surveys run __ ! Daily Report of Well Operations __ Oil __ Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 3900 Signed 2~~~~~c-~-~'~ Form 10-404 Rev 06/15/88 WELLS3/102 J. Title Operations C. Braden, 263-4536 Engineering Manager Date ~*~ SUBMIT IN DUPLICATE NGI 7 12% HCI-3% HF Matrix Stimulation 2 January 1989 ARCO Alaska, Inc. performed the following stimulation treatment: 1. The following fluids were loaded: ~ 18000 b. 30000 c. 30000 d. 200 e. 14000 f. 150 g. 249 gal 12% HCI with 15% dispersed xylene and with additives. gal 12% HCl-3% HF with additives. gal 2% NH4Cl water - for overflush of mud acid. bbl hot water (140OF to 150OF) - for first stage hot water wash. gal 2% NH4Cl water gelled with 40 Ibs/Mgal of HEC polymer and containing a foaming agent. bbl of 50/50 methanol/water. MSCF N2 - 229M for foam and 20M for warmup. 2. MI&RU pump trucks, transports and N2 unit. 3. Pumped the following fluids: ~ 200 b. 6000 c. 6000 d. 6000 e. 150 f. 2000 g. 4000 h. 8000 i. 8000 j. lOO k. 1500 I. 4OOO m. 8000 n. 8000 o. 100 p. 1500 q. 4000 r. 8000 s 8000 t. 150 bbl of hot water gal of 12% HCI with dispersed xylene and additives gal of 12% HCI-3% HF with additives gal of 2% NH4Cl water bbl of 50 Quality Foam consisting of the following: 4000 gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and foaming agent 115MSCF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water gal of 2% NH4CI water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCl with dispersed xylene and additives gal of 12% HCI-3% HF with additives gal of 2% NH4Cl water bbl of 50 Quality Foam consisting of the following: 2000 gal of 2% NH4CI water with 40 Ibs/Mgal HEC polymer and foaming agent 58MSCF of N2 injected at 1200 SCF/bbl of 2% NH4CI water. gal of 2% NH4CI water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCI with dispersed xylene and additives gal of 12% HCI-3% HF with additives gal of 2% NH4CI water bbl of 50 Quality Foam consisting of the following 2000 gal of 2% NH4Cl water with 40.1bs/Mgal HEC polymer and foaming agent 58MSCF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water gal of 2% NH4CI water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCl with dispersed xylene and additives gal of 12% HCI-3% HF with additives gal of 2% NH4CI water bbl of 50/50 methanol/water 4. RD and released the equipment. 5. Returned the well to injection immediately. ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 28, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS NGI-7 Permit No. 76-38 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment :' cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS NGI-7)W1-3 iss~or WELLS2/177 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. · Box 100360, Anchorage, AE 99510 4. Location of well at surface 216' S & 989' E of NW cf, Sec. Attop ofproductiveinterval 270' S & 1034' E of NW cf, Sec. Ateffective depth 12, TllN, R14E, UM 12, TllN, R14E, UM Attotaldepth 272' S'& 1044'E of NW cf, SeC. 12, TllN, R14E, UM 5. Datum elevation (DF or KB) 47' ~B 6. Unit or Property name Prudhoe Bay Unit feet 7. Well number NGI-7 8. Permit number 76-38 9. APl number 50-- 029-20210 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 8645 feet 8644 feet Effective depth: measured 8584 true vertical 8583 Casing Length Size Surface 81 ' 20" Intermediate 2678 ' 13-3/8" Production 7688 ' 9-5/8" Liner 1194' 7" feet feet Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth 240 sx Arcticset 81' 81' 4800 sx PF II 2725' 2725' 750 sx Cl 'G' & 7735' 7734' 275-sx PF II 250 sx 8640' 8639' Perforation depth: measured 8176-8245'; 8263-8330'; 8350-8446'; 8464-8534'; 8553-8565' true vertical 8175-8244'; 8262-8329'; 8349-8445'; 8463-8533'; 8552-8564' Tubing (size, grade and measured depth) 7", 29f~, L-80, PCT @ 7395' MD; 5½", 17fl, L-80, PCT tail @ 7436' MD Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 7399' MD; Otis RPB SSSV @ 2139' MD 12.Attachments RECEIVED NOV Alaska 0il & Gas Cons. Commi4 ~, ~nchorage Description sUmmary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation July 1988 14. If proposal was verbally'approved Name of approver Subsequent Work Reported ou Date approved 15. I hereby..certi'fy that the foregoing is true and correct to the best of my knowledge Signed ~;~'~'~//~//,~('/'~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness I ApprovaINo. ~_~~L. [] Plug integrity [] BOP Test [] Location clearance[ Approved Copy Returned _ ORIGINAl- SIGNED BY bY order of Approved by. LONNIE C, SMITH Commissioner the commission Date dj Form 10-403 Rev 12-1-85 WET.LS2/177 3. M'. Vitucci, 265-6358 ,. ~Zi'> Submit in triplicate 6 5 4 3 2 COILED TUBING UNIT eDP E Ou ! Pl~Nm 1. 5000 PSI ?" WELLHEAD CONNECTOR IrLANGE 2. 5000 PSI 4 1/16" PIPE RAMS ,~.5000 PSI 4 1/6" HYDRAULIC ,SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 2 REEEIVED NOV 3 :~ !9.g~q Oil & Gas Cons. Commission ~,-~ Rnchorage NIRELINE: BOP EOUIPHENT 1. 5000 PSI ?" WELLHEAD CONNECIOR FLANGE :2.5000 PSI WIRELIN[ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF NGI 7 12% HCI-3% HF Matrix Stimulation ARCO Alaska, Inc. proposes to perform the following stimulation treatment: 1. Load the following fluids: a. 1 800 0 gal 12% HCl with 15% dispersed xylene and with additives. Concentration specification is 10.5% to 13.0% HCl and less than 300 ppm Fa. b. 30000 gal 12% HCl-3% HF with additives. Concentration specification is 10.5% to 13.0% HCl, 2.4% to 4.0% HF and less than 300 ppm Fa. c. 30000 gal 2% NH4Cl water - for overflush of mud acid. d. 200 bbl hot water (140OF to 150OF) - for first stage hot water wash. e. 1 2000 gal 2% NH4Cl water gelled with 40 Ibs/Mgal of HEC polymer and containing one of the following foaming agents: B J/Titan Dowell Halliburton FAW-16 at 5-10 gal/Mgal F75N at 3-5 gal/Mgal Pen-5 at 1% by volume f. 150 bbl of 50/50 methanol/water. g. 1 9 2 MSCF N2 - 172M for foam and 20M for warmup. 2. MI&RU pump trucks, transports and N2 unit. 3. Pump the following fluids: a. 2OO b. 6000 c. 6000 d. 6OOO e. 150 f. k. m. n. O. 2OOO 4000 8OOO 8000 75 2OOO 4OOO 8000 8000 75 bbl of hot water gal of 12% HCl with dispersed xylene and additives gal of 12% HCI-3% HF with additives gal of 2% NH4Cl water bbl of 50 Quality Foam consisting of the following: 3000 gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and foaming agent 86MSCF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCl with dispersed xylene and additives gal of 12% HCl-3% HF with additives gal of 2% NH4Cl water bbl of 50 Quality Foam consisting of the following: 1500 gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and foaming agent 43MSCF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCl with dispersed xylene and additives gal of 12% HCl-3% HF with additives gal of 2% NH4Cl water bbl of 50 Quality Foam consisting of the following R E ~ E'IV E D .Oil & Gas Cons. Commission = Anchorage p. 2000 ~ 4000 r. 8000 s 8000 t. 150 1500 gal of 2%' NH4CI water with 40 Ibs/Mgal HEC polymer and foaming agent 43MSCF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water gal of 2% NH4CI water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCl with dispersed xylene and additives gal of 12% HCI-3% HF with additives gal of 2% NH4CI water bbl of 50/50 methanol/water 4. RD and release the equipment. Se Return the well to injection immediately. Note the injection rate, pressure and temperature on the wireline report. ARCO Alaska, Inc.,,"~'X Post Office ~_ ~ 360 Anchorage. Alaska 99510 Teieoho?~ 907 ?77 August 15, 1983 Reference: Arco Pressure Data D.S. 1-19 7-16-83 7-16-83 NGI #7 7-29-83 Pressure Build-up PreSsure Build-up Survey Report ,Static Survey GO DA and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 474 Chevron Dallas Drilling Exxon Getty Marathon Mobi I DISTgIBUTION North Geology Phillips Prudhoe Bay ~ 3'-' Sohio ARCO Alaska, Inc Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer August 10, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: NGI #7 Permit No. 76-38 Enclosed is "Subsequent" Sundry Notice detailing work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JDD/lmi Attachments cc: Sohio Petroleum ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRichfleldCompany ~.~. STATE OF ALASKA ALASW :IL AND GAS CONSERVATION C ;AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WEL~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-38 3. Address 8. APINumber P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20210 4. Location of Well 216' S & 989' E of NW Cr. Sec. 12, TllN, R14E, UM (Surface) 270' S & 1034' E of NW Cr Sec. 12, TllN, R14E, UM (Top Prod) 272' S & 1044' E of NW Cr Sec. 12, TllN, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 47' RKB I ADL 28302 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number NGI ~7 12. 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 7/27/83. RU slickline unit. Pull SSSV. Made gauge ring run to PBD. RU pump truck, pump 655 bbls of diesel down wellbore for pressure control. RU perforating unit, pressure test surface equipment. Shot 8~4-8534' MD (20') with gun #1, 8494-8514' MD (20') with gun #2, 8474-8494' MD (20') with gun #3, 8464-8474' MD (10') with gun #4, 8426-8446' MD (20') with gun #5, 8406-8426' MD (20') with gun #6. Change out pack-off rubbers. Shot 8386-8406' MD (20') with gun ~7, 8366-8386' MD (20') with gun ~8, 8350-8366' MD (16') with gun #9. Gun #9 misfired from 8355-8360' MD. Did not re-shoot. Shot 8288-8305' MD (17') with gun #10, 820'1-8220' MD (19') with gun #11. RIH with Hewlett-Packard pressure recorder. Static pressure and temp. at 8300' ss (8348' MD) was 3994 psia and 158°F, and at 8000' ss (8048' MD) was 3940 psia and 169.3°F. Hook up blOw-down line. Backflowed well to flarepit from 0700-0840 hrs., 7/29/83. Secured well. Began gas injection 7/29/83. General Notes: Depth reference was BHCS 6/10/76, tie-in log was CCL/GR 11/29/76. All shots fired except 5' interval 83.55-8360' MD on gun #9. All intervals shot at 4 spf, 120° phasing with 4" casing gun. Lubricator was pressure tested prior to each gun run. EC£1V, ED ,AUG 7' ,9B3 14. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Signed ........ Title Regional ~lneer Ar~oh0rageDate The space below for Commission use Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay i=ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 7, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: NGI #7 Permit No. 76-38 Attached is the "Notice of Intention" Sundry Notice for work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JCD/lmi Attachments cc: Sohio Petroleum JUL "- 8 ARCO Alaska, Inc. Is a Subsidiary of AtlanticRIchfleldCompany "~ . STATE OF ALASKA ALASK?DIL AND GAS CONSERVATION GCMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] ' COMPLETED WE LL)~, OTHER [] 2. Name of Operator ARCO Alaska, Inc. 7. Permit No. 76-38 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 5o- 029-20210 4. Location of Well 216' S & 989' E of NW CR Sec. 12, TllN, R14E, UN (Surface) 270' S & 1034' E of NW CR Sec. 12, TllN, R14E, UM (.Top Prod) 272' S & 1044' E of NW CR Sec. 12, TllN, R14E, UM (Tn) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. I ADL 28302 12. 9. Unit or Lease Name Prudhoe Ba,v Unit 10. Well Number NGI #7 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool CheCk Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate )~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other . [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed 'Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO. proposes to add 202' of additional perforations to NGI #7 for increased injection capacity. The additional intervals are: 8201-8220', 8288-8305', 8350-8446', and 8464-8534' MD (ref: BHCS 6/10/76). We plan to perforate with diesel in hole and then backflow to the flare pit for clean-up. Pertinent pressures, temperatures and flowrates will be monitored while backflowing. Static reservoir pressures will be taken at 8000' and 8300' S.s. The work is expected to be completed by July 15, 1983. RE£EIVED ,JUL - 8~ Alaska Oil & Gas Cons. Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed P~q~,~"'~~ ~~ Title Regional Engineer The space below for Commissio e Date Conditions of APproval, if any: ,~,'~,.~ Approved by. COMMISSIONER Approved Copy ?.eturned _ By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~ Post Office B~ ,:t60 Anchorage, Alaska 99510 Telephone 907 277 5637 May 11, 1983 Mr. C. V. Chatterton Commissioner State '-'.of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive ,Anchorage, Alaska 99501 Subject' Monthly Report of Drilling & Workover Operations Dear Sir: Enclosed find Monthly Reports of Drilling and Workover Operations for the · ,~, ~llowing. ..,_Ds 7-26 Ds ' 7-25 DS 7-24 DS 1-26 DS 13-29 DS 5-11 ~ NGI #7~ S. Point State #1 Sincerely, M. A. Major Area Drilling Bngineer MAM/CSM' tw Attachments ARCO Alaska, Inc. is a subsidiary of Allanti.:RichfieldCompany STATE OF ALASKA ~ ALASKA ~- .~ AND GAS CONSERVATION CL .~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL ~fE3 OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of Well 216'SNL & 989'EWL, Sec. 12, T11N, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 47'RKB I6. Lease Designation and Serial No. ADL 28302 7. Permit No. 76-38 8. APl Number 50- 029-20210 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number NG I #7 11, Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Puli Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: Submit in Duplicate) [] Altering Casing [] Abandonment Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105,170). Accept rig @ 0600 hrs 03/25/83. Pulled BPV. RIH & perf tbg. Left gun, CCL, cable head & 3-4' wire in hole. Attempt to fish, did not retrieve fish. Top of fish ~ 8503'. PU & stand back 3-1/2" DP. Set BPV. ND tree.l NU BOPE. Pull BPV. Pull 87 jts 4-1/2" tbg w/control line balling up. Tbg stuck unable to work up or down. Attempt to jar loose, failed. Run free pt. indicator, pipe stuck ~ 1180'. Run string shot and back off tbg 1115'. Pull 36 jts 4-1/2" tbg. Pull 25 jts 7". Ran 10 jts 7" back in hole. Fish @ 442'. RIH w/fishing assy and jarred fish loose, moved only 30'. Backed off at 400'+. Pull 10 jts 7".. Unballed control line & freei 4-1/2" tbg. MU storm choke & RTTS on 4-1/2" tbg and set in 7" tbg. Reland 7" tbg. RIH, release RTTS & tbg. Pull & LD 7" tbg. Retrieve K-anchor. Mill Packer. POOH, recovered pkr. RIH w/9-5/8" csg scrpr &! 4-1/2" CO. RIH, set RTTS. Tst 9-5/8" csg. TOOH w/RTTS. MU storm choke on DP. RIH & set. ND stack & spools, NUi BOPE & new landing spool. 'Tst BOPE. RIH & tel storm choke, POOH. TIH w/Fishing BHA. Top of fish ~ 8503'. Work over fish. TOH w/FBHA, recover fish. MU bit & CO to PBTD. POOH. RIH w/pkr on DP and set ~ 7399'. POOHi and LD 3-1/2" DP. Ran 130 its 7", 29#, 8rd tbg compl string and 53 jts 7", 26#, IJ4S tbg. Land tbg. Set BPV, ND BOPE. NU tree & tst. Pull BPV. Set inj. valve. Set BPV. Secure well & release rig ~ 1000 hrs 04/09/83. RECEIVED MAY 1 3 i983 14. I hereby certify that the foregoing is true and correct to the best of my koowledge. A~cn0rago / - / ;'. ~;, :, , A~ea Dr~ ~ing Eng~nee~ Signed ~ Title Date The space below for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date __ Form 10-403 Submit "Intentions" in Triplicate and. "Subseouent Reports" in Duplicate ?--, STATE OF ALASKA ~ ALASKA L "AND GAS CONSERVATION C;,O. .~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation I-lX 2. Name of operator 7. Permit No. ~ARC0 Alaska, Inc. 76-38 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-20210 4. Location of Well at surface 216'S & 989'E of NW cr Sec 12, TllN, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 1 6. Lease Designation and Serial No. 47' RKBJ ADL 28302 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. NGI #7 (11-12-11-14) 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of Ap ril ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accept rig ~ 0600 hrs 03/25/83. Perf tbg. Fished, did not recover fish. PU & std back 3-1/2" DP. Pull 4-1/2 tbg, control line balled up. Tbg stuck. Could not jar loose. Ran free point. Ran string shot & backed off tb at 1115'. Pulled 7" tbg, fish ~ 442' Jarred fish loose. Backed off at 400'±. Unballed control line & free 4-1/2 tbg. Set storm choke on 4-1/2" tbg & set in 7" tbg. Reland 7", release RTTS & LD 4-1/2" tbg. LD 7" tbg. Mill Packer. POH, recovered pkr. CO. Set RTTS, ND stack & spools, NU new landing spool. Rel RTTS. TIH w/FBHA (to of fish ~ 850'3'). (Cont'd on attached page) 13. Casing or liner run and quantities of cement, results of pressure tests N/A 14. Coring resume and brief description N/A 15. Logs run and depth where run Free pt. indicator fr/1175'-1180' CCL fr/1175'-1180' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED~~~"~~ TITLE Area Dri l 1 ing Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate NGI #7 DRILLING HISTORY Accept rig @ 0600 hrs 03/25/83. Pulled BPV. RIH & perf tbg. Left gun, CCL, cable head & 3-4' wire in hole. Attempt to fish, did not retrieve fish. Top of fish @ 8503'. PU & stand back 3-1/2" DP. Set BPV. ND tree. NU BOPE. Pull BPV. Pull 87 jts 4-1/2" tbg w/control line balling up. Tbg stuck unable to work up or down. Attempt to jar loose, failed. Run free pt. indicator, pipe stuck @ 1180'. Run string shot and back. off tbg @ 1115'. Pull 36 jts 4-1/2" tbg. Pull 25 jts 7". Ran 10 jts 7" back in hole. Fish @ 442'. RIH w/fishing assy and jarred fish loose, moved only 30'. Backed off at 400'±. Pull 10 jts 7". Unballed control line & free 4-1/2-" tbg. MU storm choke & RTTS on 4-1/2" tbg and set in 7" tbg. Reland 7"-tbg. RIH, release RTTS & LD 4-1/2" tbg. Pull & LD 7" tbg. Retrieve K-anchor. Mill Packer. POOH, recovered pkr. RIH w/9-5/8" csg scrpr & CO. RIH, set RTTS. Tst 9-5/8" csg. TOOH w/RTTS. MU storm choke on DP. RIH & set. ND stack & spools, NU BOPE & new landing spool. Tst BOPE. RIH & rel storm choke, POOH. TIH w/Fishing BHA. Top of fish @ 8503'. Work over fish. TOH w/FBHA, recover fish. MU bit & CO to PBTD. POOH. RIH w/pkr on DP and set @ 7399'. POOH and LD 3-1/2" DP. Ran 130 jts 7", 29#, 8rd tbg compl string and 53 jts 7", 26#, IJ4S tbg. Land tbg. Set BPV, ND BOPE. NU tree & tst. Pull BPV. Set inj. valve. Set BPV. Secure well & release rig @ 1000 hrs 04/09/83. #12 (cont'd) Recover fish. CO to PBTD. Set Pkr. POOH & LD 3-1/2" DP ' Ran 130 jts 7" 29#, 8rd tbg compl string & 53 jts 7" 26#, IJ4S tbg. Release rig @ 1000 hfs 04/09/83. ..... -- " ~-., STATE OF ALASKA " ALASKA £ .'AND GAS cONSERVATION CO~'~AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONSY · Drilling well X~( Workover operation [] 2. Name of operator 7. Permit No. 'ARCO Alaska, Inc. 76-38 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20210 9. Unit or Lease Name UM Prudhoe Bay Unit 4. Location of Well 216' S & 989'E of NW cr Sec 12, T11N, R14E, at surface 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 47' RKBI ADL 28302 10. Well No. NGI #7 (11-12-11-14) 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of. Ma rch ,19 83 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accept rig @ 0600 hfs 03/25/83. Perf tbg. Fished, did not recover fish. PU & std back 3-1/2" DP. Pull 4-1/2" tbg, control line ba]led up. Tbg stuck. Could not jar loose. Ran f'ree point. Ran string shot & backed' off tbg at 1115'. Pulled 7" tbg, fish @ 442' Jarred fish loose. Backed off at 400'±. Unballed control line & free 4-1/2" tbg. Set storm choke on 4-1/2" tbg & set in 7" tbg. Re]and 7", release RTTS & LD 4-1/2" tbg. LD 7" tbg. Milling packer as of 03/29/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description N/A 15. Logs run and depth where run Free pt. indicator fr/1175'-1180' CCL fr/1175'-1180' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Area Dril ling Engineer SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by ~-,~/,5~1~1~ ~he succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate NGI #7 Drilling Hi story Accept rig @ 0600 03/25/83. Pull BPV. RIH & perf tbg. Left gun, CCL, cable head & 3-4' wire in hole. Attempt to fish, did not retrieve fish. Top of fish @ 8503'. PU & stand back 3-1/2" DP. Set BPV. ND tree. NU BOPE. Pull BPV. Pull 4-1/2" tbg. Pull 87 jts w/control line balling up. Tubing stuck, unable to work up or down. Attempt to jar loose, failed. Run free pt. indicator, pipe stuck @ 1180'. Run string shot and back off tbg @ 1115'. Pull 36 jts 4-1/2" tbg. Pull 25 jts 7". Ran 10 jts 7" back in hole. Fish @ 442'. RIH w/fishing assy and jarred fish loose, moved only 30'. Backed off at 400'+. Pull 10 jts 7". Unballed control line & free 4-1/2" tbg. MU storm choke & RTTS on 4-1/2" tbg and set in 7" tbg. Reland 7" tbg. RIH, release RTTS & LD 4-1/2" tbg. Pull & LD 7" tbg. Retrieve K-anchor. Mill packer as of 03/31/83. CSM/DH8' 1 lm 04/14/83 ME MORANOU M ~ . TO: .... '"/ It'll/! DATE: C. V March hat~~°nC .