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Home My WebLink About192-116• BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7ih Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, ~J bp ~ ~ JUL 4 1 2009 ~l~s~a Qil ~ Gas Cans. Commi~sion Anchora~~ ~~ ~ ~ ~ ~ I- ~ ~ ~- l~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~-.,~~ }~,9i ~~ ~ ~ ~: (~r;c c~'~t.v~'15gV~D~~S.% ~,!~J;. ~y ~Uv,r Torin Roschinger BPXA, Well Integrity Coordinator . • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-oN Report of Sundry Operations (10-404) S-pad nsee ar~~r~nna Wetl Name PTD R Initial top of cement Vol. of cement um ed Finai top of cement Cement top ofl date Cortosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al S-01B 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 0.25 NA 7.7 5/25/2009 S-03 1811900 1325 NA 13.25 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-05A 1951890 0 NA 0 NA 0.9 5/26/2009 S-O6 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA O.s 5/26/2009 S-088 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA s.a 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 S72A 1851930 025 NA 025 NA 7.7 6/t/2009 S-13 1821350 8 NA 8 NA 55.3 6/1/2009 5-15 1840170 025 NA 025 NA 3 6/2J2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 0.25 NA ~ 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA 1.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.s 5/31/2009 S-29AL1 1960120 0 NA 0 NA 0.85 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S32 1901490 0.5 NA 0.5 ~ NA 3.4 5/31I2009 S33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-34 1921360 0.5 NA 0.5 NA 3.4 5/31l2009 S-35 1921480 0 NA 0 NA .85in 5/31/2009 5-36 1921160 0.75 NA 0.75 NA 425 5/27/2009 S-37 1920990 725 NA 125 NA 17.9 5/27/2009 S-38 1921270 0.25 NA 025 NA 102 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5l30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29/2009 S-101 2007150 125 NA 125 NA t1.s 5/29/2009 5-10211 2031560 125 NA 125 NA 11.1 5/31/2009 S-103 2001660 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2W9 5-106 2010120 1625 NA 1625 NA 174.3 6/2/2009 5-107 2011130 225 NA 225 NA 28.9 5/18/2009 S-108 2011000 3.5 NA 3.5 NA 40 5/30/2009 5-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-110 2071290 11.75 NA 11.75 NA 98.6 5/30/2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 5-172 2021350 0 NA 0 NA 0.5 5/30/2009 S-7t3 2021430 175 NA 175 NA 22.7 5/18/2009 5-714A 2021980 125 NA 125 NA 102 5/30/2009 S-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 S-117 2030120 1.5 NA 1.5 NA 15.3 5/29l2009 S-1te 2032000 5 NA 5 NA 76.5 5/28J2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-t27 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 S-122 2050810 " 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 1.75 NA 11.9 5/2fi/2009 5-725 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 725 NA 15.3 6/1/2009 S-200 1972390 125 NA 125 NA 14.5 5/26/2009 5-201 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042730 2 NA 2 NA 13.6 5729/2009 S-215 2021540 2 NA 2 NA 18.7 6!1/2009 5-216 2001970 4.75 NA 4.75 NA 5t 5/29/2009 &217 2070950 025 NA 025 NA 1] 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 16 NA 99.5 6/2I2009 S-504 - 0 NA 0 NA 0.85 5/28/2009 8-36 (PTD #1921160) Under EVa]""" for sustained casing pressure - TxIA immuniCatiOn Regg, James B (DOA) Page 1 of 1 From: (7 . A q \C( 0 7 ~·./1 ,{ NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Monday, September 17,20077:12 AM Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; NSU, ADWWell Operations Supervisor; Rossberg, R Steven; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr Roschinger, Torin T.; Austin, Paul A; Holt, Ryan P (ASRC); NSU, ADWWI Tech; NSU, ADWWelllntegrity Engineer Subject: S-36 (PTD #1921160) Under Evaluation for sustained casing pressure - TxlA communication Attachments: S-36.pdf Sent: To: Cc: All, Well S-36 (PTD #1921160) has been found to have sustained casing pressure on the IA. The TIOs were SSV/21 001540 psi on 09114/07. A subsequent TIFL failed on 09/17/07. The well has been classified as Under Evaluation and may be produced under a 28-day clock. The plan forward for this well is as follows: 1. D: TIFL - FAILED 2. S: Caliper & CIO S/O 3. D: Re- TI FL SCANNED SEP 2 1 2007 A wellbore schematic has been included for reference. «S-36.pdf» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 9/19/2007 TREE = WELLHEAD = ACTUA TOR = KB. ELEV " BF. ELEV " KOP= Max Angle" Datum MD = Datum ND = 6" 5M CN\! 11" 5M FMC BAKER 70.00' 35.84' 5338' 51 @7118' 113-3/8" CSG, 68#, L-80, ID" 12.415" Minimum ID = 2.635' 3-1/2" REDUCING N I 5-1/2" TBG, 17#, L-80 NSCC, .0232 bpf, ID I 9-5/8" CSG, 47#, L-80, ID PERFORA TION SUM REF LOG: BHCS ON ANGLE AT TOP PERF: Note: Refer to Production DB fo SIZE SPF INTERV AL 0 3-3/8" 4 9738 - 9788 3-3/8" 6 9918 - 9926 3-3/8" 6 9934 - 10076 17" TBG, 26#, L-80 NSCC, .0383 bpf, 10" DATE 11/23/92 1 0/08/04 1 0/13/05 12/31/05 05/02/06 05/14/06 5-36 ¡;AOTES: I 2011' H5-1/2" OTIS SSSV LAND NIP, ID" 4.562" I . ~ ST MD ND DEV TYPE VLV LATCH PORT DATE I 2930' ~ 5 3029 2954 1 MMG DOME RK 16 05/26/06 I 4 5313 5233 8 MMG DOME RK 16 OS/26/06 L 3 7677 7140 42 MMG DOME RK 16 OS/26/06 2 9371 8431 42 MMG SO RK 20 OS/26/06 **1 9443 8485 42 MtvIG DMY RK 0 10/13/05 , @ 9545' ··ST#1 EXT PKG DMY·COVERBJ BY WFD PATCH (05/12/06) IP wINO GO 19432'·9469' ELM 5-112" WFO ECLIPSE PA TCH (05/12/06), I IX ID" 2.992" ~f- 1-1 9463' I 5-1/2" PARKERSWS NIP, ID" 4.562" (BEHIND PATCH) IX ~ ~ 9487' 1-i9 518" x 5-112" SABL-3 PERM PKR, 10" 4.750" I JL.:::o 9525' H5-1/2" PARKERSWS NIP, ID" 4.562" F 7" LNR I 9545' 1-_ II II 9545' H 5-112" OTIS XN NIP, 10" 4.455" I -¡--f 9545' l-i3-1/2" XN REDUCING NlPwl NO GO,ID" 2.635" I " 4.892" I 9558' 9558' H 5-112" W/LEG I I 9568' H ELMD TT LOGGED 02/04/93 I "8.681" I 9721' 1--4 .. [ MARY 11/20/92 Z ........, 9845' 4-112" BAKER PERM FB-1 PKR, 40 @ 9738' ¡¿....:> r his torical perf data ID = 4.00" MILL OUT TO 4.50" pn/Sqz DATE I . 9859' H4-1/2" OTIS X NIP, 10" 3.813" I 0 1 0/15/93 0 02/04/93 . 9868' -1-i4-1/2" OTIS XN NIP, ID = 3.725" I 0 02/04/93 9870' H4-1/2" W/LEG I I 9870' H ELMD TT LOGGED 11/27/941 [ I PBTD I 10221' 6.276" I 10300' I ITOPO DATE OS/26/06 OS/27/06 06/17/06 REV BY COMMENTS RCT/PJC GL V ClO RCT/PJC MIN ID CORRECTION DA V ITLH CORRECTIONS PRUDHOE BA Y UNIT WELL: S-36 ÆRMIT No: 92-1160 API No: 50-029-22301-00 SEC35, T12N, T12E REV BY COMMENTS ORIGINAL COM PLETION RMHlTLP GL V ClO GJB/PJC GLV ClO MORlTLH SET NIP REDUCER (12/17/05) DTRlPJC MIN ID CORRECTION RRD/TLH ECLIPSE PA TCH SET BP Exploration (Alas ka) . !f¿ JIJ~/x STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION RECE\VED SEP 1 4 2006 REPORT OF SUNDRY WELL OPERATlº~&GasGons.GommisSlon 1. Operations Performed: AncnOl CI\tG_ Abandon 0 Repair WellŒJ PIUR PerforationsD Stimulate 0 OtherD Alter Casing 0 Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!J ExploratoryD 1A2-118O 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-22301-00-00 7. KB Elevation (ft): 9. Well Name and Number: 69.30 5-36 8. Property Designation: 10. Field/Pool(s): ADL-028258 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10300 feet true vertical 9211.5 feet Plugs (measured) None Effective Depth measured 10221 feet Junk (measured) None true vertical 9150.2 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 32 - 112 32.0 · 112.0 1490 470 SURFACE 2900 13·3/8" 68# L·80 30 - 2930 30.0 · 2925.0 5020 2260 PRODUCTION 9690 9-5/8" 47# L-80 31 - 9721 31.0 · 8766.0 6870 4760 LINER 755 7" 26# L-80 9545 - 10300 8631.8 - 9212.0 7240 5410 ~CANNEt} SEP 2 0 2005 Perforation depth: Measured depth: 9738-9788,9918-9926,9934-10076 True vertical depth: 8779-8817,8916-8923,8929-9038 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 30 - 9558 4-1/2"12.6# L-80 @ 9845 - 9870 Packers & SSSV (type & measured depth): 5-1/2" Patch @ 9432 - 9469 5-1/2" Baker SABL-3 Packer @ 9487 4-1/2" Baker FB-1 Packer @ 9845 12. Stimulation or cement squeeze summary: RBDMS BFL,SEP ] g 700& Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure TubinR Pressure Prior to well operation: SI 0 0 490 400 Subsequent to operation: 397 674 1226 --- 284 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development[!J ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¡Sundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature Phone 564-5174 Date 9/8/06 Form 10-404 Revised 4/2004 U K IlJ 11\1 A L . . S-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/15/2005 ***WELL S/I ON ARRIVAL*** (pre-patch) PULL STA# 1 DGLV @ 9422' SLM, SET DGLV W/ EXTENDED PACKING IN STA# 1...ATTEMPT TO MIT-T, T-IA TRACKING. 12/16/2005 (pre patch) DRIFT W/ WEATHERFORD DMY PATCH TO THROUGH ST A# 1 @ 9513' SLM, W/ NO PROBLEMS. PULLED PXN PRONG @ 9513' SLM. PULL PXN PLUG BODY @ 9517' SLM. RIH W/ 5.5" x 2.75 XN-NIPPLE REDUCER. 12/17/2005 SET 5.5"x2.75" NIPPLE REDUCER IN XN NIPPLE @ 9545' MD. ***LEFT WELL S, DSO NOTIFIED.*** 12/29/2005 T/I/O= 300/350/750. Temp=SI. OA FL, FL Survey. OA FL @ 1680'. 02/10/2006 T/I/O=350/390/725 Temp=S/I Bleed OA<300 psi, OA FL Post Bleed. Initial OA FL=1800' Bleed OAP to production from 725 psi to 250 psi in 1.5 hrs. Post bleed OA FL= 1580' (92 bbls) lAP dropped 10 psi during OA bleed. Has AIL, S/I at tree. FWHP=350/380/250 04/25/2006 T/I/O=1730/480/400, Temp=SI. TBG & IA FL's (pre-patch). AlLP @ 2000 psi. TBG FL @ 3926' (91 bbls) below STA#5, IA FL @ 150' (7 bbls). 