~ FILE NO: T~i~U: ~ie ~. ~th TELE~O~E ~0: ' C~ssioner FROM: '~ SUBJECT: ~troleum InS~o~ State of Alaska 29, 1983 BOPE Test on ARCO's NGI-7, Nabors IES Workover Rig. Sec 12, T11N, R14E, MU~I Permit 76-39 (Redrill} .~atur~,~:.~F_ch.26,~.:1983_~~ I travelled this date from ARCO K~a~ (S~Je~ of another report) to ARCO NGI 7, Nabors 1-ES to witness a BOPE teSt. The Nabors rig was in the process of ntppling up. .~un~.~....y,~27,. 1983= The BOPE test commenced at 7=a.m. witnessed the' annular ~eventer ~hich tested to 2500 psi satisfactorily, i also witnessed the upper pipe rams, the blind rams, the H.C.R. valve and the last three valves on the Down Stream side of .the manual choke tested to 5000 psi.. I also witnessed the inside valve on the choke valves, the check valve, inside valve on kill line and the two inside valves on the mud cross tested to 5000 psi. There was a leak on the tubing hanger and we could not finish the rest of the BOPE test, I informed Mr. Clay Boudreaux the state of Alaska would have a representative present to finish the rest of the BOPE test. I informed ~arold ~edlund, Engineer on we~-end duty about the problem on this job. i fille~ o~ the AOC4~C BOPE test report which is attached to this report. In summary I witnessed the BOPE test as listed in this report for ARCO's NGI-7 - Nabors i-ES. 02-00IA(Rev. 10/79) ~3-~ .%4 4/8o STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~g,r '~-~ Operator ~ ~.f~, , Location:. Sec.. / % Drilling Contractor ~ . Well ~/~ -~ Representative ~__/~ ~ ~ ~'~'X% ~ Casing Set ~ ft. Representative ~ '~z~.~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular P/eventer Pipe Rams Test Pres sure .. · Blind Rams Choke Line Valves H.C.R. V~,ve Kill Line Valves Check Valve ACCUMULATOR SYSTEM Full Charge Pressure psig Pressure After Closure psig 200 psig Above Precharge Attained: Ful% Charge Pressure Attained: .. N2 ~si$ Cqntrols: Master' Remote Blinds switch cover -- -. ..... ._-.-.-- , ., ,,. Kelly and Floor Safety Valves ' Upper Kel 1 y Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves Test Pressure Test Pres sure Test Pressure Test Pressure .. Test Pressure No. 'flanges Adjustable Chokes [lydrauically operated choke Test Results: Failures Test Time .hrs .... Repair or Replacement of failed equipment to be made within' ' days and'"" Inspector/Commission office notified. Remarks: ~Xw 9:3~ ' [~' 3~ Dis tribution orig.' - AO&GCC cc - Operator - Supervisor. Inspector min sec min sec ARCO Alaska, Inc. ~ Post Office B~,.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Harch 18, 1983 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: NGI-7 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. repairing the communication to the 4-1/2" annulus. Since we estimate starting this work on March 21, prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG2L235:1 lm Encl osures We propose 1983, your Alaska Oil & Gas Cons. C°mrnis$iol~ Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA, ,L AND GAS CONSERVATION CC,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-38 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20210 4. Location of Well Surface: 216' S & 989' E of NW cr Sec. 12, TllN, R14E, UN 5. Elevation in feet (indicate KB, DF, etc.) 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number NGI #7 (11-12-11-14) 11. Field and Pool Pru~lhoe Bay Field 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool ADL 28302 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well I~ Change Plans [] Repairs Made [] Other [] Pull Tubing ~( Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc.)proposes to repair the communication to the 4-1/2" annulus. The 4-1/2" tubing & 7" circulating string will be pulled. A 9-5/8" retrievable bridgeplug will be set while the 4-1/2" tubing spool is removed and the. 7" spool is replaced. The packer and 9-5/8" casing will be pressure tested and repaired a necessary. Th~ well will be recompleted with a new 7" completion string with all necessary provisions for subsurface safety equipment. A 13-5/8", 5000 psi, RSRRA BOP stack will be used on well work performed by the workover rig. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid wil'l be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start - March 21, 1983 RECEIVED MAR 2 ]983 Alaska 0il & Gas Cons, Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~~~~_.~~~ Title Area Dri 1 1 i ng Engi neet The space below for Commission use Date Conditions of Approval, if any: I.l]~;~JE C. SMITll Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 GRU2/SN13 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Septeml~r 14. 1982 Mr. Robert Area Paleontoiogi st Union Oil Company of California P.O. Box 6176 Ventura, Cali fornia 93006 Preparation of Foraminifera! Samples and Palynologic/Kerogen Slides - ARCO NC.l-? Dear Bob, Our reoetpt ~eptember 13th of the foram, palyn and kerogen slides and residues on the ARCO Prudhoe Bay NGI-? completes the project set forth in my June 18, 1982 letter to you. The slides all appear to be top quality and ac¢ordingl~ represent a valuable ad~ition to the State's permanent reference library of well sample and core material~. On b~half of the Commission, please accept my thanks to you, Go C. Brown and all Union ~ersonnul involved in pre. ring these slides from state well samples. cci ¢. C. ~rown wva / 9 Ih Union Oil and Gas ~'~4sion: Western Region Union Oil Company of California 2323 Knoll Drive, P.O. Box 6176, Ventura, California 93006 Telephone (805) 656-7600 un.19n Paleo./Stratigraphic Section September 2, 1982 Mr. William Van Alen State of Alaska Division of 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99S01 Dear Bill: We are sending you by registered mail one box containing both the paly slides and residues and the foram slides and washed residues from the ARCO, NGI #7 well. We appreciate your continued assistance in these projects. Yours truly, Robert A. Ballog Area Paleontologist PleaSe acknowledge receipt and return one copy of this letter tome. ~.//~/~~~ Received b Date: ,~/~/~/~'~" RAB/plh (0049p) RI CEIVED S EP 1 1.982 0il & C-as Cons. Anch0rag0 ARCO Alaska, Inc. Post Office Bo 0 Anchorage, AlasK~.~ 99510 Telephone 907 277 5637 July 12, 1982 Mr. Co V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. Chatterton- Enclosed are monthly reports for June on these drill sites' 2-24 14-22 2-25 15-6 6-17 18-1 13-22 18-2 13-25 1E-13 13-26 1H-8 14-15 Also enclosed is a well completion report for Kuparuk 1E-12, and subsequent sundry reports for' 3-14 14-6 4-9 15-3 4-15 Eileen No. 1 11-4 NGI-7 (Since the information on the Eileen well is of a confidential nature, we would appreciate it if you could store it in a secure a rea. ) Surveys for 2-22 and 13-21 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG: I lm Enclosures GRU1/L48 A~CO AI35k,! Inc ,', a s~it~sid~,3ry O! /'~llRnl~.':P~chh~.! 'f:(: t~l~l;:'~ STATE OF ALASKA ~ ALASKA ,.,IL AND GAS CONSERVATION CL, MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-38 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20210, OTHER [] 4. Location of Well Surface: 216'S & 989'E of NW ct, Sec. 12, T11N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 47' RNB 12. I 6. Lease Designation and Serial No. ADL 28302 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number NGI #7 (11-12-11-14) 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other XJ~ Pull Tubing '[] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). The proposed work described in our Sundry Notice, dated 05/21/81, has not been performed. Also, the work is not scheduled to be done in the immediate future. RECEIVED J U L ! 2 ]982 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~r-~~ Title Area Drilling Engineer Signed The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU1/S5 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1982 Mr. Robert Union Oil Company of California 2323 Knoll Drive Ventura, California 93003 Preparation of Foraminifera1 Samples and Palynologic/Kerogen Slides -- ARCO Dear Bob, ~irsuant to our recent discussions, permission is hereby granted to Union oil Company of California to extract a maximum of 1 cc. of sample (cuttings) material per sample envelope and 1 cc. of core material per foot of core fr~ the State's set of samples and core ~hips for the sole purpose of preparing foraminiferal samples, palynologic ~lid~s and TAI/~erogen slides within th~ indicated interval in the following well, subject to the conditions set forth below~ Sample Set Ng, we11 .I.n..te~rval 370 ARCO Prudhoe Bay #NGI-7 2,730"-8,635' COnDITIOnS . _ Foraminiferal, Palynologic and TAI/Kerogen slides of cuttings material wilt be prepared in 90 foot composites; slides of core material will be in five foot composites. The foram assemblages shall not be glued to the slides. 3~ Cuts of the ~ample and/or core material from the State col lection are to be extracted only from those individual en~lopes or bags in which total content of cuttings or core material 'is greater than 10 cc. (No cuts are to be extracted if the volume of material in the individual envelope is less than 10 cc. ) Union will provide the State with a list of the s~cific sample and core footages from which material was extracted. .~]ne 18, 1982 6~ One co~posite set and one screened set of palynologtc ~ltdes~ one set of k~rogen slides, and one ~t of foram slides are to ~ prep~d fo=. t~ a~ve 211 slides pre~ared are to be received by the Cc~mission by September 21~ 1982, and are to be transmitted d~rect to the C~mission and not exa~Aned by outside pa=ties. 7~ All residue and excess material is to ~ returned to the Cc~m~ssion and no slides or sample ~aterlals are to be retai~d by Union. analyses made w~thout specific consent fr~ th~ C~ssion. Union shall ~ar all costs entailed. We look forwar~ to your company's continued exercise of care and goo~ Judgement ~n the 'handling of this l~m~ted ~an~i~y of ~11 ~terial. I ~ ~ ~th un~rstand tha~ t~e State's well ~am~le lihra~ is ~bltc pretty a~d t~t granting Union ~iss~on to e~ract ~rtions o~ ~ter~al fr~ this li~a~ for the ~ur~se of pre. ring the in~te-d slides e~an~s the ~lue of the libra~ WVA/glh ~ NGI #7 Table I Grouping 8050-8059' 8060-8069' 8070-8079' 8080-8089' 8110-8119' 8140-8149' 8170-8179' 8!80~8189' -r- -- ,,__, , 8190-8199' 8200-'8209' 8210-8219' Depths Represented 8055, 8058' 8067' 8076, 8078' 8083, 8084, 8088' 8111' ' 8140' 8178' 8181, 8183, 8186, 8188' 8].90, 8192, 8194, 8195, 8197, 8199' 8201, 8202, 8203, 8205, 8206, 8208' 8210, 8212, 8214, 8216, 8218' F£~ £ 6 1982 '/~Choi'ar~c]Gas COns Ooit~a~i$$iol~ Of) ' .~ ' 4~ ~ ~ ~ ~o Depth ~ m m ,. :: . ~ ~-.'" ,,.. ,. , ~ ,,. ..... ~ o~= ' .46 .'471 ou~u-o(,39 3 .12 3 ' 80 20 ...... L , , ,. ~. ,. , ........ 8060-8069 ' 2.28 · 09 3.95 30 70 ~ ,.., , , , ..... ~ , 8070-8079' ~' 1.56 . 15 9.62 75 25 . ., . ., . 8080-8089' ' 7.92 3.60 45.45 95 5 --,.. ......... . ...... , ..... ,. ,, 8111' .2.00 .01 .50 50 50 .... ..,. 8140' 1 58 .03 1.90 90 10 :- .. ., :: , , _ ,-..: ......... , ..... , ., ,, ,, ., ~ ...... 8178' 3.16 1.73 54.75'100 I . ~ .... ,, , ........ .. 8180-8189' 17.48 .01 .06 60 ' 40 . , , , :.~ .............. 8190-8199' 21.31 .01 ' 05 25 30 20 10. 10 5 ___ ...... , ,, , ..... ,. ,, I 8200-8209' 21.79 .12 ..55 20 '30 25 15 10 .... _ . , ..... , ..... , ., .,, , .,~ 8210-8219' 11.19 .01 .09" 50. 20 30 , ,~ ..... ..... 8220~ 4.40 .01 23 60 20 10 10 : ,,, , ........... : : -: : .. . ~_ , . ~ ,, = . _ . ,, .- I ...... ~ ..... , ................ _ __ _ , , _, ..... ,, : . . , . , " . u.~ , ,, , ........... :, *"~Opaqu'~s'include nonreflective minet'als such as pyrite, inagnetite, ilmenite, etc. (,))'/0 February 10, 1982 Mr. Dick Brown Amerada Hess Corporation 1200 Milam - 6th Floor t{ouston, Texas 77002 Re= Petrographic Thin Sections of Core Chips and Heavy Mineral Analysis Report -&aCC Pru-dhoe Bay NGI #7 The attached copy of your February 3, 1982 transmittal sheet reflects the 24 thin sections and 14 heavy mineral slides received here Februar~ 9, 1982 in connection with the subject project set forth in ~l October 9, 1'981 letter to you. The slides were received, in good condition. We note that the thin sections sent do not include the following depths from which samples of core chips were taken~ 8078, 8084, 8088, 8040, 8178, 8183,_ 8188, 8190, 8192, 8194, 8197, 8199, 8202, 8208,. 8210, 8212, 8214,. 8216, 8218, 8220. Unless I hear otherwise from you, I will assume that thin sections are being prep&red at these depths and wi1! be sent shortly. w/Il we see you and/or Cliff up here for the Western Alaska ~ymposium February 17th and 18th? Sincer~ y, William Van A!on Petroleum Geologist En¢losure~ Februa~l 3, 1982 transmittal sheet January 20, 1982 inventory of special materials WVA/glh Heavy Mineral Separation and Summary Arco NGI #7 Well, North Slope, Alaska Procedure Heavy mineral separation was performed on core chips from the Arco NGI #7, Prudhoe Bay, Alaska. Where possible, samples were grouped into 10 foot intervals to facilitate analysis. A complete listing of samples examined is given is Table 1. Following disaggregation of the samples using a porcelain mortar and pestal, the fine fraction was removed using a 200 mesh sieve. The remaining samples were placed in test tubes along with bromoform, centrifuged 15 minutes at 2250 rpms and allowed to settle an addi- tional 15 minutes. The test tubes were frozen in liquid nitrogen and the lower portion of the test tube, containing the heavy fraction, was removed with a saw. After thawing, the heavy fraction was poured into filter paper and washed with acetone. The samples were air dried, mounted on glass slides with Canada balsam and examined using binocu- lar,.petrographic and scanning election microscopes. The minerals were identified by using a combination of optical properties and ele- mental analysis obtained through use of an EDX system. Results of the analysis are given in Table II. · Prepared By' S.B. Pluim & J.F. Dichiara Amerada Hess Corporation. P.O..Box 2040 Tulsa, Qklahoma 74102 FEB 1 o Oil & Gas Cons. Anehora,qe At l'O: Wi 11 i am Van A1 en Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ...February 3, 1982 5¥';bh' f!-.C~ ................................................. 1200 Milam Street 7t_b. Houston, Texas 77002 David A. DesAutels 1) [: PA !~,1 lvl El N l Exploration/Frontier Areas VIA i DAI'IJ .%HIPPED Mail ~ 02-03-82 OUANTII'Y DESCRIPTION _ Sample material from the ARCO NGI #7 Well, North Slope: Alaska. 3..._Th Unused sample- 8178, 8083, .8084, 8088 in t~o envelopes. _Hea_ vy Min'era. 1 S lides-~ .... ~..'~-~_.~ ]. ? J ..~/-) Alaska Oil & Gas Cons. Commission Anchorage l~fr. Dick Brown Amera4a ~ess Co.ration 120'0 Mtlam- 6th Flor ~ouston, T~as 77002 Rez Thin. sapiens of core chips and heavy mineral analysis - ARCO ~r~e Bay NGI ~7 D~ar Dick, ~rsuant to my discussions with 'David DesAutels. and you October 8th and 9, 1981 respectively, permission is hereby granted to Amerada Bess Corporation to ~tract a maximum I cc. of sample material per sample envel~ or I cc. of core material per foot of core from the State's set of samples and core chips on the subject well for the ~rpose of com4uoting the analysis and preparing the petrographic thin-sections within the fo/lowing respective intervals, s~bject to the conditions set forth belows ARCO ~u~oe Bay NCI ~7 -~tr~raphi¢ thin-sections cores 1, 2, 3~ -Hea~f mineral analysis samples core chips 8055'-8217' 7900'-$055' 8055'-8217' C~s of the sample and/or core material from the State Collection are tO ~ extra~e~ only from those individual envelopes or ba~s in whi~ total content of cuttings or core material ~s ~eater than 10 cc. (No ~uts are to ~ extracted if the ~lu~ of ~erial in the individual envelope is less than I0 CC.) ~ra4a ~ess will provide the C~ssion with a list of the ~cific sample and core f~tages from which ~terial was All thin~ections, a hea~-mineral analysis report and all residue materials are to ~ s~tted to the C~sslon prior to P~rua~ 15, 1982. 2 ( .chef 9, 1981 '6. All materials are to be transmitted direct to the Commission and not examined by outside parties. No other anaiyses are to be conducted nor other materials prepared fr~ these cuts of samples and cores without specific consent fro~ the Co~missiono Ams=ada Hess' ~all bear all oosts entailed. It is.~understood that an Anchorage employee of Marathon Company will be d~signated to make the cuts. of the samples and core Chips. for shipment to Amerada Hess. A aopy of this letter is being sent to Tom Wilson so the Marathon designee can be advised of the sampling stipulations. we are pleased to work with you in this beneficial project and look forward to your company's exercise of care and good judgement in the handling 0f this li~ted quantity of well material. I know we ~th understand that the State*s well sample library is public property and that granting Am~rada Hess permission to -extra'c~-~ portions of material from this library for the purpose of preparing the indicated slides and conducting the heavy mineral analysis enhances the value of the library and is in the public interest. ~nclosure ~ AdditiOns to ~arch 16, 1981 inventory of special cci .Tom Wilson Marathon Oil Company P.O. Bc~ 2380 Anchorage, Alaska 99510 ARCO Alaska, Inc. ~ Post Office B_ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 20, 1981 Mr. Hoyl e Hami 1 ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI #7 Dear Mr. Hamil ton: Enclosed please find the Sundry Notice of Intent for NGI #7. Sincerely, p. ^. YanDusen District Drilling Engineer PAV/KJG:sp Enclosure RECEIVED MAY 2 1 1981 Alaska 011 & Gas Cons. Commission A~ohorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA /'% ALASKA ~,~L AND GAS CONSERVATION CL.,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS' 1. DRILLING WELL I-I COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK 99510 4. Location of Well Surface- 216'S & 989'E of N~'~ cr Sec 12, TllN, R14E, UM 7. Permit No. 76-38 8. APl Number 50-029-20210 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number NGI #7 (11-12-11-14) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 18' Gravel Pad, 47' RKB I ADL 28302 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 1 1. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to replace the 4½" tubing in this well with 7" tubing. The larger tubing is needed to increase the injection capacity of the well. The 4½" tubing string and the 7" circulating string will be pulled. The 9-5/8" casing will be checked for leaks and repaired as necessary. The well will then be recompleted with new 7" uncoated tubing. A 13-5/8" 5000 psi WP RSRRA BOP stack will be used on well work performed by the workover rig. The BOP equipment will be pressure tested each week and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Necessary provisions for subsurface safety equipment will be run in the completion string. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on wireline work as necessary. The downhole safety valve will be installed and tested upon conclusion of the job. Estimated start: 6/15/81. RECEIVED 2 ] 1981 'AI~sP~ Oi~ & 8~ Oons. Oommisslor~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ . . Title District Drilling Engineer The space below for Commission use Conditions of Approval, if any: Please notify the Commission so that a representative may be present to witness the initial testing of BOPE before downhole work commences. OlIIGINAL SIGNEt) ~,ppl~V~ Co~ 8v Order of ~-.'/~//~/ Approvedby ~Y l. Ofl~JE B,S~Tlt Returned COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 II ~ Submit "1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company North Alas~?'~. ist rict Post Office :..JX 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 7, 1980 Reference: ARqO Cased H~$e?~i~s D.S. 2-9 9/21/80 CNL Run 3 5" D.S. 2-7 10/15/80 CNL Run 2 5" 1'0/1/80 EPL Run"l 5" ' ._.cOM r ] ENG 3 ~I'-,~ 3 ~OL '_ STAT TE~ CONFER: FILF: Please sign and return the attached copy as receipt of data. .o Mary F. Ke!lis North Engineering Transmittal #781 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO ,j'~, ~ Jj ~ JV E D . MARATHON~../].. /"//~ ' ,:2 ~ ,"~/~/L CHEVRON fpo/'/v~,-6,'~"~-'--~'?~~-''- ~' ~ Alaska 0il & Gas Cons. Commission A~ ARCO Oil and Gas Company is a Division o! AtlanlicRichfieldCompany ARCO Oil and Gas Company North Ala~,'~"~.Di st rict Post Office .,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 21, 1980 Reference: ARCO Pressure Surveys D.S. NGI 7 10/1/80 Pressure Survey COMM.. - RES ENG~ .. i I 2 ENG 3 ENG 4 ENG ~ -STAT TEC-- . STAT TE~ · ~Please sign and return the attached copy as receipt of data. Mary Kellis North Engineering TRASNMITTAL #729 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG; MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE;OF ALASKA CHEVRON 'ARCO oil and Gas Company is a Division of AtlanticRichlieldCompany ARCO Oil and Gas Company North Alask~'"~istrict Post Office x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 20, 1980 Reference: ARCO Magentic Tapes NGI 7 ~~l~ase 9/29/80 Tape #SP 7950-8550 sign and return the. attached copy as receipt of data. Mary Kellis North Engineering TRANSMITTAL #728 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE. OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division o! AtlanticRichlieldCompany ARCO Oil and Gas_Company North AlaSl qstrict Post Office uox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 2, 1980 Reference: ARCO Cased Hole Finala D.S. 12-2 5/4/80 Carbon/Oxygen Run 1 D.S. 11-4 7/26/80 Compensated Neutron D.S. 6-15 8/2/80 Collar Log Run 1 D.S. 6-15 7/25/80 Sonan Run 1 D.S. 6-15 8/2/80 Compensated Neutron D.S. 6-15 7/25/80 Diff Temp Run 1 5" Run 1 5" ~'~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TRANSMITTAL #65~ DISTRIBUTION North Geology "'" R&D Dri l l i ng Eng. Manager D&M Geology State of Alaska ARCO Oil and Gas Company is a Division of AtlanhcRichfieldCompany Exxon Mobil Getty Phillips Sohio Marathon Chevron / / ARCO Oil and Gas Comp;my Alaska Post Offiu,_~Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 I~_._~.~__o ~__~_~ ~ I---i-Ti~-~s ~u~ r-- I--'['~ ~N°~I '. s~P~ ~smm~ I-.!-~-~N~ I 'i'~r~-! ' ' State of Alaska DATE' ~ugust 21, Division .of Oil [ 'Gas Conservation ] i 3 GEOL~ s00i Porcupine Dr, l~.srArr~d7j .Anchorage, AK 99501 ~~ ~.~ STAT TECt Attn: ~m. Van Allen Arco _ . N~ffi: N. Gas Injection ~7 [[ILF: SHIPPED TO: OPERATOR: core chips' s~.~.s s..~: 80~ - 8~0 8191- 8277 827§.- 8380 8381 - 8479 NIBtBER OF BOXES: $ in 1 big box 8480 - 8606 AUG 2. '1. 'i§79 (Paleo Lab Tech). '.. SHIPPED COPY OF ~IS FO~ TO: -. ARCO OIL ~ GAS CO. P. O. BOX 360 .ANCHORAGE, ALASKA 99510 ATTN: DICK BROOKS DATE ARCO Oil and Gas Company is a Division of AtlanticRichlieldCompany North Alasl<a District Post Office B~50 Anchorage, A xa 99510 Telephone 907 277 5637 ) Mr. Ho'yle Hamilton · State of Alaska Department of Natural Resources .Di.vision of Oil and Gas 3OO1 Por'cupi ne Dr i ve Anchorage, Alaska 99501 GE( ST~'T Subject:. Core Summary N.G'. I. //7 Dear Mr. Hamilton: Enclosed please find the Core Summary for NGI #7 submitted as Item No. 36 on Form P-7 for the above well. Very truly yours, ARCo OIL & GAS, A Division of Atl-antic Richfield Company R. A. Mc lntosh DiStrict Geologist' RAM: G FP: j ea Enclosure ATLANTIC RICHFIELD COHPANY NGI-7 Core Summary Co re # 1 2 4 5 6 7 8 10 11 12 Dep,~h~ 8055 - 8102 8102 - 8161 8161 - 8217 8217 - 8275 8275 - 8289 8289 - 8295 8295 - 8336 8336 - 8395 8395 - 8450 8450 -'8495 ,,Recovery 36 59 56 57 7 4 28' 55' 45' 8495- 8555 85'55 - 8615 60' 60' Li,thology, Sandstone and conglomerate Sandstone and shale Shale and sandstone Sandstone and conglomerate Cong ]ome rate · Conglomerate and sandstone Sandstone and conglomerate Sandstone and conglomerate Sandstone and shale Conglomerate, sandstone and shale Sandstone Sandstone and shale Shows ~laS Ga s Gas Gas Gas Gas Gas Gas Gas .Gas Gas Gas .p?rosity fair poor-to good poor to excel lent good to excellent fair fair to good fair to excellent good to excellent fair to excellent fair to excellent good to excel!en.,/ fair to good Atla, nticR~,qalfield Company North American Producing Division North Ala~ Oistrict Post Office ~bx 360~ Anchorage, Alaska 99510 Telephone 907 277 5637 March 12, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Core Summary N.G.I. #7 Dear Mr. Hamilton: Enclosed please find the Core Summary for NGI #7 submitted as Item No. 36 on Form P-7 for the above wel 1. Very truly yours, ARCo OIL & GAS, A Division of Atlantic Richfield Company R. A. Mclntosh District Geol ogi-'st RAM: G F P: j ea Enclosure 02-001B (Rev. 10/76) STATE of ALASKA Department of Natural Resources Division of Oil and Gas Conservation TO: FROM: Fran Jones Librarian Bill van Alen Petroleum Geologis~ DATE: FILE NO: TELEPHONE NO.. SUBJECT: December 11, 1978 Atlantic Richfield Prddhoe Bay NGI#7 "Tickle File" - March 1, 1979 The drilling history, submitted with the P-7 cc~pletion report indicates that 12 cores were cut in this well. Although the well was ccmpleted 7-15-76, the required core description data (p-7 Item 36) has not been submit~ to the State as of the date of this msmo. Upon bringing this to the attention of ARCO's Pete van Dusen, John Glazer and Gary Player, the latter advises that the required core description will be submitted to the state approximately March 1, 1979. (Note: The required core chips were su~z%itted 11/16/78 follc~ing notification to Pete van Dusen on the date that neither chips nor the descriptions had been ~!_h~itted. ) AtlanticRichfieldCompany North Am~"~a~n Producing Division Alaska RE_ , Post Office Box 360 Anchorage, Alaska 99510 Telephone. 907 277 5637 SAMPLE TRANSbiI TTAL SHIPPED TO: State of Alaska Division of 0il and Gas Conservation 3001 Porcupine Dr. Anchorage, Ak. 99504 Attn: Mr. Wm. VanAllen OPERATOR: ARCo NA\[E: SAMPLE TYPE: core chips DATE' November 16,1978 North Gas Injection #7 NUMBER OF BOXES: one SAMPLES S~NT: 8055 - 8608' SHIPPED BY' UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED .~o.~ o~ ~.~ ~o~ ~o: ' R EC E IV E D RECEIVED BY' ATLANTIC RICHFIELD C0. P. O. BOX 560 Anchorage, Alaska 99510 Attn' R. L. Brooks AtlanticR~'chfieidCompany North American Producing Division North Alas~istrict Post Offic.e ,..,.,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 15, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #2 Permit No. 75-52 NG · Permit No. 75-69 Permit No. Permit No.. 76-68 NGI #10 Permit No. 76-69 Dear Sir: Enclosed please find a Completion Report for the abo~e- mentioned wells. Very truly yours, ~/~- Frank M. Brown District Drilling Engineer FMB:lr Attachments ": ,-: SUBMIT IN D~,~s3~ITE* -~ STATE OF ALASKA {$eeotberln- structions on reverse si,lc,, OIL AND GAS CONSERVATION CO/I~MITTEE i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* t,,. T~PE 6F WELL: b. TYPE OF COMPLETION: %VELL OVER Other Gas Iniection Other Perforated 2. NAME OF OPERATOR Atlantic Richfield Company ~. ADDRESS OF OPERATOR P O BOX 360 Anchorage. Alaska 99510 4. LOC^T~ON O¥ WELL (Report location cYea~:ly and in accordance with a~y State requirements)* at~c~ 216'S & 989'E of N W cr Sec. 12, TllN-R14E, UM At top prod. Interval reported below 270'S & 1034'E of NW cr Sec. 12, TllN- R14E, UM At total depth $. AP1 NU-M.F-,PdCAL CODE 50-029-20210 6. L~SE DF-~IGNATION A. ND SERIAL NO. - ADL 28302 7. IF INDiA, N, ALLOTTEE OR TH1BE NAME 8. UNIT,FAtl3/I OR LEASE NAME ,,, 9. WELL NO. ' NC! #7 (11-12-11-14) 10. FLELD A2qD POOL, OR WILDCAT ?rudhoe Bay Field/prudhoe u. sec., .., ~., ~., (eo~o~ ~ Pool O~E~IVE) Sec. 12, TllN-R14E, UM 1~. P~'P. MIT NO. 272'S & 1044'E ,of NW cr Sec. 12, Tlln-R14E, UM ..~5,8-7613' O.~Tr ~! 7--10--76 ~'[ 7--15--76'[ 18' gr pad, 47'RKB I'?'ELEV'CASINGHEAD 18. TOTAL DEPTH, 'NiD & TVD[19. PLUG, BACK MD & TVD~0. LF 1VUJLT1PLE COMi~L., -[ 21. VlNTERVALS -DRILLED BY ! : ! HOW MANY* ] ROTARY TOOLS I'- ' CABI,E TOOLS 8645'_& 8644' ] 8590' 85.89' ,1 Single [ All [..None, 22. PRODUCING INTERVAL(S), OF THIS COMPLETION--TOP, BOTTOM, I~AME (lVID AND TVD)' 1~3. WAS DIRECTIONAL Top Sadlerochit 8174' MD 8173"TVD }! SURVZYMADE Base Sadlerochit 8588' MD 8587'TVD I Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/BHC/GR, CFD/CNL/Caliper, CBL/VDL/CCL "~. ' .... CASING RECORD' (Report all strings set in w~ll) CASU4G SIZE wzlGI-IT, LB/FT. [ 20" 94#-Vetco 13-3/8." 9-5/8" 72#-Butt 47#-3utt ' m/_8i mi_8 DEPTH SET (MD) 80.5'bel ' 2725 ' 7735' , , HOLE SIZE [ CEMLNTING RECOF~) A3~OUNT PULLED ad 32" [ 240 sx Arcticset cmt 17%" I 4800 sx PF II cmt , 12,¼" ] 750 sx Class ~ cmt , ,[, 2nd,, o ,sta'ge 'w/275 Si" PF,, II, , SCi-LEEN i~D) J SIZE $ DEPTH SET (MD) PACKER SET ,7386'~ .... t t,, =,.,, ,. N/A :~: Q ~' ~', ........... 26. LINE~ REC OH,O 7" 7/'/'6, g6/'O' 25.0.. PEP,.FOR.ATiONS OPFSN TO PRODU,~OlhT ~interval, size and number) w/4 shots per ft. PRODUCTION ::'8553' -8563' J 8305 '-8330' ~ 8263'-8288' : 8220'-8245' 8176'-8201' ~0. DAT~ FIRST PIKODUCTION [ FI~ODUCTION ME'I[{O'D (Flowii, g, g&$ lift, ~'~': )~ u,. ~, ~q"~ [ In~ection ..... ] .~:~':~::;!~ ;:; N/A .... : ""~'~ [ [ ITEST I I o s,ooo sc o [ ~4 ~'~ ~ ~~b'~RES'SURE ICALC~T~ OI~BBL OA~M~. ' WA~BBL. [oIL GRAVITY-~I (C~.) 43o0 I I [ o S,000MSC / 1 0 I 31~ D"ISP0SlTION O~ GXS (80ld~ used lot ~ael, vented, etc.) , , TEST WITNESSED BY Reinj,ec~ed t Production Operation 32. LIST OFATTACHMENTS ...... 3~. I hereby cattily that the foregoing and attached information is complete and correct as determined from all-available records ~ SIGN TITLE District Drilling Enginaar DATE - INSTRUCTIONS General: This form is designed for submitting a compl, ete arid correct ,.,veil complet,on repot; and log on all types of lanJs and leases in Alaska. Item: 16: Indicate w~ich elevation is used as reference (where not o;herwise shown) for depth measure- merits given in cther spaces on this form and in any a~t~!~rne,qts. Items 20, and 22:: If this well is completed for separatc, prcduction from more than one Interval zone (multiple complet,on), so state in item 20, and in item o") show the prcJuc,n_q 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 separately produced, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing an5 the location of the cementing tool. Item :28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). j ,,, ~" 34. SUMMARY OF' I~O~MATION TESTS IN('LUDIN(; INTERV,~L TE~TED. t:'HF~%SURE DATA ~ ~OVERIES C)F OIL. GAS. 35 G I~OI.,OG I C' M A R KE:~R~ WATER AND MUD ., NAME MEAS D~Y'TI-I, ~U~ VIL'I1T, D~ , Top Sadlerochit 8174' 8173' Base Sadlerochit] 8588' 8587' A~D: ~E~P~'~i,) StiOWS Or O~b. GAS OR ~,, i STATE of ALASKA' FROMz Divisic~ of Oil and Gas Ccnservatic~ Director, DOGC BATE , J%~1~ 17, 1977 SUBJECT: ARCO NC~ NO. 7 Blowout I have reoei~ a copy of Fred Bcness's ma~o to you regarding legal ramnifica~ of the subject blowout. I agree with Fred and believe the precedent of collect/rig for hydrocarbons lost. Unfortunately not enough doc'urt~.ntatic~, was atL~~ at the time of the. blowout to this in the department and it would appear that .the o~ly way we could blc~uts .occur we will start docummtatic~ im~a~iat~ly and ccmplet~ly ~t throughout so that we can b~ve a legal, trail if ~o: ['--Fred Boness Assistant Attorney General Jack R. Roderick\~¢,i'¢* Deputy Commissioner DAte : April 29, ]..977 Penalty Payments to be Assessed Against ARCO and Shell for Loss oJ .H. ydrocar bons ~-%tachcd._ma~ials from Hoyle Hamilton. indicate that ~ARC~_'s NGI No..7 ~11 blew out On'June 17, 1976, in the iml-~DL~-Bay area with the loss of approximately 19.8 MMCF volume of gas and 204 barrels of condensate. The Conservation. . 'r'ecomm~~r~ Commission places a total value of $1,127 00, and" $15,000 as a fine. . .......... Shell Oil CompanY, during a nine-day period in the fourth quarter of 1976 and for 16 .days in the first quarter.of 1977, flared from approximately 50 MMCF from Platform "A", Middle Ground ShOal, in violation of CO 105-C of the Oil and Gas Conservation regulations. The Conservation Commission recommends that they be fined $5,000. Please see Hoyle Hamilton's memo to me of April 22, giving the reasons for the difference in the value of the lost hydrocarbons. Having reviewed the material, Commissioner Le Resche thinks that these two penalities should be imposed against the operators. Please prepare the appropriate notifications to the companieg cc: Robert'E. LeResche Commissioner L--Hoyle Hamilton Director, Division of Oil & Gas Conservation O. K. "Easy" Gilbreth Division of Minerals & Energy Management attachments RECEIVED MAY _ 1977 Division Anchor,..~h CONFID[I IAL STATE Olr ~ r}Ivl$10N OF .OIL & CMl -!~ ATLANTIC RIQ~IELD CO:'~g-?f North Alaska District Enginee_~ing TRANSMITTAL To: From: J. A. Rochon/p. Hellstrom D~:i Ap~ril ..14, 1977 .~. Well NGI #7 Trans~tted. herewith are the following fOr the subject well: Run No. Scale Xerox Sepia BL Line BHC Sonic/CaliPer L. og- :BHC Sonic/Caliper - Gamma Ray'. Log i' '~ BHC Sonic/Gm Ray'Log · _ .... Caliper/CCL Cement Bon~ Log/VDL · - ' ' CompermateR Formation Der~_i..ty- Log .... Compensate~ Neutron-Formation Density _. 'i Compensatea Neutron Log. .Core Analysis - Interval · . Core I~scription (S~C).- Inte~rvai ......... Core Description (Cony.) - Core NO. - .... Directional Survey - Gyro .. Single Sh~t "'' '"'-" ' ' Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation D ~e~sity Log Formation 'Density Log/Gamma Ray Gamma Ray/CCL Laterolog. Location Plat Microl'aterolog . Microlog Mudlog- Interval Sample Log (A.R.Co.)-In'terval) .Synergetic Log TVO-DIL TUD-Porosity Log CCT, r ...... . ... .... . - - -- · J,',. , -, . .L · · Receipt' Acknowledged For: Date- Please return receipt to: 'Atlantic Richfield Co.any North Alaska Engineering P. O. Box 360 . . m '- - .., LC. , ~ ~,. · , · · ,. ~, ._:_ . ,..'L_ , · · · . · North AlasKa Dlstrict kngzneer~_n§ TRANSM CONFIDENTIAL DiSTRIBUTeD TO: To: STATE. O.F ALA. KA From: :Date: April 13, 1977. Well N=-z..e' J. A. Rochon/p. Hellszrom NGI #7 ~ansmitted herewith are the following for the subject well' · ~?Rua ;-No. Scale Xerox Sepia ~L Line' BHC Sonic/Caliper L. og- BHC Sonic/Caliper - Gamma Ray L. og . . BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Lo~fVDL- Compensated Fomation Dens~.ty Log . Compensated Neutron-Formation- Density i_'~- , -' Compensated Neutron Log Core Analysis - Interval " ' '.Core No. Core Description (~,%rC) - inter~ai-"" ' · . Core Description (Cony.) - Core No'. _ --- .- - . - ._ Directional .SurVey - Gyro .-- Single Sh6t .......... · Multishot Drill Stem Test - Test No. Dual. Induction Lategolog Fomation Density Log FOrmation Density Log/Gamma Ray Gramme Ray/COL Laterolog . . _ Location Plat Microlaterolog }4icrolog Mudlog- Interval Sample Log (A.R.C~i)-InterVal) .Syn. ergetic Log TVD-DIL TVO-Porosi~ Log :Receipt Acknowledged For' Date ' %.* By: <Ptea~e return receipt to' Atlantic Richfield Co..-p.~=_ny ._=~ E C E I V E O North Alaska Engineering Mmn--=_. P. O. Box 360 ;mchorage, Alaska 9~,~i:: APl{ ] ~t 1~7 #215 OivMon of 011 & I]lt~. OoneerYatlon CONFIDENTIAL DISTI~T,.~T~D TO~ STATE OF A~S~ ~o.~IV!S!ON O~ OIL ~ ~ ~", ATIJ%NTIC RICHFIELD ORqPT~T --~ -North Alaska District Engineering T RAN S M I.TT A L . . From: J. A. Rochon/p. He,lls, tr0. m..._ April ,7, 1,977 Well Nmme' NGI #7 "Transmitted herewith are the following for the subject well: ~Run NO. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log . Caliper/CCL .. Cement Bond Log/VDL · Compensated Formation Density Log .... .,-:~Compens ated Neutron- Formation__Dens ity . ._ Compensated Neutron Log Core Analysis - Interval .. - -. · ' Core No. Core.-Description (~VC) - Interval . Core Description (Cony.) - Core No. Directional Survey- Gyro Single ShOt Multishot Drill Stem Test - Test No. - . - Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray 1 Gan~a Ray/CCL Laterolog · ' Location Plat ~ ~ MicrolaterolOg Microlog Mudlog- Interval ' --Sample Log [A.R.Co'~']'Interval) .Synergetic Log TVD-DIL TVD-Porosity Log .? ':Receipt Acknowledged For: Date · return receipt to-: Atlantic Richfield Company North Alaska Engineering Manager P. O. Box 560 Anchorage, Alaska 99510 #202 STATE DEPARl~ENT OF ~TURAL RESOURCES Division of Oil and Gas Conservation IDENTI TO: [-- Jack Roderick Acting Commissioner CONFIDENTIAL under AS 31 until 8/17/78 Hoyle H. Hamilton ~'/(l~'v rector D^TE : March 11, 1977 SUBJECT: Hydrocarbons Vented During Arc.._9_o NGI No. 7 B1 owout Easy Gilbreth, Director of the Division of Minerals and Energy Management, has advised us that CommissiOner Martin intends to require payment for hydrocarbons vented because of the blowout of Arco's ltGI No. 7 well and has asked us to provide back-up data from our "Confidential" records. On June 17, 1976, the Arco NGI ~(o. 7 blew out during completion operations and flowed with only partial c~ntrol until June 20, 1976. I flew to Prudhoe Bay on June 17, 1976 and monitored kill and control efforts until June 20; A copy of my "Confidential" report is attached. Table I estimates volumes of gas and condensate lost based on our "Confi- dential" reports and an Arco news release. Rates and volumes are very speculative as it was not possible to take measurements and the primary concern was controlling t_he flow. Based on these estimated volumes, the total value, State production tax and State royalty are estimated in Table II. A value of $5/Bbl for condensate was used as a mid-value between current compensation for Ret crude through Arco's Prudhoe Bay topping plant and estimated FY 78 Prudhoe crude wellhead value. A gas value of 30C/Mcr was used based on an interim agreement between the State and BP Alaska for gas currently being .utilized off of a lease on the North Slope. Some of the information included with this memo is confidential under AS 31 until August 17, 1978, and should be revealed only with Arco's permission. Attachments ~J~.bJm Table I Arco - NGI No. 7 Estimated Volumes of Gas and Condensate Vented During June 1976 Blowout CONFIDENTIAL' Date 6/17/76 6/18/76 to 6/19/76 6/19/76 to 6/20/76 Est. Gas Est. Gas Durati on Rate Vol ume (Hrs.) (1) (MMcf/D) (MMcf) 21.25 1'7.5 (1)' 15.5 16.25 4.4 3.0 14 2~2 1.3 19.8 Explanation (1) Initial uncontrolled flow Killing and gas bleeding phase Final killing to zero surface pressure Est. Volume of Condensate (Bbls).= 180 Bbls* X 19.8 MMcf = 204 Bbls 17.5 MMcf (1) Hoyle Hamilton's Memo to File dated 11/10/76 * Arco News Release dated 6/17/76 Table II Arco - NGI No. 7 Estimated.-Value of' State Royalty and Production Tax For Hydrocarbons Vented During June 1976 Blowout Total Value Est. Volume 30¢/Mcf & .!MMcf or Bbls) $5/Bbl Value of Value of State Prod. Tax(1 ) .R.oyal ty Gas 19.8 $5,940 $208 $743 Condensate 204 1,020 48 128 Value of Roy. & Prod. Tax $951 176 TOTALS $6,960 $256 $871 $1,127 (1) WPI Factor = 1.59 ! :~-' (3;/S ~ ~ / ¢- - 0 = k//c/ --~/~/79' ~-~orth Alas,ka Dis..trict Engineer:~-~,~ CONFIDENTIAL DISTRIBUTED TO: STATE OF ALASKA DIVISION OF OIL & GAS TRANSMITTAL From' J. A. Rochon/p. Hellstrom Date' Nhrch 3~,,!977 Well Name: NGI #7 Transmitted herewith are the following for the subject well' Run No. Scale Xerox BHC 'Sonic/Caliper Log BHC Sonic/Caliper -' Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/eCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (~VC) - Interval Core Description (Cony.) - Core No. Directional Survey- Gyro Single' Sh0i' ' Maltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog - Location Plat Microlat~rolog Microlog Mudlog- Interval Sample Log (A.R.Co'.)