04/29/2006 T/I/O=1850/500/300 Load TBG for E-Line (Patch to restore tbg integrity) Spear in to TBG w/5 bbls of meth followed by 80 bbls of 100* 1 %kcl. Had to shut down. Spear in tub follwed by 319 BBls of 100* and 135 * 1 % KCL followed by 2 bbls of meth spacer caped w/46 bbls of 0* diesel Final Whp's = 100 / 660 / 460 04/30/2006 ATTEMPTED TO SET 5-1/2" WEATHERFORD PB ER PACKER @ 9469 FT. UNABLE TO GET PAST SWS NIPPLE AT 9463'. POOH & FOUND HEAVY ASPHAUL TINE COATING TOOLS. WILL RE-ATTEMPT AFTER BRUSH & FLUSH. **JOB POSTPONED** 05/02/2006 T/I/O=375/480/420 Assist slickline with Brush & Flush. Pumped 5 bbls methanol, 216 bbls crude @ 190*. FWHP's=500/650/450 05/02/2006 ***WELL S/I ON ARRIVAL*** (pre patch) B&F TBG W/ BRUSH & 4.50 G-RING TO XN NIPPLE REDUCER @ 9531' SLM DRIFT WI 5.5" WFD DMY PATCH TO XN NIPPLE REDUCER @ 9531" SLM (NO RESTRICTIONS) ***LEFT WELL S/I*** 05/10/2006 T/I/O=400/490/400. Temp=SI. TBG & IA FL's for EL (pre-patch). TBG FL @ 312'. IA FL @ 186'. Page 1 . . S-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/12/2006 CLEARANCE FROM PAD OPERATOR SET WEATHERFORD 5.5" TUBING PATCH FROM 9432'-9469' AS PER PROGRAM. SHOT TWO 2 STRAND STRING SHOTS AT ELEMENT DEPTHS TO CLEAN SCALE AND INCREASE PROTENTIAL OF GETTING A BETTER SEALING PATCH. SLACKED OFF TO CONFIRM SET OF EACH PACKER, PULLED 900 POUNDS OVER TO CONFIRM UPPER TO LOWER PACKER LATCH WAS GOOD. WORKED TOOL ASSY. AT 100 LBS INCREMENTS OVER TOOL AND LINE WEIGHT AND RAN 20' SLACK EACH TIME UP TO -3300# AS PER WEATHERFORD. PULLED 100 LBS OVER TOOL AND LINE WEIGHT AND SET PATCH. RIG DOWN AND PERFORMED POST JOB WALK-A-ROUND NO LEAKS, NO SPILLS, NO INCIDENTS! CLEARED DEPARTURE WITH PAD OPERATOR JOB COMPLETE! 05/13/2006 T/I/0=350/500/260. Temp=SI. Cold-TIFL PASSED. (post-Patch). IA FL @ 186' (9 bbl). Stack out TBG with AL gas from S-37. Stacked out TBG from 350 psi to 1470 psi in 1 hour 45 minutes. IA FL dropped 18' during TBG stack out. lAP decreased 30 psi to 470 psi during TBG stack out. No change in OAP during stack out. Rig down and monitor for 1 hour. TP decreased 10 psi to 1460 psi during monitor. No change in lAP during monitor. IA OS/24/2006 ***WELL SHUT IN ON ARRIVAL *** SET WHIDDON @ 9413' SLM, ATTEMPT TO PULL VALVE @ STA #2 - 9354' SLM OS/25/2006 PULL DGLV FROM STA'S #2,3,4,5. SET 1.5" GLV IN STA #5 @ 3007' SLM, STA #4 @ 5293', STA #3 @ 7660' SLM OS/26/2006 SET S/O GLV IN STA #2 @ 9356' SLM. PULL CATCHER SUB @ 9403' SLM ***WELL LEFT SHUT IN*** OS/27/2006 T/I/0=250/1370/500. Temp=Hot. TIFL (PASSED) (Post Patch / POP). Stacked out TBG & IA to 1390 psi. IA FL @ 9371' sta#2 (SO). Bled lAP from 1390 psi to 260 psi in 3 hours. TBG pressure increased to 1560 psi. IA FL unchanged @ 9371'. Monitored 1 hour. TBG pressure & lAP unchanged. Final WHP's=1560/260/500 09/03/2006 TestEvent --- 289 STBO, 870 BWPD, 3,068 Mscfpd gas, 2770 Mscf AL Rate FLUIDS PUMPED BBLS 3 Diesel --- PT Surface Equipment 18 Methanol 46 Diesel 216 Crude 399 1 % KCL Water 682 TOTAL Page 2 . TREE = 6" 5M CrN I W8..LHEAD = 11" 5M FMC 8-36 SAFEr OTES: · ACTUATOR = BAKER KB. 8..B! = 70.00' BF. 8..B! = 35.84' KOP= 5338' 2011' 1-i5-1/2" OTIS SSSV LAND NIP, ID=4.562" I Max Angle = 51@7118' . Datum MD = 9855' Datum TVD = 8800' SS ST MD TVD DB! TYÆ VLV LA TCH PORT DATE 113-3/8" CSG, 68#, L-80, ID = 12.415" I 2930' ..4 ~ 5 3029 2954 1 MMG DOME RK 16 OS/26/06 4 5313 5233 8 MMG DOME RK 16 OS/26/06 U 3 7677 7140 42 MMG DOME RK 16 OS/26/06 2 9371 8431 42 MMG SO RK 20 05/26/06 **1 9443 8485 42 MMG DMY RK 0 10/13/05 Minimum ID = 2.635" @ 9545' **ST#1 EXT PKG DMY-COVERED BY WFD PATCH (05/12/06) 3-1/2" REDUCING NIP wINO GO - -i 9432'-9469' ELM 5-1/2" WFD ECLIPSE PA TCH (05/12/06), I ID = 2.992" - - 9463' 5-1/2" PARKER SWS NIP, ID = 4.562" (BEHIND PATCH) :8 ...,..." I 9487' l-j 95/8" x 5-1/2" SABL-3 ÆRM PKR, ID = 4.750" I ""'-'" I . I 9525' -j5-1/2" PARKER SWS NIP, ID =4.562" I . I 9545' -j 5-1/2" OTIS XN NIP, ID = 4.455" I I TOP OF 7" LNR I 9545' I- 11-. II -, 9545' -13-1/2" XN REDUCING NlPwl NO GO, ID = 2.635" I 15-1/2" TBG, 17#, L-80 NSCC, .0232 bpf, ID = 4.892" I 9558' I- 9558' -j 5-1/2" W/LEG I I I 9568' H 8..MD TT LOGGED 02/04/93 I 19-5/8" CSG, 47#, L-80, ID = 8.681" 1 9721' 1--..4 ~ PERFORA TION SUMMA RY J REF LOG: BHCS ON 11/20/92 ~ = I 9845' 4-1/2" BAKER ÆRM FB-1 PKR, ANGLE AT TOP PERF: 40 @ 9738' "--" Note: Refer to Production DB for historical perf data ID = 4.00" MILL OUT TO 4.50" SIZE SPF INTERV AL Opn/Sqz DATE I I 9859' -j 4-1/2" OTIS X NIP, ID = 3.813" I 3-3/8" 4 9738 - 9788 0 10/15/93 3-3/8" 6 9918 - 9926 0 02/04/93 I · 9868' -j 4-1/2" OTIS XN NIP, ID = 3.725" I I 3-3/8" 6 9934 - 1 0076 0 02/04/93 I I 9870' 1-14-1/2" W/LEG I I 9870' H 8..MDTTLOGGED 11/27/941 [] I PBTD 10221' 17" TBG, 26#, L-80 NSCC. .0383 bpf, ID = 6.276" 10300' DATE RB! BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNfT 11/23/92 ORIGINAL COM PLErION OS/26/06 RCT/PJC GL V ClO W8..L: 8-36 10/08/04 RMHlTLP GLV ClO OS/27/06 RCT/PJC MIN ID CORRECTION ÆRMfT No: 92-1160 10/13/05 GJB/PJC GL V ClO 06117/06 DAVfTLH CORRECTIONS API No: 50-029-22301-00 12/31/05 MORlTLH SET NIP REDUCER (12/17/05) SEC 35, T12N, T12E 05/02/06 DTRlPJC MIN ID CORRECTION 05/14/06 RRD/TLH ECLIPSE PA TCH SET BP Exploration (Alaska) Schlumbergep Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth RECE\VEC¡ DEC 2 1 2005 AJaska Oil & Gas coos. çç:IT'.m~k:n AnchcrãQ€ Well Job # Log Description Date BL C-04A 10687728 SBHP SURVEY 01/07/05 1 L 1-15A 10715359 PROD PROFILE W/DEFT 11/04/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 09-33 N/A PROD PROFILE W/DEFT 07/16/05 1 D.S 18-03B 11057071 SBHP SURVEY 12/02/05 1 M-10 11072878 LDL 08/05/05 1 D.S 18-25A 11057072 SBHP SURVEY 12/03/05 1 A-31A 11072881 LDL 08/07/05 1 K-06A 11075903 MEM PROD & INJ PROFILE 07/30/05 1 L 1-27 11058255 PROD PROFILE WIDEFT 10/25/05 1 AGI-10 11087429 LDL 09/05/05 1 S-36 ¡t:J- II 14 11152365 LDL 11/08/05 1 K-20B 11057076 SBHP SURVEY 12/06/05 1 M-18B 11072876 INJECTION PROFILE 08/02/05 1 2-18/L-16 11087185 LDL 10/01/05 1 2-62/0-17 11084325 INJECTION PROFILE 11/21/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~""'C h M~'!i:: D ~io1rw~~~~ JJ4N 2 5 2005 Date Delivered: 12/21/05 NO. 3630 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. Color CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Received bY~1J r@'r 1 ~?[AI '~'~ \\ lI:.¡7 ¡"f¡.::IJ I ~:.,. ì:1 ðl\ II t I Ii \\,'\ ¡i /L\ Ii ¡:J , ~ ) \ I ¡ / r . \ I i: ~ ' ~U~LlLÇ: ) ¡~I: Iii irb' ~/8¡:~\ n l-tJi1\1 (0) ill"PI , ¡ . ! ' ,: ¡I \ 'I il;1 I,d, ''\'" : r/ ! I 1 ~ ~ I : I \ ,: .., I,: \. ~ I ", \} I i I ¡ i : ! "... \ :! I"::' ,,'ì'~ ! ¡ , \ 10 J U \J ~~Lrlj \~J) L~¡ h ) / f ! .f I .9 FRANK H. MURKOWSKI, GOVERNOR AI,4SKA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~q g..-' \ \ (0 Re: Prudhoe Bay S-36 Sundry Number: 305-308 SCANNED NCnf Q)! B 200~ Dear Ms. Julian: 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 fonn. Please provide at least twenty-four (24) hours 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 fùe with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, V~~n - Chainnan DATED this/I day of October, 2005 Encl. · STATEOFALAf:f.~:£<111 /S \JJff=ð~ivEb AU-. )A OIL AND GAS CONSERVATION COMMI.... ¡.oN - APPLICATION FOR SUNDRY APPROVAL OCT 1 0 2009 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4, Current Well Class: Development ~ /' Exploratory D Service D 6. API Number: Perforate U AlaslwJilitljas Cons. £dm"rn·on Stimulate D Time Extension []\nchorage Re-enter Suspended Well D 5. Permit to Drill Number: 192-1160 /' Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 12. Attachments: Descriptive Sum m ary of Proposal 0 Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for é~' Commencing Operations: 10/20/ 005 16. Verbal Approval: \ Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Nam", Jer nifer Jg'an Title Wells Engineer Signature \...,. AM.";". . ^- Phone 564-5663 r IV I y r --..JI\.. V COMMISSION USE ONLY 1. Type of Request: 8. Property Designation: ADL-028258 11. Total Depth MD (ft): 10300 Casing Conductor Surface Production Liner Liner Perforation Depth MD (ft): 9738 - 9788 9918 - 9926 9934 - 10076 Packers and SSSV Type: Suspend U Repair well [2] Pull Tubing D Stratigraphic D 50-029-22301-00-00 9. Well Name and Number: 69.3 KB S-36 ../ Total Depth TVD (ft): 9211.5 10. Field/Pools(s): PRUDHOE BAY Field / PRUDHOE OIL Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10221 9150.18 None Length Size MD / TVD Burst 80 20" 91.5# H-40 32 112 32 112 1490 2900 13-3/8" 68# L-80 30 2930 30 2925 4930 9690 9-5/8" 47# L-80 31 9721 31 8766 6870 25 4-1/2" 12.6# L-80 9845 9870 8860.37 8880 8430 755 7" 26# L -80 9545 10300 8631,75 9212 7240 Perforation Depth TVD (ft): 8778.52 - 8816.73 8916.37 - 8922.51 8928.66 - 9038.01 5-1/2" Baker SABL-3 Packer 4-1/2" Baker FB-1 Packer Tubing Size: 5-1/2" 17# Tubing Grade: L-80 Packers and SSSV MD (ft): 9487 9845 13. Well Class after proposed work: Exploratory D Developm ent 0 15. Well Status after proposed work: Oil ~ / Gas D Plugged D WAG D GINJ D WINJ D Contact Jennifer Julian Date 10/6/2005 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D Other: /' Junk (measured): None Collapse 470 2270 4760 7500 5410 Tubing MD (ft): 30 - 9558 /' Service D Abandoned D WDSPL D BOP Test D ~ Sundry Number: -?j;) ~- -.3i:J c¡- Mechanical Integrity Test Location Clearance D RBDMS 8FL 0 CT 1 2 2005 COMMISSIONER APPROVED BY THE COMMISSION Date: Form 10-403 Revised 11/2004 \......--- OF)'r't\'~t L ,.. ./ ~ ,II J i P I f ." \~~. ~u'bð ~/~ Submit in Duplicate bp ., "....Øl.. . ... .., .' .' .. .. ,... .I~.' ...!,.,¡~'~1' ) ) To: J. Bixby/ D. Cismoski Well Operations Team Leader Date: October 5, 2005 From: Janet Sack Design Engineer Subject: 5-36 OA Cement DownsQueeze Procedure / PB5PDWL36-N Est. Cost: $22M lOR: Ann com Please downsqueeze the OA as described in the following procedure. This procedure includes the following steps: Step Type Procedure 1 F OA cement downsqueeze 2 F MIT OA cement downsqueeze after WOC / ¡ i 5-36 is a PAL with TX:A communication. On 11/14/04 it failed a MITOA to 2800 psi with / a LLR of 3 bbls @ 1450 psi. The OA FL was depressed to 1224' on 10/04/05. This program is designed to pump a column of cement from the shoe to approximately 500' above the shoe. The procedure includes the following major steps: 1. DHD 2. DHD Shoot fluid levels and record WHP's. Bleed the T, lA, and OA to +/- 200 psi and fluid pack with crude as required. /,,/ OA Downsqueeze MIT OA after waiting on cement. 3. 0 4.0 If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W) 564-5663, (H) 274-0929, (Cell) 240-8037. cc: w/a: Well File J. Sack J. Young ) ') JOB PLANNING DETAILS: > 11/14/04: MITOA Failed, 3 bpm @ 1450 psi > 09/13/05: TIFL Failed BUR & Inflow > 10/02/05: Depressed OA FL to 378' > 10/03/05: Depressed OA FL to 882' > 10/04/05: Depressed OA FL to 1224' / Well has TxlA communication. /' OA= 13-3/8" 68# L-80 IA= 9-5/8" 47# L-80 Shoe at 2930' OAxlA Annular Capacity=.0597 bbls/ft Volume to shoe = 175 bbls 500' of cement = 30 bbls ,/,/''''/ Oisplacement= 175 -5 (H20 spacer) - 30 (cement) - 5 (H20 flushy= 135¡obls - ( ,-<,/ --,.~~.,~ Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 400 bbls of =80 degree F (includes water for cement mixing and clean up.) 60/40 Methanol: 20 bbls Crude Displacement: 135 bbls at 30-60 degree F Crude: (volume needed to load OA, OA FL was 1224' on 10/04/05) OS CW1 01: .1Q bbls Arctic Set 1 Cement (15.7 ppg): 30 bbls pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. PREP WORK (pre downsQueeze): DHD/FB: 1. Shoot FLs and record WH Ps. 2. The day prior to the downsqueeze, bleed the OAP to +/- 200 psi. 3. Fluid Pack the OA with crude. CEMENTING OPERATIONS: FB Pumping 1. Hold a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. ) ) 2. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. /' 3. If well has IA x OA communication (well has not shown this communication to date), the IA pressure must be maintained at a pressure greater than the OA treating pressure to ensure no cement enters the IA. Tie into the IA with a LRS or pump. 4. Flood lines with warm fresh water and pressure test lines to 3000 psi. 5. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the maximum pressure of 2000 psi. Note injectivity at pertinent times during the displacement. Start pumping into the OA as follows: a. 10 bbls of 60/40 Methanol to establish injectivity b. 10 bbls of OS CW101 surfactant (optional) c. -260 barrels of 800 freshwater to flush OA (approx. 1.5 x annular volume) d. 5 bbls of fresh water spacer e. 30 barrels of 15.7 ppgArctic Set 1 cement f. 5 bbls of fresh water flush g. 135 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 125 bbls of displacement has been pumped./ Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 6. Shut down pumps and leave the well SI. Please DO NOT try to achieve a sQueeze or to build sQueeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 7. Notify the Pad Operator prior to leaving location that the OA may be subject to /' rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. POST SQUEEZE FULLBORE: 8. MIT-OA to 2800 psi. Previous OA History: CIT -OA to 2800 psi - (Failed). Est LLR of 3 BPM at 1450 psi. Final TI0=200/1 060/280 TREE:: 6" 5M crvv WELLHEAD:::: 11" 5M FMC .- .~~ ACTUA TOR:= BAKER KB, ELEV :: 70,00' .,., .."-_."_.~"..__."._-""..~.~,_.....,,..._,,"""_._,,.."--_.,,-~".~...,._-_..""... BF, ELEV :: 35,84' KOP:: 5338' Max Angle:: 51 @ 7118' Datum MD :: 9855' Datum lV D :: 8800' SS -) 8-36 /1 SAFE" lOTES 1t'J'!!t.1::,¡, ~ 2011' 1---15-1/2" OTIS SSSV LAND NIP, 10:: 4.562" 1 Minimum ID = 3.725" @ 9868' 4-1/2" OTIS XN NIPPLE GAS LIFT MANDRELS ~ ST MD lVD DEV TYPE VLV LA TCH PORT DATE 5 3029 2954 1 MMG DOME RK 16 4 5313 5233 8 MMG DOME RK 16 L 3 7677 7140 42 MMG DOME RK 16 2 9371 8431 42 MMG DMY RK 1 9443 8485 42 MMG S/O RK 20 10/08/04 I 9463' 1-15-1/2" PARKER SWS NIP, ID:: 4,562" I 113-3/8" CSG, 68#, L-80, 10:: 12.415" 1-1 2930' .. z z --1 9487' 1-195/8" x 5-1/2" SABL-3 PERM PKR, 10:: 4.750" I I 9525' 1-15-1/2" PARKER SWS NIP, ID:: 4,562" I I TOP OF 7" LNR 1-1 9545' h I-~ 9545' 1---15-1/2" OTIS XN NIP, 10:: 4.455" 1 ~ 1 5-1/2" TBG, 17#, L-80 NSCC, ,0232 bpf, 10:: 4,892" 1-1 9558' ~ 9558' 1-15-1/2" W/LEG 1 9568' 1-1 ELMO TI LOGGED 02/04/93 I 19-5/8" CSG, 47#, L-80, ID:: 8.681" 1-1 9721' ~ .,. PERFORA TION SUMMARY REF LOG: BHCS ON 11/20/92 ANGLE AT TOP PERF: 40 @ 9738' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9738 - 9788 0 10/15/93 3-3/8" 6 9918 - 9926 0 02/04/93 3-3/8" 6 9934 - 10076 0 02/04/93 9870' 9870' 1- 4-1/2" BA KER PERM FB-1 PKR, 10:: 4,00" MILL OUT TO 4.50" 1-14-1/2" OTIS X NIP, 10:: 3.813" 1 1-14-1/2" OTIS XN NIP, 10:: 3,725" 1 1---14-1/2" W/LEG I 1---1 ELMD TI LOGGED 11/27/94 I z z 9845' f ~ 9859' 9868' I PBTO 1-1 10221' I 17" TBG, 26#, L-80 NSCC, ,0383 bpf, 10:: 6,276" 1-1 10300' OA TE REV BY COMMENTS 11/23/92 ORIGINAL COM PLEfION 09/07/01 RNlTP CORRECTIONS 10/08/04 RMHlTLP GL V C/O OA TE REV BY COMMENTS PRUDHOE SA Y UNIT WELL: S-36 PERMIT No 92-1160 API No: 50-029-22301-00 SEC 35, T12N, T12E BP Exploration (Alaska) THE MATERIAI~ UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000, E E pl~. E W M A T E R IA L U N D ER TH IS M ARK ER C:LORihMFILM.DOC LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 February 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PLS/STATIC FINAL BLF PLS/STATIC BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF ECC No. Run # 1 5788.07 Run ~ 1 5867.07 Run # 1 5887.10 Run # 1 5995.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: sign and re%urn ~.o; Petrctec~'n~ ca~ D~,~a~ ~' EIVED Date 1995 Alaska Oil & Gas Cons. Commission Anchorage AOGCC zhO. mvidual We~t logical Materials Invente PERMIT DATA T DATA_PLUS 92-116 5477 T 7968-10320 BCS/DTE/GR 1 ~-116 5478 T 97~5~ -10203 RFT 1 92-I16 407 92-116 DWOP 92 1116 SUR ~JE .~ 92-1i. 6 BHC/SL/GR 92-116 CALl R COMP DATE'02/04/93 R 11/07-i!/24/93 R 0.00-9652 L 9718-10264 1 L PACKER SETTING REC. 92-!16 PDI/SFL/GR L 8000-10294 1 _ /STAT PRESS L 9700 9971 1 92-1~6 PDLS? - 92-116 PFC L 9380-10200 1 92~i16 PFC PACKER REC L 9250-10000 i 9°-!1~~ ~ PFC/CCL (PERF) L 9700-9810 1 92-11t. 6 PFC/GR PERF REC L 9765-9986 1 92-116 PLS L 9800-9968 I 92-116 PROD L 9650-10139 1 92-i16 RFT L 9755-10203 1 92-'116 SBT L 9250-10212 i ,~- = i 6 SBT/GR/CCL L ,~H 92-116 SSTVD L 9718-10294 i Page - Date- 01/23/95 RUN DATE_RECVD !.2,/22/1992 12/22/1992 02/19/1993 02/19/1993 02/19/1993 12/22/1992 12/18/1992 12/18/le9~ 12/07/1994 02/18/1993 12/18/1992 10/19/1993 07/12/'1993 06/03/1994 04/05/1993 12/18/1992 12/18/1992 12/22/1992 12/18/1992 Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS yes no ye s ilo LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION R-21 A \1. R-24 %6 .\\~S-36 (41-34-12-12) ~L~ B-02 (32-11-14) 1 PLS FINAL BL + RF 1 PLS FINAL BL + RF 1 CN/GR FINAL BL + RF 1 PLS FINAL BL + RF 1 PFC/PERF FINAL BL+RF i CN/GR FINAL BL +RF 1 PLS FINAL BL + RF Date: 1 December 1994 Transmittal of Data Sent by: MAIL Run # 1 · .. Run ~ 1 Run # 1 · - Run # 1 -- Run # 1 Run # 1 Run # 1 ECC No. 4952.03 5089.04 5770.02 5788.06 5803.07 5811.05 5867.06 Please sign and return to.- A~~as Wireline S vi~~ces 560~_Street/ Anchorag_~/AK 99518_ Attn. R~n~D. Paulson or_~~to {9o'~-78o3 Received by: Date: -\ STATE OF ALASKA ALAS .... 'OIL AND GAS CONSERVATION COMMISSIC REPORT Or: SUNDRY WELL OPEnATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well_ Perforate X Other × 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1646' SNL, 1888' EWL, SEC. 35, T12N, R12E At top of productive interval 383' SNL, 645' WEL, SEC. 34, T12N, R12E At effective depth 295' SNL, 812' WEL, SEC. 34, T12N, R12E At total depth 279' SNL, 873' EWL, SEC. 34, T12N, R12E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE=69.3' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-36(41-34-12-12) 9. Permit number/approval number 92-116 / 10. APl number 50- 029-22301 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2865 Intermediate 9699 Production -- Liner 736 Perforation depth: measured 10300 feet Plugs (measured) 9204 feet 10218 feet Junk (measured) 9141 feet Size Cemented 20 11 yds Arcticset 13 3/8 1100/480 sx cs III/11 9 5/8 1030 sx Class "G" 7 267c. f. Class "G" 9918'-9926', 9934'- 10076' Measured depth 111 2928 9720 9564-10300 True verticaldeCh BKB 111 2923 8765 8646-9212 true vertical subsea 8914'- 8920', 8926'- 9034' Tubing (size, grade, and measured depth) 5 1/2",L-80 @ 9558' Packers and SSSV (type and measured depth) Packer @9487' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1890 1129 64 1007 2080 3460 1873 1115 Tubing Pressure 265 312 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S~ ned ~ '~1 ~:--~'~,' ~ i~-,:~,~-~,i,,ii ~,--ii,,~-i '~ /'~' ~:~.,'V-~,,, ,i Title Senior Technical Assistant I Form 10-404, Rev 06/15/88 ~/ Date SUBMIT IN DDPLI~ATE 4/05/93 6/28/93 WELL S-36(41-34-12-12) FRAC/ADDPERF/REPERF Performed a Hydraulic Fracture using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST: 50 BBLS DIESEL TO SET TREE SAVER 430 BBLS 20g GEL INJECTIVITY TEST DATA FRAC: 25 BBLS 40g GEL PREPAD TO ESTABLISH RATE 260 225 75 IFRAC: 233 67 16 22 28 32 36 38 LOAD 220 BBLS 40g X-LINK GEL PAD W/2.5% ESL (275 GAL) BBLS 20g GEL DATA FRAC FLUSH BBLS DSL TO FREEZE PROTECT WELL 30 BBLS 40g GEL PREPAD TO ESTABLISH RATE BBLS 40g X-LINK GEL PAD W/2.5% ESL (245GAL) Dirty 1 PPG 2 PPG 3 PPG 4 PPG 5 PPG 6 PPG 7 PPG 10 8 PPG VOLUME:1577(TOTAL FLUIDS PUMPED DOWN HOLE) Total diesel pumped downhole The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9918'-9928'MD 9934'-9980'MD 7/02/93 Performed a Hydraulic Refracture using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST: DATA FRAC: 240 225 FRAC: 30 181 65 12 17 20 24 26 27 29 30 175 225 LOAD VOLUME: 20 445 BBLS 2O# GEL 30 BBLS 40# GEL PREPAD TO ESTABLISH RATE BBLS 40# X-LINK GEL PAD BBLS 20# GEL DATA FRAC FLUSH BBLS 40# GEL PREPAD TO ESTABLISH RATE BBLS 40# X-LINK G EL PAD Dirty 1 PPG 2 PPG 3 PPG 4 PPG 5 PPG 6 PPG 7 PPG 8 PPG 9 PPG 10 PPG 20# LINEAR GEL FLUSH 1801 (TOTAL FLUIDS PUMPED DOWN HOLE) Total diesel pumped downhol e 10/15/93 fjh 6/20/94 Page 2 WELL S-36(41-34-12-12) The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9738' - 9788' MD Sag Perf ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 17 May 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION z-25 K-10 (31-05-11-14) J-lO (iO-1!