-InterVal) Synergetic Log TVD-DIL TVD-Porosity Log ~ CCT,. · Sepia BL Line o, , Receipt Acknowledged For' Date' By: -Please return receipt to: Atlantic Richfield Company North Alaska Engineering Manager P. O. Box 560 Anchorage, Alaska 99510 · ! ~ - , A'tlanticl~ichfieldCompany North Amer[~"~ Producing Division North Alask~ ~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 18, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #7 (11-12-11-14) Permit No. 76-38 _. i' ~ :~':~ .... ,, ~l~,~ I'' SEC CONFER:_ ~ Dear Sir' Enclosed please find our Sundry Notice of Subsequent Report detailing the work done of the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer losure RECEIVED MAR 1 1977 DMsion o~ 0ii Anchorage Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) i5. APl NUMERICAL CODE 50-029-20210 6. LEASE DESIGNATION AND SERIAL NO. ADL '28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELLm m OTHER Gas Injection ~ NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 360, Anchorage, AK 99510 NGI #7 (11-12-11-14) 4. LOCATION OF WELL At surface 216'S & 989'E of NW cr Sec 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad 14. CheCk Appropriate Box To Indicate Nature of NOtice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 12, TllN, R14E, UM 12. PERMIT NO. 76-38 )orr, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) Perfo ra ~e REPAIRING WELL ALTERING CASING ABANDONMENT* (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. See Attached. 16. I hereby certify that the foregoing is true and correct TITLE, District.. Drilling Engineer DATE February 22, 1977 (This space for State office use) APPROVED BY, CONDITIONS OF APPROVAL, IF ANY: TITLE DATE Sea Instructions On Reverse Side NGI #7 (11-12-11-14) SUNDRY NOTICE OF SUBSEQUENT REPORT Moved onto NGI #7 1-11-77. Installed & tstd surf equip. Retrieved ball valve. Tstd lubricator. RIH & perf'd w/4 shots per ft 8553' - 8565', 8305' - 8330', 8263' 8288', 8220' - 8245', & 8176' - 8201' Tbg press 1375 psi after firing. After several attempts to set ball ~alve failed, wireline operations were suspended @ 0600 hrs 1-21-77. Hooked up & circ warm Glycol. Resumed operations @~1400 hrs !-25-77. Ran press recorders. After several attempts to set ball valve failed, ran & set dummy valve. Press tstd balance & control lines 5000 psi OK. Retrieved dummy valve & pulled to 3230', wireline parted. RU & peess tstd lubricator. Wireline BOP leaking. RD & take to shop for repairs. Reinstalled & Dress tstd BOP OK. Press tstd lubricator to 5000 psi. Work suspended due to cold weather 2/1/77. RU & press tstd lubricator 2/9/77. Worked wireline fishing tools into lubricator & rec same. Reran fishing tools, engaged wireline, rec broken line & dummy valve asbly. Ran & set flapper valve in ball valve nipple. Press tstd balance & control lines 5000 psi OK. Pumped 10 drums ARCO Hib w/methanol spacer in front & behind. Displ w/206 bbls warm diesel. Final tbg press 1800 psi. Closed & operated flapper valve. Connected surface equipment to fl ow & clean up well. F1 owed at various choke sizes from 20/64" to 16/64". Min tbg press 2885 @ 48/64" choke, max tbg press 3190 @ 16/64" choke. Shut in well. Closed flapper valves & tree valves. Removed tst equip. Turned well over to Operations 2/16/77. RECEIVED MA? 1 1977 Division of Oil Anchor3go STATE Of ALASKA DEPARTMENT OF NATURAL RESOURCES Divtston of 0tl and Gas Conservatlon Hoyle H. Hamt lton//~/ Director Thru: Lonnte C. Smith Chief Petroieta~ Engineer FROM~ Harold R. ~lawkins .-~4-~ Petroleum Inspector DATE 'February 25, 1977 SUBJECT: Subsurface Safety Valve and Surface Control Safety Valve, Arco NGI NO. 7 Prudhoe Bay Honday,. Februaryr 14, 1977 - Gtl Meyer picked me up at 7:00 PM at BP's base 'camp 'and tOok me t° Arco'S NGI No. 7 gas well. $tl Meyer is the operator for Arco. A, L. Pace is manager and operator for CAMCO. This is the first CA~ subsurface safety valve that has been run for Arco on the slope. This valve is a Bll)-6 flapper type valve. This valve has a flow tube that extends inside housing of flapper valve. When hydraulic pressure from surface is applied to the valve, the flow tube slides down inside housing and applies pressure to flapper and-protrudes on past flapper in valve and seats at bottom of housing. Flapper for valve is forced in an offset in housing, as flow' tube goes by. To shut valve, the control pressure on line is relieved ' and flow tube goes back up into housing by the help of a 750 psi spring and flowing pressure. Flapper has also a small spring to help it to start closing, then well pressure is also exerted on the flapper to help seal it. The valve works on the same control lines as the Otis does. Both valves have the control and balance tine features, One thing that A. L. Pace pointed out to me was that there must be pressure on the balance line When opening the flapper or the valve could be damaged. "This CAMCO valve was set 2-13-77. The control line was pressured up to 5000 psi OK. When I arrived at NGI No. 7 they were squeezing diesel and chemicals in the tubing through the CAMCO valve. These chemicals are. supposed to adhere to the walls of the pipe to protect the metal from corrosive elements. At ll:O0 PM, the CAMCO subsurface safety valve was opened with 1400 psi on the tubing. The surface control safety valve was tested. I observed pressure above the SCSV valve bled d~own to 400 psi for 15 minutes with no buildup. At ll-30 PM there was an attempt to close the SSSV. They were bleeding through a 1/2 inch valve with no results. Gil Meyer had a crew manifold a 6 inch choke to the flow line to the pit, Tuesday,. FebruarY 15, 1977 -.At 3:00 At4 the flOW line was hooked up. The blee'~~' ~ff of"-~e 'tubing ~t-arted with no results. 'BY 4:00 AM CAMCO checked their control lines. The balance line for some reason had air in it. They purged the line with hydraulic fluid and/the line was OK~ 4:30 At4. This time the~control line pressure was relieved and the CAMCO valve closed. This was indicated on the first bleed off of 530 psi above the SSSV on the tubing which held at g50 psi for 15 minutes with no buildup. The tubing pressure was dropped above SSSV 300 psi from 950, :~L~nen to 630 psi, then bled to zero. I observed the subsurface safety at ?acli~'cirop at 300 psi for 15 minutes and at zero for 30 minutes with no build up of pressure, indicating there were no leaks and that the CAI~O BTB-6 subsurface valve held OK. There was one failure which was air in the balance line which was taken care of. Arco NG! Ho. 7 2- February 25, 1977 In sm~: I wttnes~ the ~t~ of subsurface-safety valve and surface C'~r~l' ;safety at Arce's ~lt6! ~. 7. ~ ~lves I ~~s~ ~~ satlsfactory ~ ~is ~, F~~ t4. 1977. Attac~t .:"."(::-).' (.:.)'~. :"~.:- ~e'n~?H~U~e~:~ng. . .':~ :~:~'):::(.): ~. ~est ~'~'uid:( ):~~ )mud'( )'Oi~.] :'-'(:).. (-.): .-'.~,~ ,ese~'"'~:~;(:...':::):o~n(~ }'~'~e~ ("~'-..( ) : ~' ~,s~er H.Vd, contro~ Sys.- .~ ,~i ?::'"-:'~ -' '" "".' ~) -Sa~ety.;~va:~ve 'Tests ~"-:'.(: .)':'-:( ) 19. 'Remote. uQn.~ro,l:.~ ,, ' :]..."'~) { (-)' '~. '.5-.. Surfac6g, o~-'we:]..~': ~,/; '- :(. )'. '( ) · 20. Dril.]i,~:'spoO]J. ' .outlets ':.,'.. ~'::(v)'" (-':)" .6.'-Sub:surfjCe~,'OL;::>~~. (.)' .() 2i. Ki]] Li6e:( .),-~~va]ve .:,' ' ::L-~-. '::~: '" ":;.'. L;.::'."-":~( .:),:.:~.~'.,~.TeSjE~ D2:~a' - ':-(:. )_-_. ( ) : 22... Choke F]6w~'i'ne:::(')- HCR va]'ve. '::: ;(:">):: (.")':-:"':-:.7:L'-::W611'-%~'L -':':.? :":, , , "~:-- ):;--( ) ";-'2a'.' Ch°ke ~a'h~':'fol-6:No: va]vs (,:) (-)-~. 8. Hrs'. 'obser" .;,__, . ,__ '( )-( )24. Chokes-(-)Remote( )Pos.(~d,i' .-: .... '__(')-..:.(-). -9. 'BS&W '....'_ ::-.::. . ,~ ( ) ( )25. Test ~]ug-( ')We]]hd(')csg( )none' - ( ) .(') ~'lO. Gr. Bbls."' ~ ( ) ( ) _26. Annular Preventer, psia (,) Final AbJ'ndon~ent '-- ( ) ( ) 27. Blind Rams,~sig " ( ) ( ) ll. P&A.Marker" ( ) ( ) 28. Pipe Rams . psig . (-) ( ) 12~ Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psig ()(') 13. Clean-up -( ) ( ) 30. Lower Kelly valve psig ( ) ( ) 14. Pad' leveled Total in~ection .observation time/~ ~days ( ) ( ) 31. Safety Floor valves-( .)BV ( )Dart Total number leaks and/or equip, failures~ / cc' Z~':S5 ..~''' 'Notify in' days or when ready '~s. pected by.~ ~1~-,,: .,~tlan~i~cRichfieldCompany ,~,~ North Ameri.~n Producing Division North Alas~/ ~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 3, 1977 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #7 (11-12-11-14) Permit No. 76-38 Dear Sir: Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Sincerely, Frank M. Brown District Drilling Engineer /jw Enclosures RECEIVED FEB -71977 ... An0ho~a~e ~t'.m 1~o. P--4 I~L'V. $- I-?0 STATE OF' AI.ASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. O,L []] o,s []] o,,'-, Gas Injection WgLL We. LL 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF 0PEI~TOR P. O. Box 360, Anchorage, A1 aska 99510 4. LOCATION OF WELL 216'S & 989'E of NW cr Sec 12, TllN, R14E, UM ~. API NUMERICAL CODE 50-029-20210 6 LEASE DESIG~A~ON A.%'D SESIAL APL 28302 IF' INDI^~T, ALOTTEE O~ TR1BE 8. ~,~IT FAP,~ OR LEASE NAME Prudhoe Bay g WELL NO NGI #7 (11-12-11-14) l0 FIF2~D A_~ID POOL. OR WILDCAT Prudhoe Bay - Sadlerochit Pool Il SEC,. T,. R., M. (B~i~OM HOLE oamcTrv-~ Sec 12, TllN, R14E, UM 12. PEP.MIT N'O 76-38 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INcLIJDI'NG ~EPTH SET AND VOLLrlVIES USED. PERFORATIONS. TESTS Ai~D RESULTS FISHING JOBS JUNK L~ HOLE AND SIDE-TRACKED HOLE AND A~Y OTi, tER SIGNIFICANT CHAIqG~ IN HOL~ CON*DITIONS. Moved onto NGI #7 1-11-77. Installed &tstd surf equip. Retrieved ball valve. Tstd lubricator. RIH & perf'd w/4 shots per ft 8553' - 8565', 8305' -8330', 8263'· - 8288', 8220' - 8245' , & 8176' - 8201'. Tbg press 1375 psi after firing. After several attempts to set ball valve failed, wireline operations were suspended.- @ 0600 hrs 1-21-77. Hooked up & circ warm Glycol. Resumed operations @ 1400 hrs 1-25-77. . Ran press recorders. After several attempts to set ball valve failed, ran & set dummy valve. Press tstd balance & control lines 5000 psi OK. Retrieved dummy valve & pulled to 3230', as of January 31, 1977. RECEIVED FEB - ? 1977 Division ot Oil and I~aa ~eneemation 14. 'I hereby ce~ that the foregoing ' true and correct S~G~ ~ /q ~ =~ ..D,:is~-:i¢-t-Drillin~q Enainee~^~ NOTE---Report on this form is required for .each calendar month~ regardless of tho status of operations, and must I)o filed in duplicate wltl~ the otl Qnd gas conservation committee bythe ISth of the succeeding month, uflle~ otherwise directed. of ALASKA . D£PARll4ENT OF NATURAL RESOURCES Division of.0tl and Gas Conservation Dt rectar ~ ~ ? ~a.~ 0 ~. Thru: FROM: Lonnie C. Smith Chief Petroleum Emjtneer Russell A. ~ouglass Petroleum Engineer DATE 'February 1, 1977 SUBJECT: Ball valve test Arco NGI #7 pday,January 11, 1977 - Traveled to Prudhoe Bay, then to the NGI pad. os~'o'f ~- t~t'P Was t~ wt~Ss the ball valve test on Arco NGI #7. When I arrived on location they were coming out of the hole with their final perforating gun. They~ expected to get the ball valve down sometime tn the after~oon. This well will be used as a gas producer during startup of the Prudhoe BaY Fl..eld. ~dhen makeup gas is ~ lenger needed it will be converted to a gas injection well. It has a 4 I/~- inch tubing string inside a 7 inch string. In order to prevent hydrate formation in the permafrost section, heated giycol will be clrculated down the 4 1/2 inch - 7 inch annulus and back up the 7 inch- 9 5/8 inch annulus. On the first ball valve run they were unable to get the valve seated in the PBR. The control lines would not hold pressure. They pulled out of the hole and redressed the ball valve. Wednesday, January 12, 1~77 - Went back in the hole with the ball valve and~"s{iilI "Could'-~t' g~t ~'seated . Traveled to BP Sag Delta ~2 Site at 7:00 PM to witness BOP test on Parker Rig 97. Thursday, Jan.rUa. ry 1~, 1977 - Finished BOP test early this morning (3:00 AM). ~1t' f~ Arco at 5:{)0 AM.- They said they had 5000 psig on the contr°l lines and were ready to start testing the ball valve in NGI #7. Traveled to NGI pad from Sag Delta #2. When I arrived I was told they had lost pressure on the control lines and were retrieving the ball valve so they could take it into the shop and test it. Friday, January 14, 1977- Finished testing the ball valve in the shop and r~-n-b~k' i'nto ~he Well'wlth it. Still could not get it seated. Arco suspended operations on NGI #7 until they could determine what was wrong. Returned to Anchorage at 9:00 PM. In sun~ fy;_ Attempts to set a ball valve in NGI #7 were unsuccessful. The &~(a~c-t problem was never clearly defined. When tested in the Camco shop the fit was tight, but not tight enough to explatn why it wasn't seating in the Well. Arco will try to set the ball valve after completlng NGI #8. · AtlanticRichfieldCompany North Ame~n Producing Division North Alas/ ~istrict Post Office BOx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 7, 1977 Mr. Hoyle Hamilton, Director State of Alaska Department of .Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton' In response to your letter of December 22, 1976, original letter was misfiled or otherwise misplaced. would like to apologize for my failure to respond to your request in a timely manner. My responses to your specific queries in your letter of July 22, 1976, are' (1) The 'gas entry was through the shoe of the 7" liner. (2) The gas entry was determined by the recovery of considerable amounts of lost circulation material while drilling the cement above the cement retainer set in the shoe of the liner. This lost circulation material was p~ed into the well during the kill operation. Secondly, shale was found below the re- tainer inside the 7" liner. " (3) The blind ram failure was due to the utilization of inappropriate rubber elements for the particular working environment. (4) The gas entry was permanently shut off by drilling out' the cement retainer and cement to 8600'. An EZ drill bridge plug was set at 8590'. The Center for Short Lived Phenomena report indicated that 50,000 'liters of Arctic Pack escaped the well. The fluid which was forced from the well was arctic diesel fuel. Secondly, the duration of any flow of gas to the surface was &ess th~.._~?.?._~..,..days and not thirteen days. Very truly yours, C. R. Knowles District Drilling Engineer c /jw RECEIVED JAN 1 21 77 o~.ig~,~,~ Signed By (2, B. KNOWLES,' JR. /eol ,-. Conservation December 22, 1976 Mr. C. R. Knowles / Atlantic Richfield Company V P. O. Box 360 AnchOrage, Alaska 99510 Dear Mr. Knowles: In a .letter I sent to you dated July 22, 1976 additional information was requested regarding the.~__~welI blow- out. A copy of my previous letter is ~a~. I am also attaching a copy of a report prepared by the Center for Short-Lived Phenomena regarding this event. I would appreciate a timely response from you regarding my letter and the accuracy of the attached report. Yours truly, Hoyle H. H~milton Director. Enclosures: 2 · HHtt/'be ~~- o~ "'//~D..-/--)(° ~"-"~ ATLANTIC RICHFIELD C(I\~A\~ '~'~ North Alaska District En in==~in.z · CONFIDENTIAL · ~, ^ ~ ~ ~,,~ ~ '~ A ~ DIS~IB~D TO: D~ON OF OIL ~ G~ From: J. A. Rochon/p. Hellstrom Date' Dec. 14, 1976 Well N~.e' NGI # 7 Transmitted herewith are the follmeing for the subject well' Run No. Scale Xerox BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CC]] Cement Bond Log/VDL Compensated Formation-Density Log Compensated Neutron-Fomation Density CompensateR Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog Fomation Density Log Formation Density Log/Gamma Ray Gmma Ray/CCL Laterolog ' Location Plat Microlaterolog Microlog Mudlog- Interval Sample Log (A.R.Co'.')-Interval) Synergetic Log TgD-DIL TVD-gorosity Log Sepia BL Line Receipt Acknowledged For' Date' Please return receipt to' Atlantic Richfield Company North Alaska Engineering blanager P. O. Box 560 Anchorage, Alaska 99S10 .... AtianticRichfieldCompany North Amer~n Producing Division North Alas[ istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 6, 1976 Mr. Hoyle Hamil ton State of Alaska Department of Natural Resources Divison of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI #7 (11-12-11-14) Permit No. 76-38 Dear Mr. Hamilton' Enclosed is the subsequent Sundry Notice for the above-mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer CRK/cs Enclosure AND GAS Form 10-403 REV. 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports,' in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-029-20210 6. LEASE DESIGNATION AND SERIAL NO. APL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL''OraL I---! WELLGAS [--] OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL At surface 216'S & 989'E of NW cr Sec 12, T11N, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad 14. CheCk Appropriate Box To Indicate Nature of Notice, Re! 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI #7 (11-12-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 12, TllN, R14E, UM 12. PERMIT NO. 76-38 3oft, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSE(~UENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SEE ATTACHED 16. I hereby certify that the foregoing is true and correct /, (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE. DATE See Instructions On Reverse Side Accepted rig @ 0800 hrs 11-17-76. RU & tstd lubricator to 3000 psi OK. Retrieved dummy valve. Ran dummy gun w/GR/CCL log. Opened XA sleeve. Displ diesel w/lO7 bbls CaC12 wtr. ND xmas tree. NU & tstd BOPE. Unlanded & pulled 12 stds 4-1/2" Hydril tbg. 1/4" balance & control lines parted. Rec approx 1500'-2000'. Worked 6 stds tbg out of hole. Pulled tight. Worked free & ran back to btm. Stabbed into PBR. Backed off tbg @ 240'. Set Baker retrievable BP @ 100'. Chgd & press tstd 7" rams. Retrieved BP. Unlanded 7" tbg. Pulled & LD 7" string including additional 1/4" lines inside 7". Set Johnston 9-5/8" BP @ 100'. Chgd & tstd 4-1/2" rams. Retrieved BP. RIH w/8-1/2" overshot. Engaged fish @ 240'. POH. LD 4-1/2" tbg & PBR stinger. RIH w/rope spear & jars to top of PBR asbly @ 7202'. No additional 1/4" line recovered w/4-1/2" tbg. Circ hole clean. POH. No rec. RIH w/junk bskt & 1 jt 7" WP. Rev hole clean. POH. No rec in junk bskt. Set retrievable BP @ 1000'. ND BOPE. Removed old style Gray pkoff. Installed & tstd new style Gray pkoff to 5000 psi OK. NU & press tstd BOPE. Retrieved BP @ 1000'. PU 2-3/8".tbg CO string. Rev out fill from 8563-8590'. LD 2-3/8" tbg. Chgd rams & ts.~d OK. PU DP & landed overshot & rec PBR & Baker Model K tbg anchor. Reran Brown PBR asbly w/new Baker Model K anchor on 5" DP. Stabbed up tbg anchor. Sheared PBR & press tstd to 3000 psi OK. LD 5" DP. Chgd rams to 7" & ran 161 its of 7" 23# S00-95 butt circ string. Landed open ended @ 7164_'. Set 7" Baker BP @ 60'. Chgd rams. Could not retnieve BP, Unlanded 7" & re"~t~ieved BP. Reran Baker Model "C" BP @ 900'. ND BOPs. Chgd 7" pkoff. NU BOPs & tstd pkoff to 5000 psi OK. Chgd rams & retrieved BP. LD 3-1/2" DP & ran new PBR stinger on 4-1/2" 12.75# CS-CB C-75 Hydril l~bg. PU tbg hgr & damaged same while landing. Repaired hgr. Relanded & tstd to 5000 psi OK. Tstd tbg to 2500 OK. Pulled dummy valve & ran 3-1./8" OD dummy gun to 8575'. Set back press valve. ND BOPs. NU & tstd xmas tree to 5000 psi OK. RU riser & lubricator. Tstd smae to 3000 psi. RIH & opened XA sleeve @ 7140' Displ CaCl2 w/diesel down to sleeve. Closed XA sleeve. Displ 7" x 4-1/2" anul ~ 9-5/8" x 7" anul w/Glycol wtr solution. Tstd 4-1/2" tbg to 4000 psi for 1 hr OK. Tstd 9-'5/8" csg to 2000 psi OK. Ran GR/CCL on 20' dummy gun from ?BI) to 2 jts above XA sleeve OK. Wireline PBR 8579'. RU Camco & ran dummy valve. Installed gauges & press up'tbg for long term tst. Released ri~ @ 0600 hrs 11-30-76. l,)iYiSiO!',,l OF OiL ./"~h!D GAB Atl'antic Ric h,f,;,_ :d C~o m pany ..