-13) q2_-I~ S-38 (24-26-12-12) o~ ?__/Q'k s-33 (11-35-12-12) ~l- l q~ s-35 (23-26-12-12-) ~-I I~ S-36 (41-34-12-12) Cont/ /% PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA /1 PFC/PERF FINAL BL ' ! PFC/PERF RF SEPIA /1 DIFF.TEMP. FINAL BL 1 DIFF.TEMP. RF SEPIA i DIFFTEMP/GR FINAL BL /1 DIFFTEMP/GR RF SEPIA /I PLS FINAL BL 1 PAS FINAL RF SEPIA /l PLS FINAL BL 1 PLS FINAL RF SEPIA 1 PLS FINAL BL 1 PLS FINAL RF SEPIA ~l PLS FINAL BL ! PLS FINAL RF SEPIA ,~i PDK/GR/CCL FINAL BL I PDK/GR/CCL RF SEPIA ECC No. Run # 1 6196.00 Run # 1 Run # 1 6162.01 Run # 1 Run # 1 3556.04 Run # 1 Run # 1 4887.03 Run # 1 Run ~ 1 5840.03 Run # 1 Run # 1 5750.09 Run # 1 Run # 1 5867.05 Run # 1 Run # 1 5788.05 Run # 1 Run ~ 1 5858.05 Run # 1 This is to acknowledge receipt of the following prints and negatives. COMPANY: STATE OF ALASKA - ALASKA OIL & GAS COMMISSION ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA X-22 DILF/GR 2~" 1 0 1 X - 22 BHC/AC - GR n ~ ~'' X-22 WATER SATURATION ~,, 1 ;Q~,Q~ -. 1%~3q %0 1 S-36 t PFC/CCL(PERF) S,t 1 ~__ fl%tO0 1 OCF Please reB~r~ o~e copy of s±~ed tra~±ttal to eaah of the follow±:~ Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT~ RTNCARD 1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/07/93 T# 84739 BPX/PBUOLOGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at ~-4oq~'~q ~z~ o6/28/93 #1 F-1i~"~ ?RODUC?ION LOG 06/26/93 #1 N-20 ~ PERF 07/01/93 #1 S-2490-~ PERF 07/01/93 #1 S-2590-%0~ PERF 07/01/93 #1 S-33q~-IOL PERF 07/03/93 #1 S-34~L-~ PERF 06/30/93 #1 S-35q~-[q~ PERF 06/30/~ #1 S-36 ~%-[J~ PERF 06/28/93 #1 S-38~%-~ PERF 07/01/93 #1 Z-199~,Z% PERF 06/30/93 #1 below. If you have any (907) 564-4004. 9200.00-10194.00 ATLAS 10980.00-12361.00 ATLAS 10980.00-12361.00 ATLAS 9915.00-10056.00 ATLAS 9700.00- 9950.00 ATLAS 9058.00- 9253.00 ATLAS 900Q,00- 9200.00 ATLAS 10100.00-10259.00 ATLAS 9500.00- 9702.00 ATLAS 9765.00- 9986.00 ATLAS 9200.00- 9350.00 ATLAS 13940.00-14224.00 ATLAS 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " Information Control Well Records RECEIVED ,.. JUL. 1 2 199,5 AJaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. DATE: 03-26-93 T# 84484 RECEIVED APR 0 5 1993 Alaska 0il & (~as Cons. Commissl0~] Anchorage A-32~,l~O CH 03/20/93 REF#124709 J-22 ~7~17 CH 03/18/93 REF#124815 J-24~~6~ CH 03/20/93 REP#124817 S-36 ~-~1~ CH 03/22/93 REP#124774 X-14A~--I~H 03/21/93 REP#124773 VERTILOG (4.5" TUBING) PFC GAMPLA RAY (PERFORAT PFC GAMMA RAY (PERFORAT PRODUCTION LOGGING SERV SEGMENTED BOND LOG;GAMM ATLAS ATLAS ATLAS ATLAS ATLAS Information Services Well Records ~ STATE OF ALASKA ALASKa, ,JIL AND GAS CONSERVATION CL,,MMISSION ~ ~ ~ ~ ,i i~! A ~ WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SLISPEI,,~r.D [] ABAND(~ED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 92-116 3. Address 9. APl Number 50- 029-22301 P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1646' SNL, 1888' EWL, SEC. 35, T12N, R12E At Top Producing Interval 383' SNL, 645' WEL, SEC. 34, T12N, R12E At Total Depth 279' SNL, 873' WEL, SEC. 34, T12N, R12E 9. unit or Lease Name Prudhue Bay Unit 10. Well Numb~- S-3b (41-34-12-12) 1. Fic, ld and Pool Prudhoe Bay Field/Prudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 69.3' I ADL 28258 12. Date Spudded !13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 115. Water 11/7/92 I 11/19/92 ! 2/4/93 I N/Aeet MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)~19. Directional Survey ~20. Depth where SSSV set 121. Thickness of Permafrost 10300'MD/9204'TVD ~ 10218'MD/9141'TVD ! YES E~ NO [] ! 2011¢eet MD I .1900'(Approx.) 22. Type Electric or Other Logs Run Run #1 DIL/GR/SP/SDT Run #2 RFT/GR 23. CASING, LINER AND CEMENTING RECORD CASING SIZE w-r. PER FT. GRADE 20' 91.5# H-40 13-3/8' 68# L-80 9-5/8' 47# L-80 7' 26# L -8O open to ProdUcti~o;,!MD+TVD" of Top and Bottom and 24. Pedorations interval, size and number) · Gun Diameter 3-3/8" MD 4~ 9918:9926' 8914 ;8920' 9934; 10076' 8926'-9034' SETTING DEPTH MD TOP BOTTOM 32' 110' 31' 2928' 31' 9720' 9564' 10300' HOLE SIZE CEMENTING RECORD 30" 11 ),ds Arcticset 16" 1100 sx AS 111/480 sx AS il 12-1/4" 1030 sx C/ess "G" 8-1/2" 267cu ft Class "G" AMOUNT PULLED 25. TUBI'4G RECORD SIZE 1/2", L-80 DEPTH SET (MD) 9558' PACKER SET (MD) 9487' 26. ACID, FRACTURE, CEMENT SQUE~. ETC. DEPTH t~rERVAL (MD) AMOUN-I' & KIND OF MATERIAL,.~:SEO 27. PRODUCTION TEST Date First Production [Method of Operation (Flowing, gas lift, etc.} 2/5/93 I Gas Lift Date of Test' Hours Tested ~,_..ST PERIOD 'PRODUCTION FOR JOIL-BBL GAS'MCF WATER-BBL ICHOKESIZE ?AS-OIL R'~'T"D ~ .~;':~v~' Tubing Casing Pressure ~ALCULATED jOIL-BBL GAS-MCF WATER-BBL JOiL GRAVITY-A'PI (corr) Press. [24-HOUR RATE I~ J 1~8. CORE DATA Brief description of lithology, p(~rosity, frac!~,~'.~'~s, apparent dips, and presence o! oil, gas or water. Submi~ cor~ chips. RECEIVED FEB 1 9 '~ ,Alaska .0ii & Gas (;0[~s. Comm~ss~0~ ~Anch0rage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 2cJ. " 30. GE-(Z~OGIC MARKERL ,--ORMATION TESTS NAME Include interval tested, pressu,9 data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9737' 8777' Top Shub/~k 9788' 8816' Top Sadlerochit 9616' 8913' 31. LiST OF ATTACHMENTS 32. I heresy ,: ertify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and tog on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. I'.~em 5: Indicate wh;ch elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this weli is completed for separate production fror~ more than one intervaJ (multiple com,~letion), so state .in item 16, and in item 24 show the producing interwls for only the interval reported i~ item 27. Submit s sep...zrate form for each additional inte~'val to be separately produced, showin; tr~e ~,~:. pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemer, tal records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Form 10-407 Item 27: Method of Operation, Flowing, Gas Li!~, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. R ~ C E IV E D Item 28' If no cores taken, indicate "none". Alaska Oil & Gas Co~'~s. Commissio~ Anchorag~ BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: S-36 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/06/92 01:00 SPUD: 11/07/92 09:00 RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 28E 11/07/92 ( 1) TD: 710' ( 710) DRILLING MW: 8.8 VIS:300 MIRU. ORIENT BHA. DRILL FROM 108 - 170' 11/08/92 (2) TD: 2120' (1410) 11/09/92 ( 3) TD: 2945' ( 825) 11/10/92 ( 4) TD: 2955' ( 10) 11/11/92 ( 5) TD: 4627' (1672) 11/12/92 ( 6) TD: 6380'(1753) 11/13/92 ( 7) TD: 7200'( 820) 11/14/92 ( 8) TD: 8100' ( 900) TRIP (BHA) MW: 9.5 VIS:300 CIRC. DRILL TO 1902'. CBU. WIPER TRIP. DRILL TO 2120' PUMP DRY JOB. RUN 13-3/8 CASING MW: 9.8 VIS:248 TIH W/BHA#2. CIRC. DROP SINGLE SHOT SURVEY. RUN 13-3/8 CASING. PERFORM LOT MW: 9.1 VIS: 38 RUN 13-3/8 CASING. CIRC & RECIPROCATE. PUMP WATER & CEMENT. TEST BOPE. MAKE UP BHA %3. TIH. CBU. TEST 13-3/8 CASING. CBU. RETEST CASING. RIH W/BIT #3 MW: 9.7 VIS: 44 PERFORM LOT. DRILLING TO 3895' CIRC. SHORT TRIP TO SHOE. DRILLING TO 4627' CBU. POH. RIH W/BIT #3. DRLG. MW:10.0 VIS: 41 REAM F/ 4510'-4627'. DRLG F/ 4627'-5509' CIRC. SHORT TRIP i1 STDS. DRLG F/ 5509'-6380' DRLG. DRLG F/ 6380'-7098' CBU POOH. 7000'-7098' DRLG ~/ 709~'-7200' MW:I0.3 VlS: 42 RIH W/ BIT. REAM ~/ DRILLING AT 8100' DRILLING FROM 7200' TO 8100'. MW:10.2 VIS: 43 11/15/92 ( 9) TD: 9250' (1150) DRILLING AT 9250 DRILLED TO 8183' MW:10.3 VIS: 42 SHORT TRIP TO 7000' DRILLED TO 9250' 11/16/92 (10') TD: 9329'( 79) WORK ON MUD LINE T MW:f0.4 VIS: 40 DRILLED TO 9297' SHORT TRIP TO 8000' DRILL TO 9329' CBU. DROP TOTCO & PUMP PILL. POH & CHANGED BiT. RET~2~ TO 9264' REPAIR MUD LINE T. FEB 1! 9 I~ WELL : S-36 OPERATION: RIG : NABORS 28E PAGE: 2 11/17/92 (11) TD: 9730' ( 401) 11/18/92 (12) TD: 9730' ( 0) 11/19/92 (13) TD: 9830' ( 100) 11/20/92 (14) TD:10300' ( 470) 11/21/92 (15) TD:10300' ( 0) 11/22/92 (16) TD:10300 PB:10218 11/23/92 (17) TD:10300 PB:10218 11/24/92 (18) TD:10300 PB:10218 TD 12-1/4 HOLE AT 9730 MW:10.2 VIS: 39 TEST MUD LINE. CIRC. RIH. CBU. RIH. WASH & REAM. CIRC & COND MUD. DRILL TO 9730 12-1/4 TD. CEMENT 9-5/8 CASING MW:f0.3 ViS: 45 CBU. WIPTER TRIP. CIRC. DROP SURVEY. TEST BOP. RUN 9-5/8 CASING. CBU. TEST CEMENT LINES. PUMP SPACER. DRILLING MW: 9.0 VIS: 38 INSTALL 9-5/8 PACKOFF & TEST. TET BOPE. TIH. CBU. TEST 9-5/8 CASING. DRILL TO 9740' CIRC. DRILL TO 9830' WL LOGGING MW: 8.1 VIS: 39 DRILL TO 10300' WIPER TRIP TO 9-5/8 CASING SHOE. CIRC. PUMP DRY JOB. POOH FOR OPEN HOLE LOGS. RUN #1 DIL/GR/SP/SDT TP 10302' TIH W/7" LINER MW: 9.0 VIS: 41 LOGGING RUN #2. RFT/GR. TIH. CUT & SLIP DRILLING LINE. TIH. CIRC & PUMP DRY JOB. POOH. TEST BOPE. RUN 7" LINER. PUMP LINER VOLUME. TIH. LAY DOWN 5" DRILL PIPE MW: 8.5 Seawater CIRC AT 9-5/8 CASING SHOE. TIP. CIRC LINER. TEST CEMENT LINE. SET HANGER & PACKER. REVERSE CIRC. TEST RAM BODY. TIH. CBU. TEST CASING. DISPLACE WELL TO SEAWATER. LD DP TO TOL AT 9462'. CIRC. POOH. RUN 5-1/2 COMPLETION MW: 8.5 Seawater RUN SBT/GR. RUN BAKER RETRIEVABLE PRODUCTION PACKER. GR FAILED. POOH. SET PACKER. RUN 5-1/2 COMPLETIO~f. TEST CONTROL LINES. RIG RELEASED MW' 8.5 Seawater RIH W/5-!