~ Norlh Amer~.,~l Producing Division Norlh A~as~ istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 27'7 5637 November 23, 1976 Mr. Hoyl e Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: _~44-2-11 ~1_4) -'1~'q~7-~(21 - 11 - 11 - 14) I CONFER: -- Dear Sir: Enclosed please fi nd a Sundry Notice outlining our perforating plans for each above-mentioned well. Very trul~ yours, C. R. Knowles .District Drilling Engineer CRK/jw Enclosures Firm 10-403 .REV. 1,.10-73 Subml t "! ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use thls form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-029-202l 0 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. WELLOIL E~ WELLGAS O OTHER Gas Injection 2. NAME OF OPERATOR !8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 360, Anchorage, Alaska 99510 NGI #7 - (11212-11-14) 10. FIELD AND POOL, OR WILDCAT 4. ':LOCATION OF WELL At surface 216'S & 989'E of NW cr Sec 12, TllN, RI4E, UM 13, ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad Check Appropriate Box To Indicate Nature of NotiCe, Re 14. Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 12, TllN, R14E', UN 12. PERMIT NO. 76-38 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Perforate PULL OR ALTER CASING g---J MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT Of: WATER SHUT-OFF ] REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) .... ' .. (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. ·DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of · starting any proposed work. Atlantic Richfield Company proposes to perforate the intervals as follows: 8175' - 8200'; 8221' - 8246'; 8263' - 8290'; 8305' - 8332'; 8346' - 8367'; 8382' - 8417'; 8432' - 8445'; 8466' -8485'; 8500' -8534'; 8553' -8563'. A 5000 psi WP wireline lubricator, tested to working pressure, will be Utilized with all wireline work. All perforations will be made with 3-1/8" JumboJet hollow carrier guns at 2 shots per foot. The downhole safety valve will be installed upon conclusion of perforating. Well Will then be flowed to burn pit for clean Up only. Bottom hole static pressures will be measured with downhole pressure bombs run on wireline. Estimated start date, December 5, 1976. t6. t herebyc~tify th~.the foregoing is true and correct z / / ' :(This s~ace for State offlc~ coNDrr~oNs O~PROVAL, IF ANY: U on ~e Instructions On ~everse Side DATE STATE of ,~ALASKA DEPARllqENT OF NATUI~AL RESOURCES Division of 0il and Gas Conservation TO: ~-- The Well File FROM: Hoyle H. Hamilton Di rector O^TE .' November 10, 1976 SUBJECT: Arco NGI #7 Gas B1 owout June 17, 1976 - Received a C~iil: .from Easy Gilbreth at 7'15 AM, June 17, 1976. He had just been not~fied that a gas blowout had occurred at 1:30 AM in the morning and .was still, in progress on Arco's NGI #7 well. Easy and I had a meeting at Arco's office at lO:O0 AM to be brought up to date on the we l 1. FOllowing the briefing, arrangements.were nmde for me to travel on BP's charter plane to the slope.~. Departed Anchorage at 4:00 PM and arrived at well location at 7:10 PM. I found the condition of the well as follows' 3 joints of 7" tbg. were leaning over in derrick with elevators attached. Bottom of tbg. extended in the BOP stack.. Bag preventor was closed around tbg. and blind rams had been closed. (See Pictures Nos. 1, 2, and 3.) It was generally believed that they were. closed' 6n the fu'il' open '~hOe ~f the 7" tbg. Later this proved incorrect as tbg. was resting on top of closed blind rams. (See Picture No. 6.) Most of the gas was escaping Out the top of the 7" tbg, although ~ small amount was coming out around the bag preventor, The gas rate was estimated at 15-20 million cu. ft./day. An easterly wind of approx.. 20 .knots was blowing gas away from location toward the central compressor plant. All rig power was shut down and also operations at the central compressor plant to prevent ignition. Started preparing a wooden chill box to put around top of BOP stack to help fo~ an ice plug. At 12 noon they had started pumping in water through the kill line at 20 gal/min, rate. Wellhead pressure was ranging from 2200- 2500 psi. Started preparing a new location for a relief well 1600' north of NGI #7. Left location and went to base camp. to phone report. Talked with Easy at 9-50 PM. Upon returning to location, I found that the well had suddenly stopped flowing .at 10:45 PM. Wellhead pressure started building and by 11:29 PM it was 3200 psig. At this time started pumping t0.4 ppg gel mud with some lost circulation material into kill line. Pumped in a total of 30 bbls. at 1 bbl/min, rate. ~une 18,.. 1976 - At 12:35 AM started pumping heavy mud followed by bleeding offWellhead~ Pressure. A 3" flowline was used to bleed off gas. This continued throughout the day. The following is a log of the operation. Pumping Rate Mud Wt. Cum. Mud. Inj. Wellhead pressure Time ~(Bbls./min) (ppg) . :(Bbl:s.,) ~. (psi) ._ .. :. ~ 1.7 13.0 39 2900 12:45 PM 1.6 ll.O - 12.8 48 3240 l:O0 AM 2.0 12.8 95 3275 1:20 AM -2 ltoveai~r 10, 1976 $1~t down pumpt~ e 1:23 N4.. Est. '74 bbls. of 12.8 ppg. mud and 21 bbls. of 11.0 ppg. mud had been lnJectad. Started bleeding off gas e 3:15 AM. Hellhead pressure bled down to 2600 pst by 3':~ AM and Increased -to 2780 psi Just befere ptmptng restored. ~ ~"~i'I~ c~. ~ud. InJ. ~11~e~d pressure Tt~e 12.8 ' . .136 3025 4:10 AM Shut down ~ 4:13 AM ~ Med .~ !:o 2300 pst ~ 4:6~) AM. lqud t~t. Cum. !~Ud. tn;l. gellhead .pressure Ttme 2~ 5:25 12.8 194 - Called Jn report: to Easy e 6:.05 AH. At 3:62 PM had pumped By 12:30 PM had I~ in 375 bbls. of heavy mud. Jn 417 bbls. of mud and kal]head pressure had butlt up to 3000 pst. Standtng shat down from 3:52 PM ~11 5:10 PM, .at whtch ttme wellhead pressure was 25(~ pst. S~ bleedJltg off gas and by 6:40 PM wellhoad pressure was 1000 pst. Called Jn retxa~ to Easy g 7:15 PM. Confirmed bleed!rig off gas and at 10~11 PM'r~ellhead pressure was 150 pst. 19, 197~_- Al~tod bleed~lng gas, pumping tn mud and_shut, ttngtn -'i'da~t~':~ly morning hours, F1o~11ae ftnally froze. At 8.00 AM wellhead pressure ~ 16~ ps1 and they ~ere trytncj to thaw 3" flowllne. Cun~jlattve heavy mud tn~. ec~ ~was 470 bbls. Called tn report to Easy g 8:26 AM. ]~ns~11ed wooden box around top of BOP stack and packed wtth dry 1ce to malntatn ice plug. Thawad out 1flow It_ne and' started-~leedt, ng o.f.~_ga.s. agatn at 4:45 ~. By 7:~,PM wellhead press~-e was 750 ps1. called in report to Lormle Smtth g 8:15 PM, trted calling Easy and he was out. Conttmmd bleedt~ gas at1 ntght using 8/64" - 12/64" choke. It was necessary at tlmes ~ Jn~t methanol taro 11ne between choke and wellhead because It ~ to pl~ wt.th 1ce. ~lune ~, 1976- By 6:46 N~ the wallhead pressure was 50 pst and zero ,~-ressure' at =~-he~e. ca11~ report to Easy e 9:00 AM. A weighted 1t~ was run thrm~h 7" tbg. to the rtg floor wtthout encountering any !ce brt~s to trap pressure. Stnce early morntng well had been dead so It was dec~ to open bag preventor ff:t~,t. Th t? wa.s dOneTl~et 3:00 PM ~ s'~ that, ma pressure had been tr~ below the oag. crew tmmedt- atelv began changtng the 5 1/2" pt'pa rams to b11nd rams, Thts was completed Novembe~ 10, 1976 by 3:30 Pg. Tubing vas cut off Just abeve r4g ~loor' and ~ulled from BOP stack ~ ne~ bli[~l~ rams el.oSCO. ! re~ to base camp and called tn · report to Lonn~e 9 6:.30' PR. Easy ~as out. aune 2'1, .)~- D~ove out In 'm°~ntn9 and spent_ e. houP ~i~TVasSt111 dead vl~h new b11nd rams- ciosed, Inspection o? nag ~uooe ~ that It had des~uctod vhtle t~/lng to clese on 7" tbg. that vas The beg had ~ Only to' dtver~ the math 1flow of gas thw~Jgh the 7N tb9. The plan vas to ~lace bag p~even~ and old b11nd rams. Set up h~&ullc smd~In9 eclullmumt and F~ve F~dy t~r speclal c~ev comlng tn frem Texas. Snub tn tublng and clean out to bottom. Toured new doc~ ar~a before ~etmmlng to base cam~ ~o~ a 1:00 PM departure on ~'s Dt~25 ~et. ~ved'in Anclu~age at 2:30 PM. ~_ ~.,~ !976 -'! talked vith .Glenn. Stmpson and they had replaced_ Olh~dd ]bTt~fi-~W' ~ bottom of st:ac~- Ustng a tost plug the entt~e stack been tes~. ttben the~ ~epi~ the !over set of b11nd rams, the Inspection tndlcated the flcM was ~lng place a~ound back stde and not though rams. The~ couid seca 11~1:1e cutting of the metal to...1halt.cate thts. Installlng snubbtttg equt~t v~htch Includes a set otr ptpe ~ams, b11nd ~oms end a bag p~evento~. · lune._.24,~ ]9~6- ][ tol~ wtth G.lenn Stmpson. An 1ce plug vas .found tn the ir~i~Val-1611'/1870'. ~ ~ ~ken through, plug and ve~e cfrculatlng at 1887' wtth 2 3/8" tubtng contatnl'ng 2 bac~ pressure vatves. Tubtn9 pressure zero, csg. 40 ps1. Had-some good gas klcks while circulating. ~ ~ 1976 - ! taltced ~t~.G1-enn Simpson and ~t~ey .have run 2 3/8" ~1~ ~r ~~ ~ C~t a~ ~ e cleen vtth 11.6 ~. ~ing and. run In drill .pipe and remove-packers at 7200' and 8610' ar~l tes~ 1ine~ shoe and liner 1~ and cement as .needed. ~al - ~im Adalr and one of bis men were called ~n ~ Houston, Texas, ?~y.--..v~ss ~ 'the location Wtce. The ~o'1!o~tng ts a 11st o~ w of the people ! met that were lnvolved tn operatlofls: Bob Htnes A~co, Anchorage Tom iqfebs~ " " Glenn Stmps~ JeF~y S~ut dt " " Hlke He~nner " " Bob t41ckey Sex,on " " 61'I He, er " Les Sellers " Lormy HcOenald " ,Tim Langston " " La~ry 8ell Arco, Dallas Dave Edmlston " " Ha-~vtn Nc .Dante1 Gray 0ti Tool #1 #3 gel1 bl~ng at maxt~ ~ato, condensate plume sbat~. Rtg subs~ructm~, brekm ~statn on ~htte butldlng at left ~as a ~lt of' dteSel f!~k. Gas being bled off through '3" flo~11ne. Pa~t of bag prevento~ ~nno~ after ~eil was ktlled. P~ of lo,mr 7" tbg. ~otnt removed af~ am11 ~as ktlled. Full opening "Texas mule shoe" on bottom tn .foregO. Sho~rs that bltnd rams dt'4 not ¢105e on tl~. Dent tn tbg. approx.. 10' th~0m bottom made by-met~l t~l~ In bag p~evento~.when t t self- dest~a:ted whtle t~ to Close on canted tbg. j, 77. l~lor[n /-~lasKa iJiStrlct Post Offi:c~.~ox 360 Anchora~. ,Alaska 99510 Telephone '907 277 5637 August ll, 1976 Mr. Hoyle Hami 1 ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 RE' DS 3-4 (11-13-10-15) DS 4-10 (33,27-11-15) NGI #7 (Il-12-11-14) Dear Sir' Enclosed are the Well Completion Reports along with the Well History and Directional Survey for the above mentioned wells. Very truly yours,. C. R. Knowles District Drilling Engineer CRK/jr Enclosures |.'ur!Il P - 7 ~" i SUBMIT IN ' ' PWE* STATE OF ALASKA .... ....~1 rLlct io~ls reverse side OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OIL -- 6^S [~ WELl. L--_J WELL DRY Other b. TYPE OF COMPLETION: xv Et.L OVER EN ~ BACK RESVR. Other __ 2. NAME OF OPERATOR Atlantic Richfield Company ~q. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOC^TION Ob' WELL (ReI~ort location clearly and in accordance with any-State requireme, tz)* At surface 216'S & 989'E of NEW cr Sec 12, TI1N, R14E, UM At top prod. interval reported below 270'S & 1034'E cf NW cr Sec 12, TllN, R14E, UM At total depth 272'S & 1044'E of NW cr SeC 12, TllN, R14E, LrbI 5. API NLrM.EKICAL CODE 50-50-029-20210 6. LEASE DESIGNATION A_ND SERIAL NO. M)I, 28302 ?. IF INDIAN, ALLOTTEE OR TRIBE NAIVLE 8. UNIT,FA.RAVi OR LE,kSE NAME Prudhoe Bay 11-12-11-14) 10. FIELD AND POOL, OR WILDCA. T Prudhoe Bay-Sadlerochit 11. SEC.. T., R., M., (BOTTOM HOLE Pool OBJECTIVE) .. Sec 12, TllN, R].4E, UM 12. PERMIT NO. 76-38 5-8-76 7-10-76 7-15-76 18' gr pad, 'RKB ""--~.~_~I.'~TER%'AI.S DRILLED bY r CONLPL';-' '121' ' 18. TOTAL DEPTH, Nil3 & TVD~9.PLUG, B~CK MD & TVD .IF lVEULTIPLE HOW lVI~NY* i'- ' i ! _-korUny TOOLS i CA~l,£ T001 s 8645' & 8644' [ 8590' 8589'' [ single .',. ;: :' :' All none 22. PRODUCING !NT2ERVAL(S), OF THIS COSIPLETION--TOP, BOTTOM, NrAI~IE (MD ~ [~): .... '' ' :/ 23. WAS DIRECTIONAL ~., i ~ ; SURVEY MADE . NONE " ~ YES 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/BHC/GR, CFD/CNL/Caliper, CBL/VDL/CCL 25. CASING RECORD (Report all strings set in well) C~SLNG SIZE 20" 13-3/8" 9-5/8" 26. SIZE 28. PERFORATIONS OP?aN TO PRODUCTION 30. N/A DATE FIRST PI[ODUCTION k-~(~ ~V 2 TcB1NG 21. DISPOSITION lb/ft~thd J"GP,.ADE t DE, P'I~-I SI~,T (1VID)I HOLE SIZE I CEMLNTING RECOI'LD 941/-Vetco / H-40J 80.5"g'el pdd 32"I 240 :,× Arcti~.~r 72/t-Butt I MN-80I 2725' i -J 17-1/2"1 amo0 .q× Pr II cmt 47~t-Butt J MN-801 7735' . J l 750 sx Class C- cmt &i S-951 , ,1 ,~ 2nd stg w/275 sx PF II LINER R.E C O I-LD 2'/. TUBING I TOP (MD) I I5OTTOM "MD} t S'~NCtc'S CE'MEN'T'7446' 8640' 250 raZE DZPqt~ SET ,Y.D, ¢iutcrval. size and number) D ,EA~I'Ii INTERVA_L ¢ N/A PRODUCTION J PI%ODUCTION IV1EIHOD ~Flowii~g, ~.:~-~ HI'L p,;mp/ng--size amd type of pump, NOURS q:mSTmg 'IcnoxE S~ZE JPP. OD'N ~OI~ om--nc~. CA~h'{ G PRESSURE ]CALC~T~ OI~BBL. GA ~-~,ICF. ~s ~8old, u~ed ~or ~uel, vented, etc.) AP,IOUNT PULLED t ACID, Si:©T, F;]ACX GRE, CEd',IEN'T SQUEEZE, ETC. AM.DUNF AND l.£!:qD OF MA'IE?.iAL USED ','. ELI. STATUS ( Producing or nperforated completion iVd/,'I'ER--BBL. I GAS-OIL ILkTIO WA~--BBL. J OIL GR.~VITY-~I (CORa.) 1 JTE~T WITNESSED 32. l. IST OF ATTACHMENTS Drilling History & Directional Su,ru~ey , m I r t s deter ..... d from all a,t rec.rds -- 2;2. I hereby certify thai the fpregoing and attached lnf)rmhti( n is co p ere and corec a ' , , - '~ liable SIGNED TITLE ~ ..... DA'FI'; .... ~ , ,. , *(See [amoctioa~ and Space~ for Additional Doto on Rever~e Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lan:ts and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in clher spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one nterval 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 seperately produce,J, show- ing the adlditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing anct the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). , , 34. S'UMMARY OF FOI~MATION 'rI~s'i~S IN('LUI)IN(; INTERVAL TE~STED. I'lt£SSURE DATA AN~J~ovEIilES OF OIL. GAS. 35. G~GIC ~ARK~ WAT~ AND MUD V~. ', lop Sadleroch~t . 8174' 8173' 3ase Sadl eroch~t 8588' 8587' a ir iii i 36. COHE DATA. Aq'I, ACII BHIEF-D~~ONS O~-' ~ITIIO~OGY; ~HO~TY. FH'A~.~B~ A~g~' ~. A~: D~[TEI) St'rOWS OF OIL. O~. OR WA~I, ATLANTIC RICHFIELD COMPANY NGI #7 (11-12-11-14) API 50-029-20210, ADL 28302, Pe. rmit No. 76-~38 Drillin~ Histcry Spud @ 16~0 hfs 5-8-76. Drld 17-1/2" ho].e to 2740', POH w/multishot. Ran DIL, Sonic/GR and 4 arm caliper. Ra.n 13-3/8" 72# MN-80 Buttress csg w/shoe @ 2725'. Cmtd 13-3/8" csg w/4800 sx PF II cmt. Wa. shed & blew dry 13-3/8" x 20" anul thru 2-3/8" risers. ND Hydril & set slips. Risers would not circulate. Poured two drums of methanol in 20" x 13-3/8~' anul. NU & tst BGP.E. RIH w/12-1/4" BHA, drld FC, cmt, shoe & tstd form to 65 gradient Drld 12-1/4" straight hole to 775G' · · , stuck p~pe and u~.able tc circulate. Worked pipe from 7750' to 7068'. Ran free point indicator, pipe stuck @ 6876' free @ 6829'. Ran back-off shot, left top of fish @ 6821', bit @ 7018'. RIH w/12-1/4" bit & cleaned out to 6821'. RIH w/9-5/8" WP, washed over & rec fish after three tries, cond hole for logs. Ran DIL, BHC/GR, CFD, CNL and Caliper logs. RU & ran 9-5/8" 47# M}:-80 & S-95 Buttress csg w/shoe @ 7735' FC @ 7649' & FOs @ 2491' & 2364' Cmtd , · 9-5/8" csg w/750 sx Class G cmt. Ran RTTS & shifting tool, open & tstd both FOs. Cmtd thru lower FO @ 2491' w/275 sx PF II cmt. Open up. per FO C 2364' & placed 300 bbls Arctic Pack in 9-5/8" x 13-3/8" an~i w/0% wtr @ end of job. Closed & tstd FOs. RIH w/8-1/2" bit, cleaned out tc 7702'. Tst csg @ 3000 psi. Chgd over wtr-base mud to Oil Faze mud. Drld cmt, shoe & 10' new hole to 7760'. Tstd form @ 0.62 gradient. Drld 8-1/2" hole to 8055'° Cut Core #1_8055-8102', rec 36'; Core #2 8102-8161', rec 59'; Core #3 8161-8217', rec 56'; Core #4 8217-8275', rec 57'; Core #5 8275-8289', rec 7'; Core #6 8269-8295', rec 4'. RIH w/8-1/2" bit, cleaned out to 8295'. Cut core #7 8295-8336', rec 28'; Core #8 8336-8395', rec 59'; Core #9 8395-8450', rec 55'; Core #10 8A50-8495', rec 45'; Core #11 8495-8555', rec 6~'; _Core #12 8555-8615~, rec 60'. RIH w/8-1/2" kit, drld to 8645' .\PO}i, ran DIL, FDC/CNL logs. RU & ran 7" 29# Mb~.-80 Buttress ]nr w/shoe @ 8640'. Cmtd 7" lnr w/250 sx Class G cat. RIH ~'/8-1/2" bit to lnr top @ 7446', no cmt RIH w/6" bit, cleaned out to shoe @ 8635' no cmt. Press tst @ 2500 psi., broke down to 650 psi. POH. Ran CBL, VDL, GR/CCL logs. RIH w/6" bit, drld 7" shoe ~ cleaned out to 86z~5'. POH. RIH & set EZ Drill plug @ 8610', press tst & pumped thru retainer OK. Mix cmt & stabbe.d into retainer. Could not squeeze w/4000 psi, rev out. POH. Ran WS¢~ tst w/5950' diesel c~:sh, pkr @ 7394'. Opened tcols w/weak blow, dead balance of 1 hr tst. POH w/60' rise. RU & ran Cyro, CBL/VDL, GR/CCI. logs. ND BOPE, insta]i 7" & 4-1/2" hgr spools, NU & tst BOPE. RIH w/OEDP disp] Oil Faze mud w/diesel. RU & r~.n 3 j ts 7" 23# SO0-95 Bu. ttress csg, well kicked diesel. Closed blind rams. Rgoms held 20 mln them. leaked, closed Hydril on 7". Gas to surf thru 7" in derrick. Contained gas flow thru preventers w/augmer, ted Hydrate plug & LCM pill. Started killing we].l by injecting mud & bleeding off excess press. Pumped mud & bled preg~s to zero, opened up spherical & removed 7" tbg. Chgd out top rams to new blinds & secured Well. Chgd spherical preventer & tstd operationally. Repaired & tstd BOPE. Installed & tstd stubbing unit. Snubbed. in the b. ole while circulating out gas to 8597'. Pulled to 7098', circ 11.9 mud in & 11.6 out. Checked well for flow, OK.! RD snubbing urit, removed BOPE & replaced preventers. NU & tstd BOPE. RIH w/overshot & pulled PBR & tail pipe left in the hole before the well kick. RIH w/6" bit to 8600', circ & press tst. Set 7" RTTS @ 7900' & press lnr to 3000 psi OK. Press tst 9-5/8" csg, found leaking pk-off. Set BP & chgd out 9-5/8" pk-off. Ran 6" bit & drld junk 8603-8610', drld EZ Drill & cleaned out to 8645'TD. Ran EZ Drill retainer & set @ 8550'._~Sq_u_gezed ~2D_O..~sx~-~.~Clas~ G cmt. Ran 6- bit & drld hard cmt from 8443-8550'v~-.~-~'csg to 3000 psi OK. Drld ~-~~'~'~'~*'~'~'~"~-~'0'~'¥,'~'std csg w/3000 psi OK. RIH w/DST tool, set pkr@ 7396'. Open tool w/weak ~.low, then dead for balance of 3 hr tst. POH w/DST tools. Ran 6" bit & csg scraper to 8600'. RU & ran CBL/VDL/CCL logs. Ran & set EZ Drill BP @ 8590'. Chgd over wtr base mud to ]0.9 ppg CaC12 wtr. Spotted 40 bbl of 11.2 ppg Oil Faze mud in 7" lnr. RIH w/PER & Baker SAB pku, set @ 7240', top of PBR @ 7203', & shear sub @ 7386'. RU & run 7" tbg circ string w/shoe @ 7143'. RU & run 4-1/2" tbg, stab into PBR @ 7203', lam. ded tbg, Camco ball valve @ 3995', XA sliding sleeve @ 7149'. ND BOPE, NU & tst xmas tree. Pulled dummy valve @ 3995', open sliding sleeve, displ CaC12 wtr w/diesel. Closed & tstd sliding sleeYe. Run 3-1/8" x 20' dummy gun & CCL. Ran dummy ball valve @ 3995', press tst 4-1/2" tbg & amul, OK. Released rig @ 0400 hfs 7-15-76. Eastman Whipstock A PETROLANE ~PANY REPORT of SUB-SURFACE D IREC TI ONA L SURVEY Atlantic Rich£ield COMPANY N. C. ~.' #7 'WELL NAME Pr-~lhoe LOCATI ON JOB NUMBER A676 GO1 35 TYPE OF SURVEY Gyroscopic DATE SURVEY BY Jay Martin OFFICE Alaska ..................................................... 'ALL~'L"CAL~COL'AT I-ON~-",:'PERFORMED By .... I B- M"-'EL~ECTRO..N_I.~_C..O. MPg.?ER TRUE DOG LEG .0 0 0 ,0,00 47,00 S2~ ............. 200 0 15 199.99 '-~'52""'~9' S45.00E 703,48 N 3'00- 0 lO --299,99--252-*'99 ..... Sl'~'*'OOE- "70~,~6 'N 718.29 718,09 71'7,70 717,36 "---~+'0'0 0--3'0~'3-9'9,99 '3'5'2-~-99 $5'21-0'0W----?02,64 N 1~9.31 W-- 7"i-'8'~-3"3--'N--fi--'59 ~50-W--0,-3-'30 716_,_8._7_ 5'00--'0-45 ~99.99 -7452%99 .... $88,00W ....... 702"e-27--N .... 150-','32-W .... 718,,:'18 ..... N-1'2 .......... ~--55 -W '-0-,250 716.65 600' O'~O~':599-,-98--55Ze-98--'SSS"-OOW--701-'-93~N ..... :'I51-,-'3'~-W ....... 71"8" -06-'N-12'T,"rO .... :-Z-W~ o.zso 716"- '7- 800 ....0 .... 0'~79'9'"98~75'2:e98 ........ S~9eOOW ........... 7'0i%'~'8 .... N ............. i5%,91 W 7%7,7~ N 12 l~ lO W 0,170 716,10 o;b'"8 o 0.~10 o-,-~-3o-- 0,180 0-,7 50 0.500 l%-O-O--O-~-O--1-5'9979-5--1-55'2-.'95--N79-;O'OE--TO'5~-O'E~ ' N-- ---'1700 0 30 1699.9~ · 18'00 0-"-~5 ---I900--O--55----1-8'99-.-93--r85'2-e-93--S3'7-.-O'OE--7'O-3-'-4-6--N i~'6-,-55 W 2000--0--1'0--i999'.'92 1-952'-92 $89-."0-0E--70-5. OZ+ N 145;72-W --2100--0 15-2"099-,792--2052-,-92--N3~'e'OOW--~'O3-'"30'N 1~5--"57-.W - 220'O--O---O---21-9-9-,-9'2--'2152,92--N3'3-~'OO'W-----T63-,-48-'N 1-~5-,-6-9 W-- ...... 2300 ...... 0 -0--2299,92- 225'2-~92-N3'3','OOW 70-3-,'48-N ....... 145-,-69 W .... 2400-'--0-I0 2399,-92--2352-"92 N39-' 00~ ?03-, 60-'N ........ 1'z+5" 78 W 1~9.~2 w 7-2 0-~'712-- N- i i~7-]-5-7-W o.il~ ., -- 0,284 0.250 0.180 0,760 0.080 0,250 0.000 '718,55"'N'"-11 ..../~2 2I'W ..... 0.170 715.96 '716e46 --7':fY,51- 7'- 56 7. _ . 719.28 _ - . 719.07 718.4~ 71 716.74 716.:98 717.18 717:_18 R'ECORD-OF-'"$URVEY AL]L~CA-COJtJAT'Z"ONs"-P"ERFO~ED-B¥--t ....... B-M-~'[,-E~YR~N ! C COMPUTER-- TRUE- ................................................................................................................... '--H ~ A S-e-'DR' I FT--V E'R'¥ Z'CAL' ........... SUB ............... D R-'Z FT ....... ¥ OTA C-CO0 R D X'NA-T-E 5 ~.E~_TH_~ NG.L E ......... DEPTH .................. SEA ............ D J REC D .... M ...................................................... DEG., DOG. kEG C b 0 $ U R E $ SEVERITY DI ST-ANC. E- ........ ANGL, E .... DEG/-10OFT . D.ISTANC-E .... 0"~ 0-55 2699'91--2652,91 512,00E 702 2 N 144,76 W 717,09 N 11 38 48 W .... 2'8'0'0--0' 55 2'79'9-,'90--'2752.90----$"l-6"e"o'o~ir77'O0.'75 ..... N ............. !.4.../4,_..,..3_7__W ___.7~,.5. e/+7__rN_.], l__38__29__W., 0.'.065_ --29'00'~---1 ...... 5~2899,'88 ............ 2852,88 ...... -~23,0.0E 699.09 N__143.78 W__ 7!3_.7.2_N_.1.!_37 19 W ---3UO:'O--~--'5 '29-99,'86 ....... 29'5'2~:8'6-: ........ ~2"3";0'~E 69'~Z'"34. N 14.3,0/+ W 71-1-,86 N 13. 35.. 3_.Q_W_ .~ 0_.._0_00 ......... 3,~0'0 .... 0-30 .......... ~299.8~ ..... ~2!~2'.'83 ......... $1i"00E ........... ~9~.~?'-N ........ -:'3~4~."82-'W-? .... '7707"7~-N .... ~i-'3~ ~4 W 0~_2~0 3'50'0 -0 .... 0 ..... 3499~'~ ....... 3452'e~ ....... SI'I,O'OE": ...... ~~i-N - ........... 0,4.68 ....... 3',899',82 .... 3852,82 ....... $85--,OOE ........ 689,82 .... N ..... i4-i-',-6:5' W ?'0/4..2]. ..... N'-'1-1----36 1,6 W 4'0'0'0--0--25--3999-J81-"'395'2%'8i~-S8'3', OOE- - -6'89 ,'74--N--I-h'O~-9'O'W "' "/03-,-98-N-i"i--3-Z--4-6-W 0,015 0,430 0,000 2 W O.OOO ........... 7.12,55.,, __7.1.0-..7.1_ 709,08 707*70_ 706.61.. 705,80 705,43 705_,_lO_ 703.58 703,07 "' Y6'2'. 8'8- 702.79- 702.79 0,000 70 r,~ 77-9-' 0-*-0 O0 702,79 o.ooo u. 4-"/0'0 0 0 ~-699'81---'4652-'-81-- .... $8'3100-E'- ..... 689,69--N .......i-40-;53 W 703'86 ...... N---i~-'-3'i -'2'-'W---0'*-000 ....... 77702.79 ~8'00---0 -0 4.-799.81 .... 4752"81 ......$83-,'OOE -'689,69-N .......... I4.0','53-W--: ..... 703.86 N 11- 31 ....... 2'W .............. Oe'O00 ........... 702.79' /4,'9'00 0-"~".1"~--4-~'0'9-'-8"1.,' 4,8'52r''"8'1-' ,S'3'F~'OOW--~- 6.89-.'30--N--3:~'O'e-3'~' W--TO-3-.-z+-5-N 1.1 30 33 W 0.590 '¥0-2"-3~- 50'0'0~0--3-0~-999";'81~4.-952'"81--$3:6-*-0'0E:'- '688.39'-N ....... 3:/+-0-'e-50 W "702.58 N -- 5-1--0'0---0-30 50-9g'-80 -50'52-.80 ..... $47-,"0'0-E ...... 687',66-N~- 'I-~'C~-~)-5-W 702-*-77 N-'il--30 4.2 W 0,2-6-'/ 700,77'0' 5200~0--3'0 5'~,'9'9'l-8'~5'l'52'e-80---SS'6-~-O-O'E~687.1i--N- - -1-3'9.37 W 701,].1 N 11- 27 57 W 0.078 700"06- 5-30'0~0--/+-0~5299-J779 5252'.-7-9--'-556'~'0'0-E- .... 686.54.-N .... 1--3'8-.52 W 70'0-','38 N 1,.1, 24, 26 W OTi-~70- 699,38 _ _ -- · TRUE DOG LEG -~ E'A*$-~-- D R-]~* 'I~*T-9-~*R*'T ~'CAL SUB '-D EPTH-A*N GL-E---DE PTH' -- $ E A ....... D D .... M .................................................................... DE'G YO'¥A~'--c~OORD-i*NAYE'$' - c L 0 S U R E $--sEVER*iTY--$ECTX*ON- D-~-$~A-N'C'E A~N'~'U E DE6-£i-O 0 F T D'I 5-6'0'0 ....... ~'-'2'0 --5599,7'4' '5552*~---S6'0-~00E ..... 683e-22*-N' --1'3' 4-[2 6 W--696'*'29 N I'1 7 3 '~ 5800 1 30 ..... 5'799'* 68 -5752'~-~---S3"Y~bOE .... 679 ~'82 ...... N ..... -i'~-"6T~*'~-~ e'92%"2~--'N--i0--~-2--~e ~ 59'00 i--2'5 ..... 5899-.65 ....... 5852'65 .......S35-~0'o-E ......... 677'75'--N ---~'29'"'-%-?--~ 689'e95--N-~-0-~'? 25 ~-- 0-.-2'~o' 696.'9-~'- 0.090 6c~ o-.-0-? o 691.59 0,0'70 -- 689 0.180 687.2]. 6100 1 20 6099.60 ...... 6'052"60 ........ $2'5';-~0E .....67'3'82 N ..... ~'2'00 1'-15 .... -6199"57 ..... 6'~"52',"57 ....... $20'*"O'OE ......... 6'7~73-N ...... 1'2"5-~"9~ W-- 6'4-0'0'~i--- 5---6'399 ','5 2 .......... 63'5-2-~"52 ..... S2"3','00E ..... 667'. 6"~-N 683-e'44'-N-%0-37 7 0.090 W--OeO-90 W 0.180 -W 0.340 W 0.090 685.09 682"9O' 680,65 678,55 676,78- 0,090 0,019 · ... 0,038 0.019 O',-o-s-o 0.080 0,250 --66o. ~ o--N-t o--~-2'-~'9W . ~ . 673631 671.53 669.72 6676-89 665.95 663,84 6~ ~.e-~- 648',-62--N--1 ~ 6 · 36--~- 6-58"e- 97-N--l'O._ l 0..._.1. 4 _.. ~ ......... 0,!60 .............. 658.64 0 50 7599.31 ..... 7552~3'i ..... N78'~OOE .... 648.13-N ...... 1~5'"'06--W ............ 658.26 N 10 4. 0 W 0-.903 657,97 ~/00 0 50 '/699.30---7652.30 "N?,/;OOE ......... 648.45'"N ~),.-3-e-63-W~-658.33"'N--9--56--2].'-W -'"-7'8'O:O--O--5'O~?99-,-2-9---TY52.29--'NT-6-eOOE . -648,'79 N 112,20 W--658.42 N--9 48 43 W ' 790-0---i----0' "/899,28 '7852.28 .... N?O'e-OOE 6~9.26-N .... ii0-'-67 W 6-58662 N' 9--~0--2-4 W-- 8000----1 "5 ?999-;26--?952-~'26--~-NS~-.-OOE ........ 649.._67-~N~----%O~B-~8'__9~W '--65-8"-73 N--9 )0 55 W-- --8'200 I-3~--8-1~-9j-2i--~-I5'2-'21 'Ne'2'~-OoE~-650~95 N Z0~.42 W 659,28 N--9--6 48 W~ 0 _,_0_1_5 658,07_ '0,0'15 658~20 0,160 658,4.5 ..... 0_~_0_9_0 658* 59_ 0,250 658.86 . - 0.250 - AL~.L"iC~LCUEA'T-~~-R-PO'R'MED' BY I B M ELECTRONIC COMPIJTER ..... ... -"D'E PT~-~AN-" G~E~-E-P' ?-1~ s*EA D'I R E C DOG_~.EG .......... D..~_S_T_.A.N~_E_ ............... A.NGL E ........... DE.G/_], OOFT D~_5.TAN.C.E D M S ~' 147 i47. lO0 0 0 - r2~1'--7 247. 200--0 0 347 347.--300 0 O. 70o 8'00 J--900--O '~['0'4 7 11/+7 ............................ 1'1~,:7" .......... 1100 703,33 N 1/+9,2.0_W 702 · 18 ~ ,3,.,, 7.0_1_,!~_N ..... ;t, 5 7 o.L,..5_O_,.H 7..o_.!..,_zt..5._N..,.. 70 !._,2.6_N ......... .],. 52...,.. 0:,5. W 0 0 0 "0 0 0 0 0 204,-7 2247 , 2'~4-? 2/+/+'t 2597 0 0 18 4 ?%£8'o'o--o 3,9'~"t,-],"9o'o .............. o 2'0-~'?,2 o o o ............ ,'o 2 2247. 2200 0 z~-?. ,230o ....o 2547e 2500 0 ?9.Z_,_..Z...5_N. _!..5_.1...,..9..8._.W ?03.,_5 6 N 1 ? 0.~_5_. 1__.~. ....... !5 o_~_ ? o~.', '8 o N 15 O..,._5.~_w ? O~..?.97_N ...... !_~_9..,._8..8. _W '/05_,_08_N. _ _~.49_.,.0.._~W 7 0.~_.,._7_e N 0 703.5_~_N .1_~ 5.,._7.1_ W __o __ 70.3..,7..:3_.N ........ 1_45.,_8_! .... W 0 703e83 N )./+5.,49_W 26/+7 27~,-7 2-8/+ 7 3'0-~-?' 3'1'-~-7 _ - -- 3247 3347 .... 3/+47 35~+-7 2647. 2600 '0 fT~,~', fT'O-O o 284.7. 2800 0 29-4?-, .... 2-9-00 --o 3-0-4-'t' · 3 0'00 0 31~+7. 3100 0 3-~, 3 2 00--0 3.3%~-, '3-3-00 0 3~-7-, -34'0-0--0 35/+7, 3500 0 0 701,59 N 1/+4.59 0 700.00 N 144,13 0 698.27 N 1/+3,~3 0 696,56 N 0 69561/+ N 0 693,89--N ...... 1'~1.92 0 692699 N ' 0 692.32 N ~1.61 0 692.13 N · "'"TRUE -' MEASURE[:) - 'VERTICAL SUB MD-TVD VERTICAL DEP TH DEP T H ,sEA-'-6-~ F FER-ENC-E ¢oRRE"C-'t; ! ON TOT A L COORDINATES 3647 36~+7. 3600 0 ~ 79_7 3 ? ~+ 7,__~ 790 ........ o, 384? 38&7, 3800 0 3967 -39'~'?"';. 3900'-"' ........... 0 ~2~ 42~7, ~200 0 ~'3~-7' ~3~7,--~300 0 ~547 4547, 4500 ........... 0 0 0 0 0 0 0 '0 0 .0 0 · 0 0 0 0 0 0 0 69.1..,.~7__N ............. l~l,9~.W _6.gQ,.69,N 1.~2.,.2.8_W. 689.98 N 1~2.02 W 689.78 N 1~1.31 W 689.71 N 1~0.65 W 689.69 N 1~0e~3 W ....... 689.69 N 1~0,53 W ...................... 689.69 N 689.69 N 1~0e53 W 689.69 N 1~0e53 W 689e69 N 140.53 W 689.69 N 1~0,53 W 689.63 N 1~0.~ W 688'.'88 N 140,53 W 688,02 N 1~0,3~ 6-8'~;'39 N 1 686.19 N 138.0~ W 57~7 6'047 6~-7 6~4~ 6~ 6~46 -- -- 66~8 6848 69~ 5-5-~-?-, -55oo ........... o 5-647. 5'600' ' 0 57'~-7-*.~'57 O0 .......... 0 .5-8-~+-7-'~5'8 O0 0 ' 5-9-~+~'F----5-900 0 6-OZ+'? · 6'000 0 6-1-~-"/, 6-100 0 ~-2-4~. 6 2'o-0~o 63Z+7, 6300 0 .64-4-7, 6400--0 65%-7 ,, 65-0'o 1 66A7-' 6600 6-?'ZFT;" 6'~00 1 68~?. 6800. ,3. 69-4'7% ' 6900 1.' ,t 0 683.86 N 135.27 W 0 682.61 N 133.33 o 6 e'0';-8 ~--N .... i3 i-'" 5 4--w 0 67'Ke--e 5-N .... --1~'9-,'9 o 6?'~i/z N --12'8~-53 w 0 672.8~ N 126.36 0 670.75 N 125.54 W 0 668.62 N 12~,z~9 W 0 666.81 N 123.70 W 1 665.17 N 122.97 W '0 663,56 N 122,01 W 0 661,92 N__12!._:_O.~_W 0 660.23 N ' 120,17 W o 6 58_.5i_N _ __ i !?-..36 w 0 656,73 N 118,63 W ............. I~ E'~SUR-ED ................ V E-~h" :rCA~'-S~b.~ T VD ~ DEP TH .... DE'PT]~- '~'$E'A--~-IF F E R EN C E 7':!.-4-~ ' 7-i-~-7,'~ 72'~-8" 72'4;T'w-' 7200~ 76-~-8 ................ ? 748 77'~-7-;~7700 7848-- 7'8-4:7. 7800~ 8048 8047, BO00 8-1~8 8-i-h-7', 8100 -82~-8 8-2'~?;' ...... 82'00 VERT I CAI, .CORRECTION TOTA~ COORDINATES 0 '"1" ! O. 1 0 1 0 1 .0 1 0 0 0 0" 83/+8 ................................. 8'3'~7. ......... -8~00 ............... 8 448 '8'~,'~7'. .... 8h:O0 ......... 854,8 8547. 850b 0 0 0 0 1 · :!. 0 0 654,73 N 118,23' W 6.5.2,_6.8 N__ 11 650,92 N 117.33 W 649,30 'N 116,79 W ................... 6_4.8_,.2p 648,28 N 114,~8 W e_fig,'4~ N 98.37 W ! NTERPOLATED VA~E._~ FOR _E_.V__E_N__~.O.,.Q_O_..FEET """ ........ 'TRUE M E A S U R E O V E !~ fl-~-A L DEPTH DEPTH SEA TOTAL COORDXNATES 1000 999. 952. '/01.31 NI 152.1~ W 2 000 3_000 2999~..~95 2. 6000 3999, 3952, 689.74 N 5000. /+9'99, · Z+952, 688,~+0 N --6000 59 9-9-' 5*952" 675.81 N 7'-000 6999. 6952. 65"f,-60 N 8000 7999. 79.52-, 6/+9.67' N .......... ) ........ : ............ ~. .~· 5 :::::::::::::::::::::::: ':::: ::: :'-:! .......................... ~_ ...... : -_~ .-.--_-y.-:-:- :- -: -_- ...................................................... '0 ..... ' ............ / ....... ~ .... ; ...... ALL DEPTHS ,SHOWN r~ ...... ARE 'TVD. ~. _~- .... ~ ..... ..__2 ..... L_:': :_i_'_ __' ~:'--:-l-_' _ :-_ ........... .... ........ : .................. i .................... ~ ............... : ...... .... V-"-[- -'t ...... -';-., ffL'[-~-Y ~oot ~' ~"i ;_._i ................................ ~ ..... ~AT, LANTiC RICHFIELD -COMR ...... ~-] ......... WELL NO. NGt. T[ ....... -:-~- .......... :'-~ -I' ........ i ............. : ......... _ . i' -- RADIUS-OF CURVATURE ......... ;;_.I~L._~ ......................... I ........ GYROSCOPIC SURVEY 5600- LOCATED IN THE APPEN.DIX [~ WFL [~ IPR LOG ~ CALIPER SURVEY UI VOLAN CURVE DATA ~ STRATIGRAPHIC HIGH RESOLUTION DIPMETER '-[~ OTHER: ~' North Alaska District Engineer~'v k..UI~IFlU[I'~,,/~I~ T'R A N S M I T T A L DISTBIBUTED TO: STA%E OF ALAS~ DIVISION OF OIL ~ G~ From: J.A. Rochon/W. Toliver Date: August 4, 1976 Well Name: NGI #7 (1'2-11-14) Transmitted herewith are the following for the subject well' Run No. . Scale Xerox Sepia BL Line BHC sonic/Caliper Log . BHC Sonic/Caliper - Gamma Ray Log .... 1 ;2-' BHC Sonic/Gamma Ray Log Caliper/CCL / Cement Bond Log/VDL 1,2 Compensated Fomation Density Log I Compensated Neutron-Fomation Density ..... Compensated Neutron Log Core Analysis - Interval Core No. , ....... Core Description ($VC) -"In{erval Core DesCription (Cony.) - Core No. Directional Survey - Gyro A676 G015S. Single Shot Multishot Drill Stem Test - Test No. "i ~ 2- Dual Induction Laterolog Formation Density Log Fomation Density Log/Gamma Ray Ganma Ray/CCL Laterolog Location Plat Microlaterolog Microlog Mudlog - Interval 2740 to TD Sample Log (A.R.Co.)-Interval) Synergetic Log TYD-DIL TVD-PorOsity Log ' · o 2"&5" Receipt Acknowledged For' Please return receipt, to' At ic Richfield Company North Alaska Engineering Manager . P. O. Box 360 Anchorage,'Alaska 99510 Atlanti~RichfieldCompany North Ameri/q.a~ Producing Division North Aiask strict Post Office BOx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 28, 1976 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- NGI #7 (11-12-11-14) Permit No. 76-38 Dear Mr. Hamilton' Enclosed is a revised Sundry Notice outlining in more detail our plans for the above mentioned well, as requested by Mr. John Miller on July 27, 1976. Very truly yours, C. R. Knowles District Drilling Engineer /JWS/jr Encl os ure REV~ 1-10-73 ~%~subsequent Reports" in Duplicate STATE O, LASKA OIL AND GAS CONSEF~VATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. ·WELL1 lOlL N WELLGAS O OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. O. Box 360, Anchorage ,.. Al aska 99510 4. LOCATION OF WELL At surface 216'S & 989'E. of NW cr Sec 12, TllN, R14E, UM · 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad 14. Check Appropriate Box To Indicate Nature of Notice, Re : '1 NUMERICAL CODE 50-029-2021 f) 6. LEASE DESIGNATION AND ,SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL I~10. NGI #7 (11-12-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 12, TllN, R14E, UM 12. PERMIT NO. 76-38 3ort, or Other Data .. NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other)' PULLOR ALTERCASING ~ MULTIPLECOMPLETE ABANDON* CHANGEPLANS SUBSEQUENT REPORT OFt WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT , ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) . , (NOTE: Report ~'esults of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly st'ate all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work, Atlantic Richfield Company proposed replacing the 9-5/8" x 13-3/8" wellhead pack0ff in NGI N0. 7 in August, 1976. A rig utilizing a 13-5/8" 5000 psi BOP stack with annular preventer, pipe and blind rams will .be used. A plug will be set in the tail pipe below the permanent packer Weighted CaC1 water will be circulated before the 4½" CS-CB Hydril 'tubing a~d 7" circulatin2g string are pulled for access to the wellhead packoff. A 9-5/8" retrievable bridge plug wi,ll be set at 100'+ while replacing the packoff. The same tubing strings will be used to recomplete the wel 1. ,, I hereby certify that the foregoing Is true and correCt for State offlc .,)'~: CONDITIONS OF {~PROVAL,'IF ANYt See Instructions On Reverse Side ' 7/28/76 . OATE "//'z.~!/74. Reh~rned Division of 0tl and Gas 3001 Porcuptn~ Drive, Anchorage, Alaska 99501 July 22, 1976 Ri chard Kno. wl es. Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. Knowles: Now that the problem with,~~ has been corrected, I would like to be brought up to date on tbt~w~)~i. Some of the questions that still' remain unanswered in my mind are: · 2 3. 4. ~,lhere did the gas entry take place? How was the point 'of gas entry determined? What caused the blind rams to fail? What was done to shut off the gas entry? Any other relevant information that you might have, besides what I am asking for, would be appreciated. Sincerely, Hoyle H. Hamilton Acting Director t(HH:bJm · Atlanlic~Ric hfieldCompany NortP Ameri~ t-~roducing Divisiol~ North Aias~'~,,~ .;trict Post Offic~ ,~x 360 AnchorageS.' Alask,~ 995'10 Telephone 907 277 5637 JulY 12, 1976 'Mr. 0.' K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 RE.: DS 3-4 (11-13-10-15), Permit No. 76-51 D~33-27-11-15), Permit No. 76-42 ~'- GI~l-12-11-14), Permit No. 76-38 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above mentioned wells. · S i ncerel y, C. R. Knowles District Drilling Engineer CRK/BDR/jr Enclosures JUL 1 4. 1,976 OlVISlON 0t~ 011. AND GAS ~ Z,,To. P~ STATE OF 'ALASKA ~'~. ~- 1-70 SUBMIT 11~ DUPLICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WOR'KOVER OPERATIONS o,L []] o,, []] at.,, Gas Injection WKLL 2. NAME OF OPE~:tATOR Atlantic Richfield Company P.O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL 216'S & 989'E of NW cr Sec 12, TllN~R14E, UM $, AP1 NUiVIEHICAL CODE ;50-029-20210 6 LEASE DESIGNATION AXD SEHIAL NO. ~DL 28302 IF INDIA]~, ALOTYEE O~ TRIBE NAME 8. L,~IT FAIIJVI OR LEASE NAME . Prudhoe Bay g WELL NO ~,Go I, ~7 (11-12-11-14) " ' A-ND POOL, OR WILDCAT ~rudhoo 8a¥ - Sad]erochit Pool 1l SEC., T., R., ~i.. (BO~I'OM HOLE Sec 12~ TllN-RI4E 12. P~:~MIT1~0 , 7§-38 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE. CASING AHD CEMENTING JOBS INCLUDING DEPTH SET A1N-D VOLUIVIES USED, PEI~FOHATIONS, TESTS A_IN-D I~ESULTS FISHING JOB~ JITATK IN HOLE AND SIDE-TItACKED HOLE AND A2qY OT/KER SIGNIFICAI~TT ~GES IN HOLE COiN-DITIONS. Report on operations for the month of June. Cut Core #1 8055'-8102', rec 36'; Core #2 8102'-8161', rec 59'; Core #3 8161 '-8217', rec 56'; Core #4 8217'-8275', rec 57'; Core #5 8275'-8289', rec 7'; Core #6 8269'-8295', rec 4'. RIH w/8½" bit, cleaned out to 8295' Cut core ~7 8295'-8336', rec 28'; Core ~8 8336'-8395', rec 59'; Core ~9~8395-8450', rec 55;; Core ~10 8450-8495', rec 45'; Core ~11 8495'-8555', rec 60'; Core ~12 8555'-8615', rec 60'. RIH w/8%" bit, drilled to 8645'. POH, ran DIL, FDC/CNL logs. RU and ran 7" 29~ MN-80 Buttress liner w/shoe ~ 8640'. Cemented 7" liner w/250 sx Class G cmt. RIH w/8~" bit to liner top ~ 7446',,no ~emen~ RIH w/6" bit, cleaned out to shoe ~ 8635', no Cement. Pressure test ~ ~0 psi, ~ ~ POH. Ran CBL' VD[, GR~CL]~s. RIH w/6" bit, drilled 7" shoe and cleaned out to 8645'. POH. RIH and set E-Z drill plug ~ 8610', pressure test and pumped .through retainer OK. Mix cement & stabbed into retainer. Could not squeeze with 4000 psi, reversed out. POH. · Ran WSO test w/5950' diesel cushion, packer ~ 7394'. Opened tools w/weak blow, dead balance of 1 hr test. POH w/60' rise. RU and ran Gyro, CBL/VDL, GR/CCL logs. ND BOPE, install 7" & 4~" hanger spools, NU and test BOPE. RIH w/OEDP,.displac~ all.Faze mud w/diesel. RU and ran 3 jts 7" 23~ S00-95 Buttress csg, well kicked diesel. Closed blind rams. R~s held 20 mtn then leaked, closed Hydril on 7"~~ thru 7" in derrick. Contained gas flow thru preventers w/augmented Hydrate plug and LCM pill. Started killing well by injeCting mud and bleeding off excess pressure. Pumped mud and bleed pressure to zero, opened up spherical and removed 7" tbg. Changed out top rams to new blinds and secured well. Changed spherical preventer and tested operationally. Repaired and tested BOPE. Installed and tested snubbing unit. SnubSed in the hole while circulating out gas to 8597' Pulled to 7098', circ 11.9 mud in and 11.6 out. Checked well for flow - OK. RD snubbing unit, removed BOPE and replaced. preventers, NU and tested BOPE. RIH w/overshot and pulled PBR and tai]pip~~ ]~f~~ ~ in the hole before the well kick. Running in the hole w/6" bit on 7-2j~ JUL 1 1976 ~ ~r'-,: ~NI~ION O~ ~ ANO OAS NOTE--Report this form il required for ,~ch calender jib% regardless of [~l status of ope~tions, end must ~ flied in dupll~te wit~ the oil and gas conservation eommi~ee bythe 15~ of the suee~ing ~n~, ~le~ otherwise directed. CATEG 0 RY POLLkFT I ON At around OllO local time on l? June 1976, gas injection well No. 7 at an Atlantic Richfield Co. (ARCO) facility on Prudhoe Bay, EVENT DATE )7 JUNE 1976 Alaska, blew out, releasing.17~OQ to 230,000 cubic meters of i §as per'day for apProxinmteli~-t~T~irteen day} until the flow wa~ ~~-~ pparently, a faul-ty seal in the well casi.ng .r~sult¥.d in the LOCATION ~ As soon as the drilling crew observed the leakage, they lulled the casing up as far as possible and closed the blowout pre- Prudhoe Bay, Alaska, USA venter; however, the crew could not tightly seal the blowout prevent- er, and gas continued to leak through a .045-centimeter-wide crack. The flow was primarily methane gas with some light hydrocarbon conden- SOURCE sate. Mike Welsh, Public Affairs Office The pressure of the escaping gas forced approximately 50,000 Atlantic Richfield Company I liters of arctic pack, an oil-based, heavy lubricant used to prevent P.O. Box 360 the pernmfrost around the casing from freezing, out of the well. Most Anchorage, Alaska 99510, USA of the pack spilled either onto the drilling pad or into a waste pit. Officials estimated that less than ten percent of the pack reached the Lonnie Smith surrounding marshy tundra, contaminating approximately 20 square ~laska Division of Oil and Gas 300l Porcupine Drive meters. Due to the danger of an explosion, ARCO cordoned off the area. Anchorage, Alaska 99501, USA _ To plug the leak, ARCO cleanup personnel injected water into the gas stream. The natural cooling effect of the escaping gases froze the water, creating ~_q ice plug that shut off the flow within ~noroximat. e- fOX* 1¥tw~q~;y-on~ho~, enpacked the hole with mud. ARCO enw- ~onmental exposestimated that 29,000 liters of the condensate es- caped from the well, coating grasses in the area with an oily sheen. ShoJ~J~-Li~r(~ No other environmental damage .... eported. e ,lq. iA i: ";I I iq/r, J ?.1,',q EVENT NOIIFICATION REPORF __ Al -,r-und Olio h,cal ti.