/2 COMPLETION. TEST CONTROL LINES. SET PACKER. TEST AL~ULUS. PUMPED DIESEL DOWN ANNULUS. SET BPV. ND BOPE. TEST CONTROL LINES. TEST TREE. PULL PLUG. SET BPV. SECURE WELL. RIG RELEASED. SIGNATURE: (drilling superintendent) DATE: Ff'~?:"'~RY-SUN DRI'LLTNG SERVI'CES ANCHORAGE ALASKA PRUDHOE BAY DRTLLING PBU/S-36I 500292230100 NORTH SLOPE COHPUTATTON DATE: 11/23 /92 PAGE DATE OF SURVEY' 111792 1',4W D SURVEY JOB NUMBER: AK-HW-20086 KELLY BUSHING ELEV. = 69.30 OPERATOR: BP EXPLORAT'rON FT. TRUE SUB-SEA HEASD VERTZCAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE INCLN DIRECTION DG MN DEGREES DLS TOTAL RECTANGULAR COORD DG/IO0 NORTH/SOUTH EAST INATES /WEST VERT. SECT. 0 ,00 -69,30 186 186,00 116,70 364 363,99 294,69 543 542,99 473,69 664 663,99 594,69 0 0 N ,00 E 0 24 S 75,90 E 0 24 S 79,30 E 0 6 N 58,00 E 0 36 N 34,00 E ,00 .OON ,22 ,16S ,02 ,42S ,19 :46S ,42 .12N .OOE ,63E 1.84E 2.59E 3,03E .00 -,63 -1 .84 -2.52 -2,66 783 782,96 713,66 908 907,84 838,54 1033 1032,59 963,29 1161 1160,19 1090,89 1351 1349,40 1280,10 1 42 N 42,30 E 3 0 N 43,00 E 4 11 N 46,20 E 4 54 N 39,10 E 5 30 N 38.40 E ,93 1,95N 4.57E 1,04 5,71N 8.05E .97 11,27N 13,58E .70 18.76N 20.41E ,32 32,19N 31,19E -3,21 -4,63 -7,09 -9.84 -13.45 1446 1443,96 1374,66 1599 1596,18 1526,88 1758 1754,31 1685,01 1884 1879,83 1810,53 2039 2034.58 1965,28 5 30 N 45.10 E .68 6 5 N 31,80 E .96 5 54 N 10,10 E 1,42 3 47 N 5,20 E 1.70 2 42 N 13,00 W .96 38.97N 37,24E 51.06N 46,72E 66.28N 52,60E 76,81N 54,12E 85.49N 53,76E -15.82 -18.87 -17,30 -13,93 -9.73 2334 2329,29 2259.99 2584 2579.12 2509.82 2901 2896,00 2826,70 3220 3214,94 3145,64 3537 3531,92 3462,62 2 24 N 17.90 W .13 1 42 N 7.30 W .32 1 23 N 11.00 W .10 0 48 N 37.50 W .24 0 30 N 47,30 W ,10 98.13N 50,30E -,96 106,79N 48.22E 4,78 115,26N 46,88E 9,77 120,85N 44.78E 14,15 123.54N 42.42E 17,47 3853 3847.91 3778.61 4171 4165,91 4096,61 4585 4579,89 4510,59 4737 4731,86 4662.56 4926 4920.31 4851.01 0 18 S 86.00 .W .12 0 12 S 5.00 W .10 0 48 S 61.30 E .18 2 5 N 80.50 W 1.89 6 18 N 77.70 W 2.22 124.42N 40.58E 123.81N 39,70E 121.70N 42.17E 121,65N 40,36E 124,44N 26.80E 19,51 2O,O2 16,86 18,47 31 ,83 5116. 5108,83 5039,53 5338 5328,16 5258.86 5561 5546,03 5476.7.3 5688 5668.02 5598.72 5877 5844.30 5775.00 7 54 N 78,30 W ,84 9 48 N 71,80 W ,97 14 41 N 63,80 W 2,32 17 36 N 58,10 W 2,60 24 30 N 60,80 W 3,69 129.30N 3.83E 138.30N 29.05W 156.73N 72.50W 174.00N 103.27W 208.26N 161,81W 54,54 87,97 135,07 170,31 238,00 6004 5958,04 5888.74 6131 6068,46 5999,16 6321 6230,28 6160.98 6545 6415,40 6346,10 6703 6538,15 6468.85 28 17 N 63,80 W 3,17 30 53 N 65,90 W 2.20 32 24 N 57,40 W 2,47 36 5 N 57,40 W 1,65 41 54 N 61,00 W 3,94 234.41N 211.83W 261.02N 268.62W 308.39N 356.08W 376.30N 462.27W 427.01N 547.71W 294.43 357,13 456,55 581,91 681,02 SpeRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/S-36I 500292230100 NORTH SLOPE COMPUTATION DATE: 11/23/92 DATE OF SURVEY: 111792 MWD SURVEY JOB NUMBER: AK-MW-20086 KELLY BUSHING ELEV, = 69,30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/IO0 NORTH/SOUTH EAST/WEST VERT, SECT. 6894 6674.00 6604, 7118 6820.75 6751. 7308 6945,88 6876, 7435 7034,56 6965. 7658 7196.29 7126. 70 47 24 N 58'.20 45 50 47 N 65.50 58 46 47 N 66.20 26 44 35 N 67.80 99 42 24 N 69,00 3,06 495,03N 663,34W 2,89 574,55N 812,54W 2,12 633,05N 942,95W 1,95 668,.58N 1026,59W 1,05 725,10N 1169,26W 814,87 983.89 1126.69 1217.38 1370.25 7785 7292.13 7222. 7977 7439.53 7370. 8168 7585.63 7516. 8422 7780.63 7711. 8678 7976.59 7907. 83 39 35 N 71,40 W 2,53 23 40 5 N 68,30 W 1,07 33 40 5 N 69,70 W ,47 33 39 35 N 66,60 W ,81 29 40 30 N 68,20 W ,53 753,36N 1247,62W 1452,96 795,75N 1363,07W 1575,16 839,83N 1477,92W 1697.59 900,36N 1628,94W 1859,71 963,64N 1781,00W 2024.01 8932 8170.31 8101, 9187 8363.37 8294. 9375 8503.89 8434, 9502 8599,08 8529. 9652 8712.71 8643. . 01 40 5 N 69,00 W ,26 07 41 30 N 73,20 W 1.21 59 41 47 N 68,30 W 1,74 78 41 5 N 66,20 W 1,23 41 40 24 N 64,80 W ,77 THE CALCULATION PROCEDURES ARE BASED THREE-DIMENSION MINIMUM CURVATURE 1023.58N 1933.95W 2187.60 1077.45N 2091.54W 2352.61 1118.63N 2209.41W 2476,44 1151,12N 2286.93W 2560.30 1191.71N 2376.03W 2658,13 ON THE USE OF METHOD. HORIZONTAL DISPLACEMENT = 2658,13 FEET AT NORTH 63 DEG, 21'MIN, WEST AT MD = 9652 VERTICAL SECTION RELATI.VE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 296,64 DEG, S,'~ ..... TRY-SUN DRILLTNG SERVTCES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRZLLZNG PBU/S-36Z 500292230100 NORTH SLOPE COMPUTATION DATE' 11/23/92 DATE OF SURVEY' 111792 JOB NUMBER' AK-MW-20086 KELLY BUSHING ELEV. = 69.30 OPERATOR' BP EXPLORATION FT, INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -69.30 .00 N .00 E .00 1000 999.68 930.38 9.60 N 11.84 E .32 2000 1995,62 1926,32 83.70 N 54,17 E 4.38 3000 2994.97 2925.67 117,63 N 46.42 E 5,03 4000 3994,91 3925.61 124.37 N 39.81 E 5.09 .32 4.06 ,65 .07 5000 4993.86 4924.56 126.16 N 18.87 E 6.14 6000 5954,52 5885.22 233.57 N 210.13 W 45.48 7000 6744,69 6675.39 534.52 N 731.72 W 255.31 8000 7457.13 7387.83 801.22 N 1376.84 W 542.87 9000 8222,19 8152.89 1038.93 N 1975.15 W 777.81 1.05 39.35 209.82 287.56 234.94 9652 8712.71 8643.41 1191,71 N 2376.03 W 939.29 161.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. Ff"-"RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING. PBU/S-36I 500292230100 NORTH SLOPE CONPUTATION DATE: 11/23/92 DATE OF SURVEY: 111792 JOB NUHBER: AK-HW-20086 KELLY BUSHING ELEV. = 69.30 OPERATOR: BP EXPLORATION FT, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL HEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST HD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -69.30 .00 N .00 E 69 69.30 .00 .00 N .00 E 169 169.30 100.00 .13 S .52 E 269 269,30 200.00 .30 S 1.19 E 369 369.30 300.00 .43 S 1,88 E .00 .00 .00 .00 .00 .00 .00 .01 .00 469 469,30 400,00 ,53 S 2,48 E 569 569,30 500,00 ,43 S 2,63 E 669 669,30 600,00 ,17 N 3,06 E 769 769,30 700,00 1,64 N 4,30 E 869 869.30 800.00 4,23 N 6,67 E .01 .00 .01 .00 .01 .00 .04 .02 .10 .07 969 969,30 900,00 8,12 N 10,32 E 1069 1069,30 1000,00 13,14 N 15,53 E 1170 1169,30 1100,00 19,36 N 20,91 E 1270 1269,30 1200,00 26,14 N 26,40 E 1370 1369,30 1300,00 33,69 N 32,38 E ,25 .14 ,51 .26 ,85 .34 1 ,23 ,38 1 ,69 ,46 1471 1469,30 1400,00 40,69 N 38,97 E 1571 1569,30 1500,00 48,61 N 45,20 E 1672 1669,30 1600,00 57,71 N 50,80 E 1773 1769,30 1700,00 67,81 N 52,87 E 1873 1869.30 1800,00 76,12 N 54,05 E 2,15 ,46 2,67 ,51 3,24 ,57 3,77 ,53 4.14 ,37 1973 1969,30 1900,00 82,48 N 54,44 E 2073 2069,30 2000,00 87,08 N 53,39 E 2173 2169,30 2100,00 91,68 N 52,33 E 2273 2269,30 2200.00 95,74 N 51,07 E 2374' 2369,30 2300,00 99,73 N 49,78 E 4,35 ,21 4,46 ,11 4,57 ,11 4,66 ,09 4,75 ,09 2474 2469,30 2400,0'0 103,56 N 48,63 E 2574 2569,30 2500,00 106,50 N 48,26 E 2674 2669,30 2600,00 109,45 N 47,88 E 2774 2769,30 2700,00 112,22 N 47,47 E 2874 2869.30 2800,00 114,62 N 47.01 E 4.83 .08 4.88 .04 4.92 .04 4.96 .04 4.99 .03 2974 2969,30 2900,00 117,02 N 46,54 E 3074 3069,30 3000,00 119,.24 N 46,02 E 3174 3169,30 3100,00 120,35 N 45,17 E 3274 3269,30 3200,00 121,45 N 44,32 E 3374 3369,30 3300.00. 122,56 N 43.47 E 5.02 .03 5,05 ,03 5,O6 .01 5.O7 .01 5,07 ,01 ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 PRUDHOE BAY DRILLING PBU/S-36I 500292230100 NORTH SLOPE CONPUTATION DATE: 11/23/92 DATE OF SURVEY' 111792 JOB NUHBER: AK-MW-20086 KELLY BUSHING ELEV. = 69.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1OO FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST HD-TVD VERTICAL DIFFERENCE CORRECTION 3474 3469.30 3574 3569.30 3674 3669,3O 3774 3769,30 3874 3869.30 3400.00 3500.00 3600.00 3700.00 3800.00 123.17 N 42.82 E 123.77 N 42.18 E 124.36 N 41.54 E 124.45 N 40.99 E 124.41 N 40,47 E 5.08 .00 5.O8 .00 5.09 .00 5.O9 .00 5.09 ,00 3974 3969,3O 4074 4069,30 4174 4169,30 4274 4269.30 4374 4369.30 3900 4000 4100 4200 4300 .00 .00 .00 .00 .00 124.38 N 39.95 E 124.15 N 39.73 E 123.80 N 39.70 E 123.45 N 39.67 E 123.10 N 39.66 E 5,09 .00 5,09 .00 5,09 .00 5.09 ,00 5.O9 .00 4474 4469.30 4574 4569.30 4674 4669.30 4774 4769.30 4874 4869.30 4400 4500 4600 4700 4800 .00 .00 .00 .00 .00 122.44 N 40.82 E 121.77 N 42.04 E 121.44 N 41.98 E 121.95 N 38.72 E 123.36 N 31.79 E 5.10 .01 5.11 .01 5.12 .01 5.18 ,06 5.44 .26 4975 4969.30 5076 5069.30 5177 5169.30 5278 5269.3O 5379 5369.30 4900 5000 5100 52OO 5300 .00 .00 .00 .00 .00 125.59 N 21.52 E 128.19 N 9.20 E 131.00 N 4.38 W 135.12 N 19.40 W 140.75 N 36.08 W 5.99 .55 6.79 .80 7.74 .96 8.97 1.22 10.51 1,54 5481 5469.30 5585 5569.30 5689 5669.30 5795 5769.30 5904' 5869.30 54OO 5500 56OO 5700 5800 .00 .00 .00 .00 .00 148.70 N 55,43 159.55 N 78,06 174.23 N 103.64 192.51 N 134,15 213.86 N 172.00 12.68 2.17 15.79 3.11 20.06 4.27 26.22 6.16 35.27 9.06 6016 5969.30 6131 6069.3O 6249 6169.30 6367 6269,30 6488 6369,30 59O0 6000 6100 6200 6300 .00 .00 .00 .00 .00 237.09 N 217.31 261.23 N 269,08 288.70 N 323.34 321.94 N ,377,27 358.51 N 434.45 47.51 12,24 62.69 15.18 79.74 17.06 98.12 18.38 118.99 20.86 6612 6469.30 6745 6569.30 ,6887 6669.30 7037 6769.30 7193 6869,30 6400.00 6500.00 6600.00 6700,00 6800,00. 397.94 N 497.27 W 143.52 24.53 441.01 N 572.61 W 175.97 32.45 492,37 N 659,04 W 217,80 41.83 547.76 N 757.02 W 268,40 50,60 598.41 N 865.24 W 324.22 55.83 ~'~ ..... ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/S-36I 500292230100 NORTH SLOPE COHPUTATION DATE: 11/23/92 DATE OF SURVEY' 111792 JOB NUHBER' AK-HW-20086 KELLY BUSHING ELEV. = 69.