~t on 17 J,me ]976..ia,, in ecttrn wel CAIEGONY Pqllt;tIq'i ., ::'~': ........ '.[~,..,,.,. ". r., ;',,. .... ~, ....... ... ,: ' EVENT DATE ~ ~q,p.,,o~t /. ~ %ulty Seal ~ th( ~II co~in~ ro~u*i~d i. th~'. LOCATION b],~l~. As Soon as the drillinq crow observed.the lJakaqe, they pulled the casinq up as far as possible and ch)sod the blowout p~e- Prudh~e Bay, Alaska. USA vente,-; however, the crew could not tightly seal the blowout P,'event- er, and ~as continued to )oak through a .045-centimeter-wide crack. Fhe flow was primarily ~thane gas with so~ )iqht hydrflcarb~n conden- sate. - SOURCE J lbo pretqu,~ of the-escaping gas forced appro~)m,)tely 50.00~ r.h~e ~'o)..l~. :',JbJlc AffaiFt Office ~tOr5 of orct~(: PaCk. an 0il-based. hed'.'y lubricant mJ%Eyd [o prevent f'lla'~tir P'{qflmld Comp,ny ' P.O. li(,~ th- permafrost arr, u,:d the cdsinq from freezing, ouL of the well. l&)~t~Anrh(,"ar]~. Alaska ~9~)0. USA of the pack sl)il)ed either onto the drilllnq pad or into a waste pit. Off~cia)~ estiaated that. less than ten percent of the pack reached the Lem~ surr()undi, ng marshy tundra, contal:dnating approximately 20 square Alaska DIVI¢ lop fit C) l) and Gas ~ters. t~OI r',rCup~*~ Due [o the dancer of an explosion. A~CO crrdonpd off the at'ed.. &nCh,qr.l.l~. ,5' 1,l,1 ')qqOJ. Tn plug the l~a;, A~FO'cJp,inup Per~orme) in.iected w. to- iat( thy No uther environmt,.tal damdge w,~s repoTte~J. · ,,.,,, ,,d :) ~ '., o£StP 197, for ~e!esse IMMP. DIATELY ATLANTIC RICHFIELD ENCOUNTERS EARLY FLOW OF GAS AT PRUDHOE GAS INJECTION ~ELL Anchorage, AK, June 17-- A gas injection well being drilled at Prudhoe Bay encountered an early flow of gas at 1:10 a.m. this morning a spokesman for Atlantic Richfield said. "There is no fire and no injuries," Howard A. Slack, vice president and manager for the Alaska Region, said. The well is partially shut off at the surface with an estimated flow of six to eight million cubic feet per day of natural gas and 180 barrels of condensate. Operations are under way to pump drilling mud into the well to shut off the flow. "Ail of the necessary means to shut off the flow are at hand and we expect the operations under way will be successful," Slack said. The incident occurred at well number seven on the gas injection pad as seven inch tubing was being set in the gas zone of the producing formation. These wells are being drilled for the purpose of injecting gas back into the formation when production begins in 1977. A-35-76 Telephone conversation between Hr. Kno~les, Arco and O. K. ~ilbreth. 06-17-76. Knowles: I tell you, Imm hanging on by my toenails. Gilbreth: I see. Knowles: ~/e got ah - took a kick last night in NGI 7 during our completion pro- cedure and we don~t know if it came in through the shoe or on liner lap but we tested both of them going both ways as per our usual procedure and we were running 7~ tubing which in this well was going to be a circulating string and we had three joints in when the well kicked. And it un]oaded diesel. The crews were unable to stab that safety valve so I threw it down and started pulling tubing to get it up where I could close the rams on it. They pulled it, and of course, they had three joints in there and thats range 3 pipe so they got it up as far as they could to the blocks and close the blinds on it and we have a leak through the blinds that, we are estimating, is about 6 to 8 million a day. Gi lbreth: I see, what is the situation through the 7~17 Is it coming through it? Knowles: Yes, that is a blessing in disguise as we had that full stand to 7~ because now that means the gas is leaving location - the bulk of it is right underneath the crown. Gilbreth: I see. Knowles: ~/e have a lot of condensate and distillate in the cellar. ~/e~ve got 2750 showing on OUr tubing head gauges. ~/e do have hydrates forming which are good and as we get this ah - we're snubbing down that stand of the 7" so that we can go ahead and depend on ~t not to go out of those rams. As soon as we get snubbed down we are going ahead and inject water to form an ice plug in our preventers because the temperature above those blind rams which are leaking ought to be down around zero. Gilbreth: I see. Knowles: ---the expansion so we ~re going to form a big ice plug and we~ve got ah, BP~s mixing mud - all of them, Briggs are mixing mud. t4e are moving in several thousand barrels of storage. ~/e've got Halliburton and Dowe]l well lined up and they're tied in. Gilbreth: ! see. Knowles: As soon as we can get ready, we're going to pump into her with Il lb mud. Gi]breth: Okay, what is your best guess now when you will start in good? Know]es: Looks long about lunch time if everything keeps running right. Gilbreth: I see. Okay. Knowles: Its ah, the flow is constant and that - since we only have 2750 lbs surface pressure that means - that tells me we're flowing through the equivalent of a downhole choke, t4e have either a small channel broke down in the liner lap or we've got a small channel broke down coming back through the plug - we had a broken shoe. Gilbreth: ~/hat~s your situation down the hole in the liner. Know]es: Okay, we have the liner - the well is full of diesel. ~/e had pressure tested it. t4e had run a water shut off test above the liner lap. They both look good. We have a - we had a funny looking cement job is where our problem comes f rom. (~ilbreth: I see. Knowles: They had no cement on top of the liner when we went in to drill out and we went down and we didn't bump the plug so we went down. t4e drilled the plug and it was three feet about the catcher stop so it was almost where it was supposed to be. We had no apparent cement between there and the shoe so we drilled out the shoe and tested it and all this was with mud in the hole. And of course we were able to pump into it but we broke it down - we did not circulate back. C;i]breth: I see. -2- Knowles: Of course we did this with a bradenhead so we don~t know. Then we went ahead and set an easy drill retainer 30~ above the shoe and stabbed into it and~id have injection without communication back around the liner. We had run:.a bond log and we do have some bonding up about /~0~ up from the shoe. Gilbreth: How much overlap do you have between the --- Knowles: 300 feet. Gilbreth: 300, okay. Knowles: And we went to stab into the easy drill and mixed 200 sacks of cement to squeeze the shoe and we stabbed back into the easy drill and went to /~000 PSI immediately without taking any cement so we're burst out of cement and came up and pressure tested again to 3000 and everything held and we ran a water shut off test which we use the worst case calculation of bringing gas to the top of the liner with a full column of diesel on the inside and we test to that plus a 500 lb safety factor. And we test that for an hour and it held. There was no rise, no bull and it held so we came out of the hole, picked up our 9 5/8 packer, its tail pipe in the PBR on drill pipe, ran back in there and set the packer, picked up and sheared stinger out of the PBR above the packer, and came out of the hole end d(~n drill pipe. The next thing we had to do was run this 7" circulating string and then weJre going to run /~ 1/2 tubing through it, and stab back into the packer. ~/e have three joints of that 7" - weighs 29 lbs, on a range 3 casing is what it is, 23 lbs. ~/e had three joints of that in there when the well kicked. Gilbreth: I see. Know]es: ~/e couldn't stab the valve and then we started pulling up but it was blowing the tubing faster than we were shucking the block. Gi]breth: The rams that you have in now, are they for the 7"? Knowles: ~/e got a set of blinds and we got a set of pipe rams. -3- Gi 1 breth: Knowl es: Gi lbreth: Know 1 es: G i 1 breth: Know 1 es: Gi lbreth: Knowl es: Gi lbreth: Know1 es: Wel 1, are the pipe rams --- They are for 5/8" drill pipe. They are, - okay. So you probably got some leakage there then, haven't you? Yeah. ~ Okay and didn't you say that ah -- We have measured and our measurements tell us~,'that we have about 1.9 of a foot of that 7" below the top of the gates in the blind rams so the blind rams by our measurements are closed on that 7". I see. The blind rams? The blind rams are closed on that 7". I see. There's where our leak is. Gilbreath: Okay. Knowles: Gi lbreth: Know 1 es: Gi lbreth: Knowl es: Gi lbreth: Know 1 es: Gi lbreth: Know l es: Gilbreth: But it did hold pressure for 20 minutes. I see. For 20 minutes it held. And then broke through -- And then broke loose and we closed the hydril on it and its all gone up the 7", the majority of it. Okay. Well, would you keep me advised then, Dick, on what your progress is. Okay, we've got with the State and Federal Environmental people as soon as we were able to get in touch with them here this morning. A11 right. We've got Red Adair coming in his Lear Jet. We've got Larry Bell and another one of the guys off the Dallas Petroleum staff coming on the DeHavel in. Okay. Well, I'll probably get a man up there just to stand arourid and -4- watch you. Knowles: Okay. If you'd like to come over for a briefing we'll pass it all on to you. I know its always hard to get it over the telephone. Gilbreath: Yeah, well I might do that --- Knowles: Why don't you do that -- if you feel like - you know, just run on over and we'll let you have everything that we~ve got. Okay, well - mighty fine then and I know you got your hands full there so I'll let you go for right now. All right, thank you. Okay, thank you then, Dick. Bye now. G i I b reth: Know 1 es: Gl l breth: -5- State of Alaska Division of Oil & Gas Attn: Mr. J. Levorsen 3001 Porcupine Drive To: Anchorage: AK Atlantic Richfield Company North Alaska District TRANSMITTAL From: R.A. McIntosh - North Geological Date: June 17~ 1976 Well Name: North Gas Injection ~7 Transmitted herewith are the following for the subject well: Run No. Scale Xerox Sepia Bi Line X BHC Sonic/Caliper Log BHC Sonic/Caliper-Gamma Ray Log BHC Sonic-Gamma Ray Neutron Cement Bond Log Continuous Dipmeter (HPD) Continuous Dipmeter Polliwog Plot Continuous. Dipmeter Printout Core Analysis Interval Core No. Core Description (SWC) InterVal Core Description (Conv)Core No. Directional Log Drill Stem Test - Test No.. Dual Induction Laterolog Compensated Formation Density Compensated Neutron Formation Density Gamma Ray-Neutron Microlog Mudlog Interval Proximity-Microlog/Caliper Log "Sample Log (ARCO) Interval Sidewall Neutron Porosity Samples (SWC) Interval No. Boxes Samples (Conv) Core No. No. Boxes Samples (Dry) Interval No. Boxes 1 box Samples (Wet) Interval No'. Boxes Synergetic Log . 7750' - 8635'TD ~]~~i~tra~~n°wl~~ged~la~nt ic~~R~= h?~'~ e ipt : ' 'c ield Company North Alaska District 'Attn: District Geologist P.O. Box 360 Anchorage, AlaSka· 99510 Processed by: ~~~7-~ State of~ Alaska Division 'of Oil & Gas Attn: Mr. J. Levorsen 3001 Porcupine Drive To: Anchorage., AK Atlantic Ric f Id Company ~' North Alaska District TRANSMITTAL . · Fro, m:. '. R.. A...McInt.osh -_ North Geolo_~ical Date: June 14~ 1976 Well Name: North Gas Injection #7 Transmitted herewith are the following for the subject well: Run No. Scale Xerox Sepia B1 Line BHC SOnic/Caliper Log BHC Sonic/Caliper-Gamma RaY Log BHC Sonic-Gamma Ray Neutron Cement Bond Log ContinuOus Dipmeter (HPD) Continuous Dipmeter Polliwog Plot Continuous Dipmet.er Printout Core Analysis Interval Core No. Core Description (SWC) Interval . Core Description (Cony) Core No.- Directional Log Drill Stem Test 'Test-No. Dual Induction Laterolog Compensated Formation Density Compensated Neutron Formation Density Gamma Ray-Neutron Microlog Mudlog Interval Proximity-Microlog/Caliper Log Sample Log (ARCO) Interval Sidewall Neutron Porosity Samples (SWC) Interval No. Boxes Samples (Conv) Core No. No. Boxes Samples (Dry) Interval No. Boxes Samples (Wet) Interval No. Boxes Synergetic Log . 2730' - 7750'. 4 boxes Receipt acknowledged: ..... · Date: ~/ ~-'~ / Return receip~ to: A~antic Richfield Company _ North Alaska District Attn: District Geologist Processed by: P.O. Box 360 Anchorage, Alaska 99510 Atlant~,RichfieldCompany North Ame~,n Producing Division '~' North Alasl ,iistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 3, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 RE: NGI #7 (11-12-11-14) Permit No. 76-38 Dear Sir: Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Sincerely, C. R. Knowles District Drilling Engineer CRK/j r Enclosure Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER Gas InjectioR 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. BoX 360: Anchorage_. _~ 99510 4. LOCATION OF WELL 216'S & 989'E of NW er Sec 12, TllN-R14E, UM 5. APl NUMERICAL CODE 50-029-20210 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhom Bay 9. WELL NO. Nc.~ #7 (ll-l 2-1 ~ -l~) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadleroch±t Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 12, TllN-R14E, UM 12. PERMIT NO. 76-38 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report on operations for the month of May. Spud @ 1600 hrs 5-8-76. Drilled 17-1/2" hole to 2740', POH w/multi-shot. Ran DIL, Sonic/GR and 4 arm caliper. Ran 13-3/8" 72# MN-80 Buttress csg w/shoe @ 2725'. Cemented 13-3/8" csg w/4800 sx PF II cmt. Washed and blew dry 13-3/6" x 20" annulus thru 2-3/8" risers. ND Hydril and set slips. Risers would not circulate. Poured two drums of methanol in 20" x 13-3/8" annulus. NU and test BOPE. RIH w/12-1/4" BHA, drilled FC, cmt, shoe and tested formation,.to .65 gradient. Drilled 12-1/4" straight hole to 7750', stuck pipe and unable to circulate. Worked pipe from 7750' to 7068'. Ran free point indicator, pipe stuck @ 6876', free @ 6829'. Ran back-off shot, left top of fish @ 6821', bit @ 7018'. RIH w/12-1/4" bit and cleaned out to 6821'. RIH w/9-5/8" WP, Washed over and recovered fish after three tries, conditioned hole for logs. Ran DIL, BHC/GR, CFD, CNL and Caliper logs. RU and ran 9-5/8" 47# MN-80 and S-95 Buttress csg w/shoe @ 7735', FC @ 7649' and FO's @ 2491' and 2364'. Cemented 9-5.8" csg w/750 sx Class G cmt. Ran RTTS and shifting tool, open and tested both FO's. Cemented thru lower FO @ 2491' w/275 sx PF II cmt. Open ~pper FO @ 2364' and placed 300 bbls Arctic Pack in 9-5/8" x 13-3/8" annulus w/0% water @ end of job. Closed and tested FO's. RIH w/8-1/2" bit, cleaned out to 7702'. Test csg @ 3000 psi. Changed over water-base mud to OilFaze mud. Drilled cement, shoe and 10' new hole to 7760'. Tested formation @ 0.62 gradient. Drilled 8-1/2" hole yo 8055'. GIH w/first core barrel on June 1. 14. , hereby certify th~.~th~~rreet SIGNED TITLE ~l DATE MOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the l~th of the succeeding month,unless otherwise directed. 024)01 B STATE .,of ALASKA DEPART~,ENT OF NATURAL RESOURCES Division of Oil and Gas TO.. [--0. K. Gilbreth, Jr. V// Director Thru: Hoyle H. Hamil ton Chief Petroleum Engineer FRO~: Ben ~LeNo~an Petroleum Inspector D^TE :May 17, 1976 SUBJECT: B.O.P Tests, Ar~,!GI-7 ~i) Arco DS 3-3 ?,aY 12, 1976 - Departed my home at 8:30 AM for 9:00 AM showup and lO:O0 AM departure via Wien flight //23 for Deadhorse. Arrived Deadhorse at 12:40 PM via Fairbanks. Harold HaWkins and I caught the Arco bus to NGI-7 via Arco base arriving there at 2:00 PM Drilling foreman for Arco was Donny Fields and toolpusher for Challenger Rig #51 was Jim Gaffney. Nippling up was still in progress. Temperature was +]5*F,.. light snow, light wind. We called Buck Rice, drilling foreman for Arco DS 3-3, who advised they had just set slips on their 13 3/8", would cement and nipple up and probably not be ready to test until the afternoon of May 13th. We then toured the location which was well organized, reserve pit well built, rig in good repair, steel welded fuel tanks not bermed and well sign not yet re- ceived from Anchorage. Pressuring would be by two stage Koomey pump with diesel. ~hile on the floor, we noted both dart and ball-type floor valves in evidence. Tests began at 7:15 PM with eighteen Halliburton Lo-Turc plug valves and sixty- six flanges testing to 5000 PSIG. One plug valve would not test and repairs were initiated. Both manual adjustab~ chokes were free moving. However, the Swaco superchoke would not actuate and a repairman was called. While hooking up to test the stack we found the accm~ulator pressure to be 3000 PSIG. N2 backup bottles tested to 1600, 1750, 1850, 1800 and 1850 PSIG. After repairing a flange leak, ,both wing valves and HCR valve on the choke line, both wing valves on the kill line and upper and lower pipe rams tested to 5000 PSIGo By t0:45 PM the Swaco choke had been repaired and successfully actuated. However, the Halliburton plug valve in the choke manifold would not test aoain and repairs began again. The check valve on the kill line would not test and since there were no spare parts or spare valve, we agreed to let them install a gate valve in its place. We requested the check valve be repaired or replaced within five days and we would be called for verification. This is so noted on the field inspection report. The hydril was then tested to 3000 PSIG. An attempt to pick the kelly up found it frozen in the rathole. May 13, 1976 - Thm~ing of the kelly continued until 3'15 AM when tests resumed. ~wefkell,y valve and kelly cock tested to 5000 PSIG. However, the Halliburton plug valve refused to test again. Donnie Fields decided to redesign that half of the manifold eliminating this valve and three others. ~,~le concurred with this idea as it would not affect the manifold. Tests were concluded at 4:~0 Field Trip Report -2- May 17, 1976 Ben LeNorman A field inspectio~ repert~as Prepared with the original going to Oonny Fields. A copy was mailed to B~ Hines and a copy is attached to this report. Departed gas injection pad at 1:30 PM arriving at drill site #3 at 2:00 PM. Drilling foreman was Buck Rice and toolpusher for Rowan Rig #35 was O. C. Murphy. Nippltng up was still in progress. Temperature was +26e F, blowing snow. We checked-with Joe Mann on progress at DS .#4 and he advised Rowan Rig #26 skidded Monday and would probably spud Thursday. B.O.P test should be made the middle of next week on OS 4-10. Tests began at 4:50 PM, but the hydrtl would not test. It was decided to close the t~ pipe rams and test them, the outside valve on the choke and the check valve on the kill line. Two attempts to do thls resulted in a leaking flange an the check valve a~ a bad grease fttttng on a Halliburton plug valve. While repairs were being made,-we toured the 1ocatian which was well organized, reserve pit well built, rig in good repair, steel welded fuel tanks not bermed, and the well sign not yet received from Anchorage. Both dart and ball type floor valves were found on the floor. At 6:40 PM the top pipe rams, outside wing valve on the choke line and check valve on the kill line were successfully test~d to 5000 PSIG. At 9:15 PM the lower pipe rams were tested to 5000 PSIG. An attempt to pressure the hydril with the mud pump failed at this point and it was decided to change the packing element i.n the hydrtl. May t4,_ )_97~6- Thirteen valves and thirty-six flanges in the choke manifold were ~e~d to 5000 PSIG by 12:30 AM. The Swaco superchoke was actuated successfully but the manual adjustable choke was not free moving and had to be repaired. While the hydril packing element was being replaced, we checked the accumulator pressure which was 29E~ PStG. N2 backup bottles tested 1450, 2150, 2100, 2150, 2100, and 2150 PSIG. Tests res~ at 4:30 AM with the hydrtl testing to 3000 PSIG. At 6:00 AM the kelly c~k tested to 5000 PSIG. ~ manual adjustable choke was repaired and operated freety. ~r keilY vaive tested to 5000 PSIS concluding the tests at 6:30 AM. A field inspection report es prepared with the original going to Buck Rice, a copy ailed to Bob Hines and a copy attached to this report. Departed Oeadhorse at 1::25 PM via Wten flight #24 and-arrived in Anchorage via F atr~anks at 4:00 PM and at my home at 4:30 PM. In s=~ we wttness~ BOPE ~sts on Arco's NGI-7 and DS 3-3. Attachment . .,....