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA HEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES. NORTH/SOUTH EAST/WEST HD-TVD VERTICAL DIFFERENCE CORRECTION 7342 6969.30 6900.00 643.12 N 965.77 W 372.92 48.70 7483 7069.30 7000.00 681.52 N 1058.31 W '414.49 41,57 7621 7169.30 7100.00 716.27 N 1146,26 W 452.15 37.66 7755 7269,30 7200.00 747.16 N 1229.53 W 485.92 33.76 7885 7369.30 7300.00 773,90 N 1308,12 W 515.89 29.97 8015 7469.30 7400.00 805.01 N 1386.36 W 546.61 30.73 8146 7569.30 7500.00 835.06 N 1465,02 W 577.35 30,73 8277 7669.30 7600.00 864.27 N 1544.00 W 608,08 30.73 8407 7769.30 7700.00 896.64 N 1620,33 W 637,99 29.91 8537 7869.30 7800.00 929.49 N 1696,25 W 667.77 29.78 8668 7969.30 7900.00 961.32 N 1775,22 W 699.11 31.34 8799 8069.30 8000.00 993.04 N 1854.52 W 730.62 31.51 8930 8169,30 8100.00 1023.28 N 1933.16 W 761.38 30,76 9062 8269.30 8200.00 1052.31 N 2013.29 W 792.78 31.39 9194 8369,30 8300.00 1078,98 N 2096.56 W 825.62 32.84 9328 8469.30 8400.00 1107.53 N 2180.61 W 859.34 33.72 9462 8569.30 8500.00 1140,64 N 2263,17 W 893.19 33.85 9594 8669,30 8600.00 1175,98 N 2342.60 W 925.70 32.51 9652 8712.71 8643.41 1191,71 N 2376.02 W 939.29 13.59 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT ND (FROH HINIHUH CURVATURE) POINTS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 .3 DATE: 12/16/92 T# 84186 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 12/12/92 #1 B-29~-I~ PRODUCTION LOG 12/12/92 #1 f G-14~/a~" PRODUCTION LOG 12/11/92 #1 S-38I SBT/~ ~/~C 12/12/92 #1 S-38I~1~ PFC6~A,~ f.~) 12/13/92 10674.00-11050.00 ATLAS 5 " 9124.00- 9325.00 ATLAS 5 " 9200.00- 9593.00 ATLAS 5 " 8050.00- 9571.00 ATLAS 5 " 9250.00- 9450.00 ATLAS 5 " Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/16/92 T# 84167 BP/PBU OH TAPES Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) -36I OH/BHC 7968.00-10320.50 FIN 11/20/92 %1 1600BPI 9195->TP% FLD 11/20/92 #1 1600BPI 9!96->TP# If you have any 564-4004. SCH REF%92697 SCH REF#92697 Information Control Well Records CEiVED BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/15/92 T# 84161 BP/ PBU OH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 38I DIL ?HASOR/Yr~/~.12/10/92 #1 9224.00- 9647.00 SCH 381 BHC/~c/~ 12/10/92 #1 9224.00- 9617.00 SCH 1/2" 2/5" 2/5" Information Control Well Records Ai~ka 0il & Gas Cons. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/01/92 T# 84115 BP/ PBU OH/CH LOGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at A-23 ~Z'~'~PRODUCTION LOG 11 B- 07 ~,?",2~/ PRODUCTION LOG 11 C-38~ ~ PRODUCTION LOG 11 M-32 ~Z'-),~ CCL/PERF ~' 11 R-25 ~Z-~ CCL/PERF ~ 11 R-30 CCL~ERF) ~ 11 [S-07A BHC / 11 %' ~S-07A CNL / 11 ~q~/S-0UA DLL / 11 ~S-07A SS T~ / 11 -36I PFC ~(¢~ 11 x-0 CCL /18/92 #1 /20/92 #1 /18/92 #1 /21/92 #1 /23/92 #1 /20/92 #1 /23/92 #1 /23/92 #1 /23/92 #1 /23/92 #1 /23/92 #1 /22/92 #1 /22/92 #1 /21/92 #1 below. If you have any (907) 564-4004. 11100.00-11516.00 ATLAS 5 " 11500.00-11870.00 ATLAS 5 " 10700.00-11130.00 ATLAS 5 " 8800.00- 9250.00 ATLAS 5 " 9800.00-10858.00 ATLAS 5 " 11250.00-11522.00 ATLAS 5 " 10800.00-11453.00 ATLAS 5 " 10600.00-11421.00 ATLAS 2/5" 10600.00-11363.00 ATLAS 2/5" 10600.00-11390.00 ATLAS 2/5" 10600.00-11421.00 ATLAS 1/2" 9250.00-10212.00 ATLAS 5 " 9250.00-10000.00 ATLAS 5 " 11412.00-11830.00 ATLAS 5 " Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/25/92 T# 84138 BP OH LOGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at I S-36I S-36I S-36I S-36I RFT '/ 11/20/92 #1 BHCS ~ 11/20/92 #1 PHASOR INDUCTION SFL GR / 11/20/92 2/5" SS TVD / 11/20/92 #1 below. If you have any (907) 564-4004. 9755.00-10203.00 SCH 5 " 9718.00-10264.00 SCH 2/5" #1 8000.00-10294.00 SCH 9718.00-10294.00 SCH 1/2" Information Control Well Records ANNULAR INJECTION DATA ENTRY SCREEN Asset .WO,~ ......................................... Legal Desc.;/..6.~6.'.SbIJ.,...1.S&~.:E.W.L,..~.e=...~5".T..12,b[,...B.12,F_ ..................... Research Rig Name ..................................................... · ....................................................................................................................... Carz~,cted..=o,~¥..=P.,~..t~..&.QGC.G..3.:.;I.Z:,gZ ............... Inj Well Name .~.~3.6 ......................................... Permit Start ....... ;:[./..:t./.~9.;~ ...... Permit End.....l.2~.3..l.J..9.3.... Sur Csg Dep ........................... · ............................................................. Cumulative Data Daily Data 955 S-35i 570 1992 Year End Summary January 10 th_r_ou_gh JanuarY_ 15, 1993 BP EXPLORATION ' BP Exploration (Alaska) Inc. .. , , ! 900 East Benson Boulevard " P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 -. DATE: 02/09/93 T# 84295 .. BP/PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions,;'"please contact BP Well Records at (907) 564-4004. .. /.B--32 q¥W -'~;J? PRODUCTION LOG · M-19A ~- ~J_..l PFC /. M_19A~'~. _36%~? CCh /-37q~/ PFC cch/sm 01/31/93 #1 . 01/30/93 #1 01/29/93 #1 02/04/93 #1 02/04/93 #1 10100.00-10744.00 ATLAS 5 " 9900.00-10450.00 ATLAS 5 " 8400.00-10531.00 ATLAS 5 " 9380.00-10200.00 ATLAS 5 " 8850.00- 9675.00 ATLAS 5 " Information Control Well Records ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 5, 1992 Bill Kirton Workover Engineer Supervisor BP Exploration P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit S-36i BP Exploration Permit No: 92-116 Sur. Loc. 1646'SNL, 1888'EWL, Sec. 35, T12N, R12E, UM~ Btmhole Loc. 177'SNL, 788'WEL, Sec. 34, T12N, R12E, UM Dear Mr. Kirton: Enclosed is the approved application' for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-lllb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []J Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 67.8'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool p, O. Box 196612. Anchorage. Alaska 99519-6612 ADL 28258 4. Location of well at surface 7. Unit or property Name 11. Type Bond(s,~,, 20 AAC 25.025) 1646' SNL, 1888' EWL, SEC. 35, T12N, R12E Prudhoe Ba)/ Unit At top of productive interval 8. Well number Number 350' SNL, 700' WEL, SEC. 34, T12N, R12E S-36i (41-34-12-12) 2S100502650-277 At total depth 9. Approximate spud date Amount 177' SNL, 788' WEL, SEC. 34, T12N, R 12E 11/6/92 $200,000. O0 '12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(M~)andTVD) property line ADL 28257-788'feet S-11-34' @ 50' MD feet 2560 10285' MD/9207' TV•feet 16. To be completed for deviated wells i17. Anticipated pressure (s,,~ 20 AAC 25.03S (e)(2)) Kickoff depth ,~5oofeet Maximum hole angle ,~o.z 0 iMaximurn surface 3330P~ig At total depth (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) $0' 20' 91.5~ H-40 Weld 80' 32' 32' 110' 110' 450 # Poleset 16" 13-3/8" 68# L-80 BTC 2874' 31' 31' 2905' 2900' 1116 sx AS 111/600 sx CS III/11 12-1/4" 9-5/8" 47# L-80 NSCC 9722' 30' 30' 9752' 8804' 1027 sx Class "G" 8-1/2" 7" 26# L-80 NSCC 683' 9602' 8690' 10285' 9207' 150 sx Class "G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural . Conductor RFEEIV P Surface Intermediate Production OC~}~ ~ r~ Liner A[a:sk8 0ii & Gas CoP, s. Perforation depth: measured AllC~ora~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program~ Drilling fluid procjram [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirementsl-] 21. I hereby certify that the foregoing is true and correct to the b~st of my knowledge Signed '~ Title Wockever Engineer Supervisor Commission Use Only Permit Number IAPI number. . IApproval date ~ JSee' cover letter ¢2_ is 0- o o I .,/,/,.--,....,~-- -. ~' ~---Jfor other requirements Conditions of approval Samples required [] Yes ,,~]'No Mud log required. []Yes~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; J~5M; •1OM; 1'-115M; Other: ORIGINAL SIGNED BY' by order of / Approved by RUSSELLA, DOUGLASS Commissioner ~ne commission Date / "',.~/'"' Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Well: S-36 Injector [41-34-12-12] PBU LOCATION: S u rface: Target: T.D.: 1646' FNL, 1888' FWL, Sec. 35, T12N, R12E 350 FNL, 700' FEL, Sec. 34, T12N, R12E 177' FNL, 788' FEL, Sec. 34, T12N, R12E ESTIMATED START: OPR. DAYS TO COMPLETE: CONT~T~: NOV 6, 1992 21 (17 days drilling, 4 days completion) Nabors 28E MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 40.7 deg/N64.8W/4500'/2..0/1377' Estimated Ground level elevation is 35.8' AMSL. KB to ground level elevation is 32'. Item TVD(BKB) MD{BKB) Mud Wt. 20" CONDUCTOR 8 0 8 0 8.5 13-3/8" SHOE 2900 2905 9.1 TOP UGNU SANDS 3 669 3 6 74 9.1 SEABEE 5244 5257 9.8 KUPARUK 6694 6971 10.2-10.5 9-5/8" SHOE 8804 9752 SAG RIVER SANDSTONE 8 804 9 75 2 9.0 - 9.5 TOP SADLEROCHIT 8 93 8 992 9 9.0 - 9.5 TARGET 8986 9992 9.0-9.5 TOTAL DEPTH 920 7 1 0285 9.0 - 9.5 CASING PROGRAM: Hole Csg Wt Grade Conn Length TOp 30" 20" 91.5# H-40 WELD 80 32 16" 13-3/8" 68# L-80 BTC 2874 31 12-1/4" 9-5/8" 47# L-80 NSOC 9722 30 8-1/2" 7" 26# L-80 N93C 683 9602 Btm 110 29O5 9752 1O285 COMPLETION: Tubing: 5- 1/2" GLMs: None Packer: Baker 1 7# L-80 LTC-M 9523 29 9-5/8" x 5-1/2" Baker set at 9552' or +/- 50' above TOL 9552 LOGGING PROGRAM: Open H01e- 9-7/8" Hole: None S-36 Conventional October 26, 1992 17:45 Ala, sk~.~ 0ii & ua.,, 0o~s, uo[r~o,~ssio~' Anchorage Cased Hole 6-3/4" Hole: DIL/CNL/GR/SP/SDT, Optional: LDT/GR, RFT CBT/CET IN 7" AND 9-5/8" before running tubing No gyro is planned. S-36 Conventional October 26, 1992 17:45 PROPOSED DRILLING AND COMPLETION PROGRAM S-36 i Procedure 10, 11. 12. 1. MIRU drilling rig. N/U diverter and function test same. 2. Drill 16" hole to surface casing point. Run and cement surface casing. function test same to 5000 psi. 3. PU 12-1/4" BHA and RIH. Test casing to 3500 psi for 30 minutes. perform leak off test. 4. Drill intermediate hole to intermediate casing point. 5. MU and run 9-5/8 casing string and cement as per well piano mud. 6. RIH and drill 8-1/2" hole through reservoir to TDo 7. RU and run e-line logs. 8. MU 7" liner on'5" DP. RIH to TD. Cement same. excess cement from wellbore. POOH. 9. MU casing scraper & clean out 7" liner. RU e-line and run cement bond Icg through liner and bottom of 9-5/8" csg. Run 5-1/2", L-80 and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 3500 psi. NU tree and test to 5000 psi. Release drilling rig. ° Anticipated BHP: 3600 psi @ 8800' TVD SS o Maximum Anticipated Surface Pressure: 2800 psi o Planned Completion Fluid: 8.6 ppg filtered sea water The drilling fluid-program and surface system will conform to the regulations set forth in 20AAC25.003. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). Based on previous logs on S-361, no potential productive zones are anticipated above 3674' TVD (Ugnu). Notes: a. b. d. No potential hazardous levels of H2S are anticipated in this well. Nipple up BOPE and Drill 10' of new hole and Bump cementing plug with Set liner hanger and packer. Circulate S-36 Conventional Injector Drilling Problems & Concerns: It was recently determined that the liner cement jobs on R-31, R-31, and R-25 exhibit channeling and/or poor cement bond log results. Each will likely require CTU squeezes. The importance of liner (and casing) reciprocation and cement displacement rate cannot be over emphasized. Some new wording to this effect has been added to the cementing steps for the surface, intermediate, and liner procedures. If there are operational factors being overlooked by town, please let us know. A draft copy of the S pad data sheet has been delivered to 28E. A review of drilling problems has been completed and are described as follows: Bridges in surface hole have occured at 500' and 2000'-2200'. Tight hole and swabbing have been noted. Hole washouts and the related high volume of gravel etc have caused cuttings handling problems. The Tertiary/Cretaceous injection interval (3876' - 5600' tvd) is overpressured by +/-125 psi. A mud weight of 9.5 to 9.7 ppg should be used through this interval to prevent salt water incursions. S-33 experienced gas cut mud as shallow as 3841' md/tvd on 10/9/92. The mud weight was cut from 9.6 to 8.9 ppg. No flow was experienced. The mud weight was raised to 9.9 ppg and no additional gas was noted. S~3 had oil shows at +/-4000' tvd and 10.1 ppg mud was used to drill this interval. S-3 also experienced gas cut mud in the Kuparuk interval(6700' - 6800' tvd) and 10.5 ppg mud was used. Weight up to 10.2 ppg minimum before drilling Kuparuk interval. Tight hole problems are common in the Jurassic shales starting below the Kuparuk. Mud weights are typically up to 9.9 ppg or higher as required to control the Kuparuk. Mud fluid loss (less than 6 cc) help to stabilize shales. The 9-5/8" casing must be centralized through the Kuparuk to maximize isolation. The Sag has been accidentally penetrated with 9.9 ppg mud weights with no problem. The possibility of lost circulation does exist. S-15 set intermediate casing with 60' of shale open above the Sag. This hole interval was lost while attempting to drill out with 9.0 ppg mud. There should be no problem if the casing point (Sag River) is properly chosen. The Sag is normally drilled with 9.0-9.5 ppg mud. Lost circulation has been noted, independent of mud weight.. The Shublik drills slowly and may be highly fractured. High torque and differential sticking are common. The mud weight should be kept at 9.0-9.5 to help minimize the potential for lost circulation. The Sadlerochit is normally drilled without trouble. ANNULAR INJECTION The S-37 and S-33 surface annulus is available for injection at present. Fluids can also be injected at the central CC-2 injection facility, AOGCC has informed PB Drilling that only associated fluids from drilling operations can be pumped down the surface x intermediate ~ ~ ~ ~. ~,%~ E D S-36 Conventional October26, 1992 18:13 Page 7 annulus-ie: completion fluids cannot be pumped. CUTTINGS DISPOSAL Plan to haul all cuttings and surface gravel by super sucker to ball mill at 0C-2. Do not RU cuttings handling unit at rig. FREEZE PROTECTION The 5-1/2" tubing along with the 5-1/2" annulus will be freeze protected by u-tubing diesel prior to setting packer. Dry crude needs to be injected down the 13-3/8" x 9-5/8" annulus after the well is completed. CLOSE APPROACHS & SHUT-INS Note near well proximity of other S pad wells. The PE°s have been requested to perform the following:. S-12-12A (producer) 38' at 1103 TVD. casing is set. S-11 (injector) 34' at 50 TVD. Close SSSV until drilling well surface casing is set. Notify WOA PE's when wells can be brought back on line. Close SSSV until drilling well surface S-36 Conventional October26, 1992 18:13 Page 8 MUD PROGRAM: Well S-36 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.5 Funnel Viscosity sec/qt ,,,300 <1 00 YP Ibs/100ft2 40 - 60 20 - 40 10 sec Gel Ibs/100ft2 30 - 60 15 - 20 10 min Gel Ibs/100ft2 60 - 80 20 - 30 pH - 8.5- 10 8.5- 10 APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to Top of Sag River Sandstone: LSND Gel/Water System Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel lbs/1 00ft2 10 min Gel Ibs/100ft2 APl Fluid Loss mi/30 min DH -- Hardness mg/I 9.5- 9.8 To to the LCU 10.2-10.5 thru Kuparuk to Casing Point 10- 15 5-10 10 - 20 <15 through Kuparuk (6800' tvd) <6 in Jurassic Shales below 6800' tvd 8.5 - 10.0 NC-no control MUD SPECIFICATIONS-PRODUCTION INTERVAL: Watered back mud system used in intermediate hole. Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel lbs/1 00ft2 10 min Gel Ibs/100ft2 APl Fluid loss mi/30 min pH -- Hardness m g/I t r 9.0-9.5 8-13 5-10 7- 15 6.0 - 8.0 (fluid loss lowered to below 6 cc prior to entering K-shales 8.0 - 9.0 < 4000 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at less than 3500 ppm chlorides. Prudhoe Prudhoe S-PAD S-36 I Bay Drlllin ]}ay I IS T -H l©©ljlj VERTICAL VIEW SCALE 1000 £t, / DIVISION REFERENCE: WELL HEAD O-- lDO0-- 300 5 ol1 0.00' ~ 0 MD TIE IN/RKO ELEVATION 69' SS 0.00° ~ 500 MD BEGIN NUDGE @ 2/100 4.00' ~ 700 MD 8,00' ~ 900 MD 10.00° ~ lO00 MD START DROP 6.00' ~ 1200 MD 2,00° ~ 1400 MD vv ~ 1500 MD END OF DROP 0.00° ~ 1949 MD BASE OF PERMAFROST 0,00' @ 290~ MD 13 3/8' CASING PT, 0,00' ~ 3674 MD UGNU ZONE 4 ,362 ~9~ 0.00' e 4500 MD KOP @ 2/100 4.00' @ 4700 MD 8,00' @ 4900 MD 12,00' e 5100 MD 15,16' @ 5258 MD TaP OF SEABEE 1~,oo. ~ 5400 MD 22,00' ~ 5600 .D 26,00. ~ 5800 Ms 30,00' ~ 6000 MD 34,00' ~ 6200 MD 38.00- ~ 6~00 M: 40 66. · ~ 6533 MD END ~F BUILD HF1RIZE]NTAL VIF-W (TRUE NORTH) SCALE 500 Fds, / DIVISI REFERENCE', WELL HEAD MD ioass,i~ Nomth 1377.72 West 2763,23 2000 150 lO 500-- 500 40.66° e 6971 MD KUPARUK/PUT RIVER 40.66' ~ 7037 MD IKRU/LCU 8OO 9094 9P08 3088 500 I I I 500 1500 2500 VERTICAL SECTION 4o.~' e 9~33 ~o TOP or SAG · ~ ~ o ~_~ 40'4640~.~666t ~ ~9~SI~ M~ ~SI~TZ~SING PT. 40.66' ~ 9993 MD TARGET ENTRY 40.66' ~ 10~31 MD Z3 40.66' ~ 10206 MD Z2C 40.66' ~ 10285 MD TOTAL DEPTH S500 PLANE: 296,50 ° Prudhoe Prudhoe S-PAD S-36 I Bay Drillin~ Say ©© Teave ( ~ in9 Cy [ i nolen - Nonmc~ ( P ~ane ReFeeence We[~ - S-36 I TV]]', 0 - 9208 £~, In,envoi, 50 ~, A[[ S inections Re[ ~o TPue Non th 300° 350 ° 0~ 500 450 400 350 300 O0 slO 50° sa5 s3( si s30xx 250°~_ s14 37p3 100° sO9 s~ S-33WP~ sO sll s13 200° 150' Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Calculated using the Minimum Curvature Method Normal Plane Method Date: Page 1 10/10/92 REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay S-PAD S-36 S-36I TVD, N/S and E/W are measured from the WELLHEAD Wet[path Slot Distance sO1 S-01 1133.59 sOlr S-O1R 1133.65 sO2 S-02 1021.44 sO3 S-03 910.31 sO4 S-04 802.36 sO5 S-05 142.84 sO6 S-06 583.94 sO7 S-07 473.22 sO8 S-08 363.10 sO9 S-09 252.57 slO S-lO 143.82 sll S-ll 34.01 s12 S-12 56.49 s12a S-12A 38.48 s13 S-13 129.73 s14 $-14 225.94 s15 S-15 1096.96 s16 S-16 1150.09 s17 S-17 1300.34 s17a $-17A 1300.14 s18 S-18 1352.58 s19 S-19 1056.44 s20 S-20 792.91 s21 S-21 876.83 s22 S-22 1095.00 s23 S-23 944.62 s24 S-24 685.78 s25 S-25 151.75 s26 S-26 468.88 s27 S-27 656.65 s28 S-28 619.37 s29 S-29 327.37 s30 S-30 507.59 s31 S-31 436.24 s32 S-32 177.49 S-33WP2 S-33 198.85 37p3 S-37 39.18 Closest Points Direction Ref MD Ref TVD 270.91 50.00 50.00 270.90 50.00 50.00 270.81 350.00 350.00 270.80 500.00 500.00 270.76 500.00 500.00 194.25 5368.30 5350.00 270.93 50.00 50.00 271.22 500.00 500.00 270.41 500.00 500.00 269.88 500.00 500.00 271.07 150.00 150.00 271.33 50.00 50.00 148.74 1204.55 1200.00 152.61 1103.81 1100.00 112.22 1455.07 1450.00 102.25 1755.07 1750.00 290.04 4505.07 4500.00 292.39 5212.39 5200.00 244.63 50.00 50.00 244.64 50.00 50.00 240.45 0.00 0.00 271.02 200.00 200.00 222.47 5526.92 5500.00 270.89 150.00 150.00 270.92 500.00 500.00 270.86 500.00 500.00 315.69 4455.07 4450.00 346.01 6781.45 6550.00 209.01 5634.49 5600.00 271.09 450.00 450.00 270.93 500.00 500.00 270.74 500.00 500.00 270.88 500.00 500.00 270.90 500.00 500.00 271.54 550.00 550.00 197.15 6264.55 6150.00 90.42 50.00 50.00 13-3/8" SURFACE CASING CEMENT PROGRAM - BJ Services CASING SIZE: 13-3/8", 68# CIRC. TEMP 38°F LEAD CEMENT TYPE: ASIII ADDITIVES: retarder WEIGHT: 12.2 ppg YIELD:1.92 ft3/sx MIX WATER: 10.5 gps APPROX #SACKS: 1116 THICKENING TIME: 4:30 hrs TAIL CEMENT TYPE: Cold Set III ADDITIVES: as required WEIGHT: 14.9 ppg YIELD: .96 ft3/sx MIX WATER: 3.89 gps. APPROX #SACKS: 350 THICKENING TIME: 4 hrs TOP JOB CEMENT TYPE: Cold Set II ADDITIVES: retarder WEIGHT: 14.9 ppg YIELD:0.96 ft3/sx MIX WATER: 3.89 gps APPROX #SACKS: 250 SPACER: 75 bbls fresh water ahead of lead slurry. CENTRALIZER PLACEMENT: 1. Run one(l) bow type centralizer per joint for the first 20 joints. 2. Place the centralizers in the middle of each joint with a stop collar. 3. Run two bow type centralizers inside the conductor pipe on stop collars. CEMENT VOLUME: 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 350 sx 3. Top job volume 250 sx. 9-5/8" INTERMEDIATE CASING CEMENT PROGRAM- BJ Services CIRC. TEMP: 130°F SPACER: 50 bbls Arco Spacer, weighted 1 ppg above mud current mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 2.0% A-2 + 0.5% Gel + 0.7% R-18 + 1 ghs FP-6L WEIGHT: 12.0 ppg YIELD: 2.40 ft3/sx MIX WATER: 14.2 gps APPROX #SACKS: 727 THICKENING TIME: 5.0 hrs TAIL CEMENT TYPE: CLASS G (batched mixed) ADDITIVES: 0.2% D46 + 0.4% B14 + 0.06% D800 for 3-4 hrs thickening time. WEIGHT: 15.Sppg YIELD: 1.15ft3/sx MIX WATER: 5.00 gps APPROX #SACKS: 300 THICKENING TIME: 4 hrs CENTRALIZER PLACEMENT: 1 Turbulator centralizer per joint on the bottom 500' of 9-5/8" casing ( 12 required ). 1 turbolator centralizer per joint from 200 above to 200 below the Kuparuk interval (6771' to 7237', 12 required ). One turbolator centralizer (7-3/4" x 9-3/8") on first two joints inside 10-3/4" surface casing shoe (2 required). OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-12 bpm. Batch mix tail cement - perform fluid loss test. Fluid loss should be 40 cc or less. CEMENT VOLUME: 1. Lead G neat slurry to 500'md above top of Ugnu with no excess. 2. Tail G slurry to 1000' md above casing point with no excess. 3. 80' md 9-5/8", 47# capacity for float joints. NOTE: The intermediate casing string should be isolated from the Cretaceous interval. 11! CEMENT CIRC. TEMP 140° F PRODUCTION LINER PROGRAM - BJ Services SPACER: 50 bbls preflush + 1% S-400 . CEMENT TYPE: CLASS G ADDITIVES: 0.8% BA-10 + 0.6% FL-32 + 0.2% CD-30 + 0.3% A-2 + 0.35% R-1 + 1 ghs FP-6L WEIGHT: 15.7 ppg YIELD:1.18 ft3/sx MIX WATER: 5.03 gps APPROX #SACKS: 150 THICKENING TIME: 4.5 hrs total Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/ cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 8-10 bpm. LINER CEMENT VOLUME: , . Open hole + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 7", 26# casing capacity below landing collar. 150' liner lap 200' of cement on top of the liner in the 9-5/8" casing. S-36 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) TJYS (#) 1069000 1300000 1556000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SIPRESSURE 1 4 3500 2548 Burst S.F. 1.35 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2900 1433 Collapse S.F. 1.58 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 2905 PBYS Tension S.F. 6.33 Mud Wt. 9.5 ppg TJYS 7.70 String Wt. (#) 168857 S-361 Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SFFP 3420 Burst S.F. 2.01 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 8800 0.1 3788 Collapse S.F. 1.25 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 9752 PBYS Tension S.F. 2.81 Mud Wt. 10.2 TJYS 3.00 String Wt. (#) 386888 S-361 Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST L-80 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 351 2 3420 2.06 Burst S.F. Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Gas Grad. TVD (FT) (psi/ft) Collapse Press 8800 0.1 3788 1.43 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 683 Mud Wt. String Wt. (#) 10.2 14990 Tension S.F. PBYS TJYS 40.29 44.50 TO FLARE CAVlEM UNIT I SCREEN CAVEM UN~ 2 CHOKE MANIFOLD TRIP TANK 170 BBL VOLUME TANK 137 BBL FILL LINE DISTI DFFCH TRAP 4 BBL 131BBL 81BBL DEGASSlNG TANK CI~ITRIFUG~ PIONEER Mt( 1 DEQA88ER DR~.CO 8EEFLOW TO PIT ITO DISTRIBUTION EQ. :VOLUME TANK 180 BBL WATER 87 BBL MUD HOPPERS & MIXING PUMP8 SUCTION 117 BBL SUCT~N 134 BBL DESlLTER NABORS TO STAND PIPE & KILL LINE MUD PUMPS NABORSDRI_LING LTD RIG No. 28E MUD SYSTEM SURFACE FAClL~E$ TOTAL ACTIVE SYSTEM: 800 BBL TOTALSURFACE CAPACITY : 970 BBL NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP UNE I RISER FLOWMNE I 10" B/U i VALVE I ,,I 10" BA!_!._ VALVE 1 I co"DUCTO" I ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE ~ VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT MNF_ THE SECOND VENT MNE VALVE CAN BE OPENED USING CONTROI.~ LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VAFE~NCE FROM 20AAC25.(G5. RESERVE PIT 10" VENT MNE 10" VENT UNE DlVER'rER UNES DISCHARGE 100 FT. FROM RIG IGNmON SOURCE. 2.42 10.93 4.50 4.82 1.51 3.07 2.13' 1.13 1.5 GROUND LEVEL NABORS 28E 13 5/8" 5,000 psi Stack r" RKB HYDRIL KR TC) RF Rlt i FLOI 13.18 PIPE RAM BLIND RAM MUD CROSS 5.58 8.06 L ! [, PIPE RAM MUD CROSS TBG SPOOL '~ASE FLG ~ / 12.58 I16.25 17.33 19.75 Stat, e: A~aska Borough: Well: S-3Gi Field: Prudhoe Bay St. Perm; 92-116 Date 1112/92 Engr: M. Minder S-36ICSG.XLS Casing Intervat interval S~e Boffom Top IA 13.375 2900 31 ZA 9.625 8804 32 SA 7 9207 8690 4A 0 0 0 5A 0 0 0 6A 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Descriptionescriptionescription Tension Length 2874 9722 683 0 0 0 0 0 0 0 Lbs Grade Thread Lbs 68 L-80 BTC 0 47 L-80 NSCC 0 26 L-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Wieght Gradient ppg psi/ff 1B 9. I 0.478 2B 10.2 0.580 9B 9.5 0.494 4B 0.,0 0.000 o.o o.0oo 6E) 0.0 0.000 719 0.0 0.000 813 0.0 0.000 9B 0.0 0.000 ! OE~ O. 0 O. 000 Maximum Minim,Jm Pressure Yield psi psi BDF 3830 3450 1.0 .-.89:90 6870 2.1 3930 7240 2.2 0 0 #DIVIO! 0 0 8DIVlO! 0 0 ~DIVIO~ 0 0 0 0 ~DIVIOi Tension Strength ~Lbs K/Lbs 1C 195.432 1069 2C 456.934 1086 3C ! 7,758 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 5.47 604 34.01 0 #DIV/0~ 0 #DIV/0! 0 #DIV/0! 0 #DIV./0! 0 #DiV/0! 0 #DIV/0~ 0 #DIVI~! Collapse Collapse Pr-Mot-Psi Resist. CDF 1372 1950 1.421 4670 4750 1.01 7 4548 5410 1.189 0 0 #DIVlO! 0 0 #DIVI0! 0 0 #DIV/O! 0 0 #DIVlO! 0 0 #DIVlO! 0 0 #DIVIO! 0 0 #DN~t! ITEM (1) Fee (2) Loc APPROVE D/~TE / ru 8] ' [14 thru 22']: ** CHECK LIST FOR NEW WELL PERMITS ** Company / YES 1. Is permit fee attached ............................................... /~ .. 2. Is well to be located in a defined pool .............................. '~. 3. Is well located proper distance from property line ................... _L 4. is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. /~ .. 6. Is well to be deviated & is wellbore plat included ................... /~ 7. Is operator the only affected party .................................. ~ . . 8 Can permit be approved before 15-day wait 9. Does operator have a bond in force ................................... /~. 10. Is a conservation order needed ....................................... L 11. Is administrative approval needed .................................... E,, 12. Is lease nL~nber appropriate .......................................... ~. 13. Does well have a unique name & n~nber ................................ /~ 14. Is conductor string provided ......................................... /~,:~,~f 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. /~[ enough cement used to circulate on conductor & surface ............. A~?' 1 cement tie in surface & intermediate or production strings ...... ~ Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... ~.~ Is old well bore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. /~t,¢ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~?'~O,~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... 15. Wi l to 16. Is 17. Wi l 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (5) BOPE :~>:~ i [23 thru 28] Lease $ Well ~ /~Z?~ NO REHARKS (6) Other___~X~2~:thru 31'] (7) Contact [32 ] .~' .:.~...:.. ,t~:; :~ ..... (8) Addl .,,, , ..,,,,.~. geology' engineerinq' DWJ MTM,./~.~( RAD RPCg'./~_~ BEW, dDH/_LL~.~ rev 08/18/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... INITIAL GEOL UNIT ON/OFF POOL CLASS STATUSAREA SHORE 0 -t ZE Z ~0 (bm Z 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. I:, 5 e, - :) 2 o ,,, 22 3 O t - ¢': r) e D t h 0. % 0 i)...) o 7 'I C, 5 2} · l, '-. P A G ~: 42 ! 5. o(')0 · -999. 250 ~;:~;fS ?ar,¢ :/er1 f'Icatic,n [ i, st:it:,q 7 g. 6 t 7 !: ~.: F !4. b T E: ~( . ~, .... 2.6'9'1 2 5.4 6 ! 6,7 4 2 - t:., ! 24.504 7.562 ~4.177 '! I,, h. f:} T F. 't: t~ [) · D T E 4395.000 -999.250 1~2.520 4~;35 2,502 182.68! 4385,000 6,172 1n'3,237 4500,000 8.666 55 469 !80:809 4490 37.~13 175,455 4.675,000 2,5e0 I69,753 hole j.o:::s rt.'~ into casi, nq~. ., I~4.276 1132.~56 !156.],70 .11 - !:, f'.; C - 1. 9 a 2 ! 1. ~ 3 :t i0fi9.300 !.047,264 !062.943 1121,638 1070.309 !.I23,146 111~,600 i. 156,834 1152.134 1i~0.443 1!.34,1~8 !1.87.227 1t00.562 !146.~3! sh,~.~,t the Sa.d.,ler 10¸ 57 . 0 !¸.2 394. 000 43.903 141.578 2. 467 2,465 66,232 -7o. !,21.7 394.000 ,43,903 799"638 2,466 2.469 66,071 -6~.250 !.2!7 393.600 2!.508 829.~40 2.689 2.642 !.216 25,46! 847.154 6,747 6.585 2!.1R4 -59. 938 1.218 000 Oq6'~ 000 ' 0S61~ 000'8 969 '~ ,1..4, 1.5 $ Y!, 5 0 2.7 ! 5 7, n 16 17 394,000 22.2 ~ 4 I4:~.275 2 · 452 63.46 '! -4~0,000 1 .'232 394.000 22.:284 a04.873 2,455 2,~53 63.32~ -40.!.88 t.232 395.600 20 068 ~45:49~ 2.6~9 2.643 49.695 -30,063 ~,240 392.000 24.,052 6,748 6,564 lg,51~ -]2.500 1.258 ¢ e r t e r 1.298 !33.t91 99.~89 1 '~, 22..t !.76.695 1.312 5, ! 00 1.2. 590.902 40t., -52~, 594 6~,975 ~ 65. 953 -q9O, ] .4q2 -539.46! -.575.74, V 7 !. 5 4 ! 163.77~ PAGE 434,400 26,634 7,513 5,99;3 -7,875 302,400 86.033 !I44,617 ! 96 ' 062 8:0..it 82 4,~23 -18'375 333,600 76,032 36,135 34,044 2,147 -6,.75 7,600 2~6,485 11~7.399 !950,000 1950,000 -436'949 -26.1~5 1,386 '999. 250 46.34P 1 t5! .OgO !9%0.000 1950. 000 -436.029 -28.68a !...402 Or, ryes .an:~ !.oq ?~eaoer data :for open 't~c:.~.le 1. e:~s r~.~r'~ i.r~t.o casinO, ~.- ,: ~ ~ L~ .~ '1': t} W ~' { ~"~ ~:-:' ~ ........... ~ ..... t : , , · , , , , .., , :,. ~', ...... . . .~. ~ . .~. . ,.. ·.. v.~ . . }-~ ., - .~ · ; e .... 57. {? ~'7 0 2t 166.8!7 !66.537 !66.671 165.5!.6 · t t .......... i -~. i:i6!i~:$ .C.8(: ! .55,: ~!~. 1,0 !1, i!. 1! 1! !i¸ ., 3'.33 · ~ ~. ~.: ~.,~ 57 r:,~ 57.1~7 43.060 27,46 ~ 70.309 i 7.2 ::~ 9 '"-:' 6. q 'i 0 t: 0.2 5 q ? F: J.: .<.; C S G 4 4: b (?. 00 0 4:3 45.0 <) 0 ,4 ~..,. 9 5. () 4355. .-:,I 3 9 %. 00 C: 44.0~ o 4 2 75. o (:; !:J 4 !. 4 0.0 0 0 a. 0 ! 5.0 (> 0 ..¢ 2 3 0.00 () ,'al. 25. c~ 0 (., 4 15(:'. O(~C: .... T E ~ C ~ C ? v . ~ {'~ i:iT ~:: i;i. C S G F'! T [.'2 !)':. C o ¢, I, 63,706 162.567 161.429 !60.762 159,686 I58.823 I57,354 156.424 I. 5:5. 229 154.565 !, 53,372 151.9~5 tS1.3S8 150.535 !.50.276 2~ ! MICI OI:ILM Date~ .......... R~CEIV~:D~ P~aska 0{{ & Gas Cons. Comm~ss~o~ o i:::~ fie C t' S~'r~e~'.,.tic~i~t.to:,:'~ reeor.d RECEIVED Aia. ska OiJ & 5 C, End o~ set L, istinO o~ set 17 t~,:~.e 6age · 1 F.: ~.~ 0 $ e t Q t, v !> e f"' [..;i {~:{! ...... ~,~ ...... ~ ~,~ c 1 f: i ci:t't: i,, on record o~:)j t 2 - 4, 0 ' ! 0 o h j e c t 0