~....: ~ ..- .~_. ~- ..., (~. ( ) 2.'_Genemal'-Housekeeping~ ('~ ( ) ' -3.; "Reserve'Pit,(. -)open( )filled (~.(' '" (~ ( ) -4:".'Rig"~','' .'"'.' ;'1; :1 - ' ' (;~"(' ' ;: -- (-.)';;'.safety.' val ve Tests ( ) ( )-. 5. Sur.face,No. Well'~m .... (') (). 6. SUbsurface-No. Wells. ( ) ( ) 8. Hrs.',obser ,.. ,__ () (,.) . -9. BS&W , ;~ ,__ ( ) ( ) 10'. Gr; .Bbls. (.) Final Ab~ndon~'ent '-- ( ) ( ) 11. P&A Marker ( ) ( ) 12..Water well;-( )capped( )plugged (~'_() 29. Kelly & Kelly-cock~~psig ( ) '(') -13. Clean-up (~ (~) - 30. Lower Kelly valv~o~.psig --'( ) ( ) 14. Pad'level.ed (.~ (:) 31'. Safety Floor valves-(~V (~a~t Total in~ection observation time-~hrs/d~ Total number leaks and/or equip, failures Remarks ~~~ i/~~_ '/~. ~'~ _~'~,.-~ (1,~-. (. .':.20.. Drilling--Spool- ~ "oUtlet.s"' ':,iii'-.-' - '. (-:~]);(.". ~]:' 22'~', Choke .Fl:-owl ,i he (~HCR~,.~V:, ~v'i'].. ("~"~(]-: ~::-' 23:~",ChO'ke 'Ma'~'ifold No. val'~'~flg~~'- , -(~'~'( ) 24.. Chokes-(:~emote( )'~os~.(~dJ'.. (.~'.'(.') - 25.-Test Plug-(~lellhd.(: )Csg(":)-non~.~ ,:' (~ ( ) 26, Annular Preventer~~sig '"' (~ ( ) 27. Blind Rams~psig (~ ( ) 28. Pipe Rams~sig cc ~.L~ ~/-/f--~Al~Notify in ~ days-~ when-ready Inspected by · ~. te ~-- -:,:' ..~?'..:..:~: '. '~.~ ,~ :~.-.~. '.~...:~. ::~:;.:~.:.~-.:-~u .::.:-~.;-~ '..':/:C'-~? L,.--. ~ "' ' ;~'':''~:' ':;'''~ : ..... ].. ::-..:.:'..,.~' . ........... .. , ~,1~.~..-.:,: .'~.~- ~i,-,.' ........ ' ,......, ,~'.~ ~ .. ',':.-.:'~,- Ap~tl 9, 1976 Atlantlc Richfield S~te Permit [;. ii..-~owles 01strtct Ortlltng £nglneer P. 0.8ox360 Anchorage, Alaska 99510 Dear $t r.: £nclosed Is t~ approved application for pemtt to dr111 the above referenced well at a location In Section 12, To~-~shtp ]ltt, Range. 14E, U. Ft. t4eli samples, core chips and a mud log are required. A directional survey is not required. l~any ri~ in Alaska and their dratnage systems have been classified as !mpor~nt for t.he spawning or migration of anadremous fish. Operations in these areas are subject to AS 16.50~870 and the regulations promulgated thereunder (Tttle 5, Alaska Admtnts~t!ve Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Depart- merit of Fish and G~. Po11_utton of a,y waters, of the State ts prohibited by AS 46, Chapter 03, Article 7 and the regulations pro]mulgated thereunder (Tttle 18, Alaska Admlntstrattve Code, Chapter 70) and by the Federal .~lator Pollution Control Act, as ame~. Pti.or to commencing operations, you may be contacted by a representative of the Department of Environmental Con.servatton. Pursuant to AS ~.40, Local Hire L~der State Leases, the Alaska Department of Labor t-s betng notlfted of-the issuance of this permtt to dr111. To aid us in scheduling field work, we would appreciate your nottCying thts -office within 48 hours after the well ts spudded, l~e would also ttke to be nottfled so that a ~entattve of the 01vtston may be present to wttness testtng of blowout preventer equlpment before surface casing shoe ts dr411ed. .. Apr~l 9, 1976 Purs~mnt, to the request ¢on~ined tn the 'lette~ accompanying the applica- tion., Ne ~), ~tYe the requlr~nnent for ~ flo~ dtverter system tn ~ccord~nce ~ Conservation .~ 'Ho. 137, Rule 2. Please nottfy th~s Division befere Jnst~111ng the dmmtmle safety shut-tn valve so t~t 8rt~~en~ can be made t~ witness the operation. Zn the event 01r s~ton or ,.~ndonment please gtve thts offtce adequate advance nottt~catton so-that Ne my have & ffltneSs present. CC: Department, of Fts~ a~d ~me, Habitat Sectton ~/o eric1. Depart of Env~~.ta.1 Con~tten ~/o eric1, Dep~~t of. L~, Supervisor,. Labor L~ Comp11.~nce ~'vtsten ~/ encl. AtlanticRLchfieldCompany North Ameri~'~ Producing Division North Alask~ .strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 22, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 RE: North Gas Injection Well No. 7 (11-12-11-14) Sec 12,TllN, R14E, UM Dear Sir' Enclosed is our Application for Permit to Drill the above- mentioned well, together with the $100 application fee; and required survey plat. Since this is the seventh well drilled from this drill site,''~ we request the waiver of the double diverter line requirement of CO 137, Rule 4. This vertical well will be cored through the Sadlerochit with an oil based mud. The surface and bottomhole locations are located on lease 28302, having an effective date of October 1, 1975 and a termination date of March 27, 1984. The information in the above paragraph will be helpful to the State Department of Labor. Very truly yogrs, C. R. I~owles District Drilling Engineer ca /Jws/j 1 Enclosures D.IVIStON OF OIL A?4D ©,\3 ANCHO~AC¥: SUBMIT IN TRIPtF..,:FE (Olher instructions on r~ve~e Form 10~401 REV. 1-1-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL oR DEEPEN la. TYPE OF WORK DRILL [~ b. TYPE OF WELL OIL F~ GAS [~ WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR DEEPEN r'~ SINGLE MULTIPLE I'--I ZONE L_! P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 216'S & 989'E of NW cr Sec 12, TllN, R14E, UM- At.pr£p~o~d. pr...od~ zone.... -u3.uo'~, zlo'S fi 989~E of NC/ cr Sec 12, TllN, R14E, llq APl 50-029-20210 5. 6. LEASE DESIGNATION ~%ND SERIAL NO. ADL 28302 7. IF INDIAN, ALLO'Iq'EE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI #7 (11-12-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit il. sec., T., R., M., ~on'oM ltOLE OBJECtiVE) Sec 12, TllN, R14E, DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. Approx. 8 miles northwest of Deadhorse 14. BOND INFORMATION: r~EStatewide s.rety.nd/o~No. Federal Insurance Co. #80113840 ~mount $100~000. 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE. FT. (Also to nearest drig, unit. if any) 4290' 18. DISTANCE FROM PROPOSED LOCATION 2560' 21. ELEVATIONS (Show whether DF, RT, eR, etc.) 18 ' Gravel Pad 16. No. OF ACRES IN LEASE 2S60 19. PROPOSED DEPTH " 8750' PROPOSED CASING AND CEMENTING PROGRAM 17.NO.ACRES ASSIGNED TO THIS WELL 320 20. ROTARY OR CABLE TOOLS 'Rotary 22. APPROX. DATE WORK WILL START April 30, 1976 SIZE OF HQLE SIZE OF C~SING ~IG~ PER FOOT [ GRADE SE~ING DEPTH Quantity of cement 32" 20" 94# H-40 100'. Circ to surf.-±500 sx PF 17-1/2" 13-3/8" 72# 5~-80 2700' Circ to surf. ±4000 sx PF 12-1/4" 9 5/8" 47# MN-80 7750' elS00' c~t column 1st st~ ±750 -- ~ $OO-95 ±300' cmt col~m~ 2nd ~t:g 8-1/2", 7" !hr 29#' MN-80 TI),, ±1200' cmt column ±300 sx See Attached Program - IN ABOV'E SPACE DI~SCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone new productive zone. If p.opo~ is to aau or aeem. ~ectio,~Uy, give m. inent dam o. s-b~face locations verfic~fl depths. Give blowout preventer program. SIGNED. (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED ] MUD LOG [] YES [] NO ] ~] YES [] NO DIRF. CnONAL SURVEY REOUIRE~ [] ws [] ~o OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 50=029-20210 PERMIT NO. 79;- ':tR ,.~ APPROVAL DATE 0q-09-76 ' ' ' ~ Chairman, 0il & Gas Conservation Instruction On Reverse Side NGI No. 7 (11-12-11-14) Drilling and Completion Program The Atlantic Richfield Company proposes drilling this vertical well to 8750' TD for use as an interim gas supply well from the Sadlerochit gas cap, Ultimately, this well will be recompleted for use as a gas injection well. The Sadlerochit interval will be cored with an oil based mud. Logs willbe run over selected iJtervals. A 13-5/8" 5000 psi ~Pstack with Hydril, pipe and blind rams will be used on the 13-3/8" casing. This equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli in the permafrost interval. A Baker "SAB" packer will be set above the liner top. A 7" circulating string will be hung above the packer. 4-1/2" production tubing with a 4-1/2" safety valve will land in the packer. The well will be tested by producing selected perforated intervals. After testing, the 4-1/2" tubing will be filled with diesel. Ail valves and safety equipment will be shut in pending connection of the well to the field fuel gas system. DIVISION OF O~L A.~,rD GAS 3/22/76 ,JWS NGI No. ? (11-12-11-14) Drillin§ and Completion Program The Atlantic Richfield Company proposes drilling this vertical well to 8750' TD for use as an interim gas supply well from the Sadlerochit gas cap. Ultimately, this well will be recomple~ed for use as a gas injection well. The Sadlerochit interval will be cored with an oil based mud. Logs will be run over selected intervals. A 13-5/8" S000 psi BOP stack with Hydril, pipe and blind rams will be used on the 13-3/8" casing. This equipment will be pressure tested weekly and operationally tested each 'trip. A non-freezing fluid will be left in all uncemented annuli in the permafrost interval. A Baker "SAB" packer will be set above the liner top. A 7" circulating string will be hung above the packer. 4-1/2" production tubing with a 4-1/2" safety valve will land in the packer. The well will be tested by producing selected perforated intervals. After testing, the 4-1/2" tubing will be filled with diesel. All valves and safety equipment will be shut in pending connection of the well to the field fuel gas system. 3/22/76 JWS DtVIS!Oiq Of: ©2 A~';_'~ C. A3 I section ...... j line 965' ' ~89' 1014' i059" 915' !064' I089' 1114' il39' ,,~.¢ OF,q ~-~ "- .'~ ~ SECTION CERTIFICATE OF .SURVEYOR I HEREBY CERTIFY ~HAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT B[FRESEN/S A LOCATION SURVEY MADE .~Y ME OR UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OIHER DETAILS ARE CORREC]% 12 A6 -BUILT WELL NO. I LAT. 70°19'56.129'' LONG. 148°28'50.016" WELL NO. 2 · , /.AT. 70° 19'37.284:: LONG. i 4 8° 28'50.762 WELL NO. 3 LAT. 70° LONG. 148° 28151.493" WELL NO. 4 . LAT. 70° 19'59.596" LONG~ 1480 28'52.223" · WELL' NO. 5 LAT. 70° 19' 40.749" LONG. 148°28'52.947" WELL NO. '6 LAT. 70° 19' 41. 908'; LONG. 148° 28'53.68~" WELL'I{IO. 7 LAT. ' 70° 19',43.052" LONG. 148°28 54.412" WgLL NO. e LAT. 70° 19'44. Z10" LONG· 148°28'55.126'' ., · WELL NO. 9 LAT. 70° 19' 45.$70" LONG. 148° 28'55.850" WELL NO. I0 LAT. 70° 19'46.519" LONG. 148°28'56.589'' Y 5 971 400.07 X 687 350.54 Y 5 971 516.90 'X 687 522.06 .Y 5 97I 633.76 X 687 294.09 Y 5 971 750.52 X 687 266. i8 Y 5 971 867.11 , X 687 258.47 f Y 5 ~JTi 984.28 X 687' 210.34 Y 5 972 099.94: X 687 lSZ~7 ~ Y 5 9?2 ~I7.07 X 687 155.05 · 'Y 5 972 534.31 X 687 Y 5 97'2 450.53 X 687' 099.14 CONDUCTOR PiPE DIVISION OF 0~[' A ..a ).., ~., WELL NO. I TOP PAD ELEV, : 18.4 FT, MLLW · cc w ,~.. ._i___ ARCO~ AFE 29Z£65 HVL ~ .... ATLANTIC RICHFIELD' CO. : . ' . , _., - _ _ :.~ _: .,~ , , ,, , ~J AS -BUILT 'WELL I THUR !0 NORTH INJECTION SITE LOCATED I!'~ PROTRACTED : SECTIONS, I ~IZ,,THN~Ri4E U.M. ._ . ,.. .. : PREPARED BY HEWITT V. LOU. NSBURY · 72~ W. 6TI-t. AV~., ANCHORAGE, ALASKA ,,~ ± ,~ ...... DATE O__C_T._~_9..~_L9 ?_5· SCA'I.E,, CHECK LIST FOR NEW WELL PERMITS Company Yes No Remarks 1.Is the permit fee attached ..................... Lease'& Well No. ~/~_~_Z" '~~ 2. is well to be located in a defined pool .............. /{~( 3. Is a registered survey plat attached ................. .~.~A' 4. Is well located proper distance from pr~pperty line ......... /~4aq' 5. Is well located proper distance from other wells .......... /~al< 6. Is sufficient undedicated acreage available in this pool ...... ~.):~ 7. Is well to be deviated ....................... 8. Is operator the only affected party ................ ~ 9. Can permit be approved before ten-day wait ............. .~a~ 10. Does operator have a bond in force .................. ~ ll. Is a conservation order needed ................... 12. Is administrative approval, needed ................. 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 19. Does BOPE have sufficient pressure rating ............. F~J,, di tional Requi r, ementsl: } Approval Recommended' Geology Engi neeri TRM ~, HWK ~/~j~<. OKG ~. ~HH ~ ,~. - JAL Les j'--.~ dCM Revised 1/15/75 Well History File APPENDIX 'Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX: No Special'effort has been made to chronologically organize this category of information, LIBRARY TAPE CURVE SPECIFICATIONS Company Atlantic Well NGI 7 Richfield Field Prudhoe Bay County,State North Slope, Alaska Date 9-29-80 Curve Name (Abbreviated) Standard curve Name Logs Used Scale "' 100-100 TC1 Total Counts (Pass 1) SP 0-100 K1 Potassium SP 0- 10 , , , ] U1 Uranium SP -12.5-+3?. TH1 Thorium SP -.50-+50 ..... oo- oo TC2 Total Counts (Pass 2) SP " 0-100 K2 Potassium SP 0- 10 U2 Uranium SP -12.5-+37. . TH2 Thorium SP - 50-+50 -. · · Basic Information Tape The Basic Information Tape (BLT) is a binary, partially multiplexed tape containing up to 20 data curves. The data samples are represented as IBM, 32-bit floating point numbers. The tape consists of a 276 byte heading record followed by a series of data records whose length is defined in the heading record. The last data record is followed by two end-of-files. The tapes are 9 track, 800 bits per inch. Heading Record The heading record contains the information necessary to recoVer the curve data from the data records and some identification information. · 1. The Epilog Computation Center (gCC) number is a unique number assigned at one of the Dresser Computer Centers. Any questions regarding the data should, if possible, include this number. 2. Company name - Well name. These are free format fields used to identify the well. 3. The number of curves (N) is designated as a 16 bit binary integer number. This number must be less than or equal to 20. It gives the number of curves of data that will be in the data records. 4. Curve names. Each curve is designated by a 4 character name. A list of Dresser Atlas standard names is given in the appendix. These names appear in the order in which the data~ appears in the data record. 5. The starting and ending depth gives the first depth for which there is data on the tape and the last depth respect- ivelY, l~en the starting depth is smaller than the ending depth the data is recorded downward. With field data, the ending depth may be smaller since the data is recorded from the bottom of the well upward. The ending depth may be given as 0 or 99999 when it is not known during record- ing; this occurs on BlT tapes recorded in the field. 6. Level Spacing (L). This field designates the depth increment between the data samples. The data samples are taken at regularly spaced depth, increments. 7. Number of samples (F). This field gives the number of samples of each.curve recorded in each data record. This number will be less than or equal to ~25. DATA RECORDS The samples in the data records are recorded as floating point members (IBM standard). This consists of a sign bit, 7 bit exponent and a 24 bit mantissa normalized to the nearest 4 bits. exp '1 sign bit. mantissa The exponent is biased by 40~6. Thus, 41100000~6 represents the number 1.0. The data record consists of N . F . 4 bytes of data where N is the number of curves and F is the number of samples of each Curve. The first F samples in the record will be of curve 1, the next F samples will be of curve 2, etc. Each record will contain data for F . L feet of data, where L is the level spacing. The current standard usage at Dresser data center is Level spacing = L = .5 feet Samples per record = F = 125 Thus each record represents 62.5 feet of data. These numbers are given as an example only, however, since L and F may vary from tape to tape, and will certainly be different for BIT tapes recorded in the field. DRESSER COMPUTER SERVICES DIVISION FILE DATA SPECIFICATIONS (Continued) DATE 10- 6- 77 EXHI BIT I Page 71 of APPLI CATION FI LE NAME I FILE FILE NAME 2 NUMBER I DEHT! FI C/,TION POSITION CHAR- NO. NO. - FI ELD DESCRIPTION - ACTER- OF OF FI ELD SUB FI ELD START STOP ISTICS DECIMALS BYTES 1 Epilog Computation Number 1 4 FP 4 2 ,, Company Name,, 5 84 AN ,,, 80 3 Well Name 85 1~4 AN 80 · 4 N~mher oF C~rve.~ on Ta~e 165 166 I.NT ..... 2 5 Filler 167 168 2 ._ 6 Curve Names 169 246 AN 80 7 Tape starting depth 247 250 FP 4 8 ~ ,. TaPe ending, depth 251 254 FP !, 4 '9 ..... Data level spacing 255 258 FP 10 Depth column (=0) 259 260 INT 11 Filler 261 262 ........... 2____ 12 Number of samples of each curve 263 266 Fp .... 4 per record 13 [ Filler 267276 I8 ! P~GF I AI'LfiNTIC RICHFIEln COMPANY .... NGI 7 DRllDHOF BAY .... NORTH SLOPE,/~I.ASKA HLAC 6307 - -:?-'~¥-'¥:: "~7~D'T-;-::'-:!-~9~-~7~7;:": ::" :':'"'"~73:9~¥'"~' T :'¥?':;~ ~ 0'~3 ........ ~'7~ 5'0 3~ ,' 75 ~'' '~ : ':::: :7":::~:9' :""'::~ '::" ......::...:: :. ::: ~: ~::,::.:-~?~:~:::,:~:.~,::,-::--...:~.,-: ' 7" :--'""--"V~:~'~;¥5"~':' ::'~:~::':--:":"¥~ '~;~': : :~¥: ~6~: :':: ~'3q: ~" 37' ,' 50 ~'9','~ ~' .-,,----:---..,,,:,--:~ ,-~::~.:q,::-:::, ~-:~--,~:F;-:----::.,::~:~:: :::::~:Y:~'~::-':~:'-"":~:O::~:~?::~'': ~'~'~'~'~ .......................... ~ :::7 :::~'::':: ~:~:¥:;: : :5~: ::::7::::'"::; :2T~0: ::::~:::":: ~:0:::::::::'~"2 :::::::::::::::::::;::9:?:::::':'" .:::::: ...... ...... -:::::-,:,::::::::::::::::::::::::::: ::--~?-::~:::: "'I-~: P~,GF $~ ATLANTIC RICHFIEL~ COMPANY .... NGI ? PP{tDHO.F.. BAY .... NOPTH SLOPE,ALASKA HI_AC 6:307 .~::... :...._ &::_.i: .Li :,.~,..: .. L... _.:i.'..L2.,.. !.!..~%.::,...21 ...i~ .~..,...~..i..:...~.~,;.!.:.i.~.i,..;...!.....2: L :.,.. L ;. '7: "77;::'"7: :' :"-~':':' PAGE ,i~ ATLANTIC RICHFIELD COMPANY .... NGI 7 PR~ID'HO~ BAY .... NORTH SLOPE,AL/~SKA HL_AC 6~07 A':¥"'F~t:~:~TM ""'F """"i ""'~AM '~':'~.']~ 7": '/'"' '~ ..... · ?:':?.~I'~0::~-' .............................. 1~'~'"I'1 ~8.1~ ............ ~5. ~0 ~.~ .g~ 3~.57 50.02 ;~0%':::;:?:;;:'~7;'L~;B':7~::7:~:T;~ 7~;~'75-'"~ :'"::2:'~[~;9:~?~;:?~:~'~:~:6":='T:::-:'"-5:OT;:OO'?"~'~7:-JO:~ ....................... 2;' 8'0 ........... ~ 7, 50 ....... 50 ~ ]7 ..................... ':"?"'::~'907;78 .............................. 2";'"g~ .......... 37 ,'50 ......... 5~'; 7'~ -~"77::':"7~;'~L~' 0-':7":'":':::~0"~;::00~::':~:?'"2:00";'U0 ............................ ;700"?'"-"~:2"0'0"';0 0 ......................... 2";' :"20'0'"'[00 ....................... O.,o--;,o, o ............ :T~-'~:-;:'5~:"':7'-~"2'OU';'-OO .PAGF- -~-~ ATL^NTIC RICHFIEt_D ~OMPANY .... NG! PRt!BHOF~ BAY .... NORTH SLOPE, "'"~:"¥¥7'~:07 !0~0-~' %"7:"Ii~'6:";' '!i,[~:' "':"-'" :~ -'"i~ 2'; '2~ ~'7' ;50 ..... 7 : . .-.:::-~ ~-:~-.:.~,:~, %~:;:~-~-~v-~ :--,--.~'-o~ ~ ~.o- .~ .................. ~..-;.?~ ........ ~?'~ 5'o ~,'~ ~ "-'""::¥-:--:"~?'~:0:;~'~¥:~70 ':':"'"'":~"~3'~'~'?'"" "7: "= "-:'~: :::~' ':"' '":"'"~ ';"91 .......... 37'; 5 O' ~ ~ ;"0'~' ............ ....... :-~'~':;--'~"~ ~'?', 5'0 ....... ~ ~ ;~ ~ ..... ~T 7'::'TFL38}~;~FT~¥~"~' :: ? ~qg¥2 p'7:'''~ "-"7 -'":P'-';'83 ........ 3'7';50 ........~5';' ~ ~ ~ .... =:~:~:3 ~'~'s3~F~¥~' 77 ' "'37; 5'0 ~'~",' 3~ ""'777~?'~:'~ ~03::~'::~;0~0":' ~':':'"':'~ ~?0 7"""-:=: '?¥~":~?~3~¥'~7¥' :~ 'T:?"~'~:5:,~ ;':.'~:~'': :¥ '~:9'~"~ 3~::~:: :7:'"::72 ;'7 7 '37,"5'0 ..... 3'9 ;~ 7 : · :=:.:':-}::'-~::~'~:9;:~-'-:'~:-''':-~ ~X~ ~'-:~gg :'":": ............. ~-;.77 ............ 3'7 ,'5 0 . 3~;'6 7 ::'?""7:-'-'I' ;"g'2 ::' "3'0 ;'2'2 36; ~ ~'?~:~:~ 07~";7: ¥':" ~':~":7: "7"~70:.¥ ~;:77¥~223~;;~: - %77 ?' -' :¥'8"~¥'~:~;: ?: 7":'7: 0"~7' 9 ......... '25"~ 5'1' .......... 3'~",'-2'~ .......................... 7-:" .::.::~.:.:.~..~:,:.-,:.:~::~ ---:..~2~.~ --=~:.~:--.::::::-~:~.;~:~:.~-.,~.-~----~.'--..~.'~-'~'~-: ~-.~ ............. o'--;-~'2 ........ 2~,-9'~ :~J~; ~!;'..2: :~:~:.'.~ : J.:;:": ~ ~'~:;.~i~':~:~.:.~:"': ,~ '~:' ~,,~.~ , '::i~C:~; :~: '- - 23 ~ 92 3 O' ~ ~ ........... ,'82 ';5I ......................... 28,22 28';'~ 2 ,~3 20,68' 29'27 0 . 8~ 20 , 67 .......... ......... 2, o,-a~ ~o, n~ S..?~-? ~-:::- :;~:0~.':-'--'-7:;- --'-':.:~:-~--';' ~-T-:--"7-'-- "':"~? -0:~ "":'::':':-" "0'-~: :2'3:' ........... 2'2 ~'~I ...... 30' '~ '-~3 : ...... :..:.. o z'9, ~ ~o · ~ o ~ , .............................................. ?.~ ........ _....~..,. ? ............ ~ ..................... ~- .................
