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e 0 pit) I q2.oggo Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] r4? 31 1 .q i7, Sent: Monday, March 12, 2012 9:02 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad SW Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); LeBaron, Michael J Subject: NOT OPERABLE: Producer S -07A (PTD #1920980) Confirmed Starting Head Leak, Well Secured With Downhole Plug All, Producer S -07A (PTD #1920980) was secured with kill fluid and a tubing tail plug on 3/6/2012 after being identified with a starting head leak. The well is reclassified as Not Operable. Plan forward: 1. WIE: Evaluate for composite wrap repair for starting head. 2. APE: Develop plan to evaluate TxIA communication Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) 'r {+ /ktitiED MAR 1 h Zola Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, February 07, 2012 12:10 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad SW Cc: Walker, Greg (D &C); Longden, Kaity; Clingingsmith, Mike J; Murphy, Gerald L Subject: UNDER EVALUATION: Producer S -07A (PTD #1920980) Sustaine• 'sing pressure on OA over MOASP All, Producer S -07A (PTD #1920980) was found to ave sustained casing pressure on the OA above MOASP. The 1 tubing /IA/OA were equal to SSV/1950/1200 t i on 02/05/2012. The sudden OA pressurization event is correlated to a well shut in. The well is reclassified as U ter Evaluation for further diagnostics. The plan forward is: 1. Operations: Shut well in 2. Wellhead: Test wellhead , -als on IC hanger, Cycle lock down screws 3. Operations: Put well o •roduction for —3 days to allow thermal stabilization, then shut in 4. Downhole Diagnost Perform OA Repressurization test as soon as well is shut in 5. Well Integrity Engineer: Evaluate for Seal -Tite IC hanger treatment // 1 • • 1 S Cr7A Prb (q z - OW, Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] Z�/1v Sent: Tuesday, February 07, 2012 12:10 PMT To: Regg, James B (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad SW Cc: Walker, Greg (D &C); Longden, Kaity; Clingingsmith, Mike J; Murphy, Gerald L Subject: UNDER EVALUATION: Producer S -07A (PTD #1920980) Sustained casing pressure on OA over MOASP Attachments: S -07A TIO 02- 07- 12.doc; S- 07A.pdf All, • Producer S -07A (PTD #1920980) was found to have sustained casing pressure on the OA above MOASP. The tubing /IA/OA were equal to SSV/1950/1200 psi on 02/05/2012. The sudden OA pressurization event is correlated to a well shut in. The well is reclassified aster Evaluation for further diagnostics. The plan forward is: 7l 1. Operations: Shut well in "' 'r) -Fr ��� 2. Wellhead: Test wellhead seals on IC hanger, Cycle lock down screws 3. Operations: Put well on production for —3 days to allow thermal stabilization, then shut in 4. Downhole Diagnostics: Perform OA Repressurization test as soon as well is shut in 5. Well Integrity Engineer: Evaluate for Seal -Tite IC hanger treatment A TIO plot and wellhead schematic are attached for reference: 04 C «S -07A TIO 02- 07- 12.doc» «S- 07A.pdf» l' .- `P Thank you, dli ce Mehreen Vazir (iltc;rnale: (Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com 1 PBU S-07A PTD #1920980 2/7/2012 TIO Pressures Plot Well: S-07 4.000 411 3,000 - Tbg - IA 2:000 — OA 00A —4— 000A 11111-111-111-11-111H1H-11-1H-000*-111-111-111-1,111HIFIHIM ••• On ism 1 ..000 I r d\ A 11/19/11 121031 1 12/17/11 12/31/11 01/14/12 01/28/12 TREE = 4" FMC I WELLHEAD = FMC SAFETY 11: * * *13 CR TBG AND LNR * ** ACTUATOR = AXELSON S -07A KB. ELEV = 67.27' BF. ELEV = 38.75' - KOP = 1700' Max Angle = 46 @ 7900' 2 119' -14 -1/2" OTIS SSSV NIP, ID = 3.813" I Datum MD = 11066' J 2390' J--17 -5/8" SB PKR, ID = 6.875" I Datum - Rid' =' 8800' SS (TOP OF 7 -5/8" CSG I I 2400' I 2632' H DV PKR I GAS LIFT MANDRELS 13 -3/8" GSG, 72 #, L -80, ID = 12.347" H 2729' • ST MD TVD DEV TYPE VLV LATCH PORT DATE P �J39P5i 5 3183 2938 40 OTIS BK 4 5715 4743 44 OTIS BK 3 7405 5939 45 OTIS BK 2 8437 6662 44 OTIS BK Minimum ID = 3.725" @ 10426' 1 9161 7188 42 OTIS BK 4 -1/2" SWN NIPPLE I7 -5/8" TIEBACK CSG, 29.04# HT -95 STL H 9224' I 9219' j- 7" BAKER TIEBACK, SEAL ASSY TOP OF 7" 13 CR TBG H 9227' I-- XO TO 7 -5/8" CSG TIEBACK 9 -5/8" CSG, 47 #, L -80, ID = 8.681" I-{ 9470' I WINDOW 9470' mayr - .,q 'TOP OF CEMENT H 9470' 1•{ f 1 • 1�1 • PERFORATION SUMMARY 11 10353' H4 -1/2" PARKER SWS NIP, ID = 3.813" I REF LOG: BHCA /GR ON 11/23/92 (TIE -IN LOG) 1 • 1 1 ANGLE AT TOP PERF: 23 @ 10846' 11 1111 N.* 10379' I--I 7" BAKER SABL -3 PKR, ID = 3.84" I Note: Refer to Production DB for historical perf data 1 1 1 1 11 � 1 111111 SIZE SPF INTERVAL Opn /Sqz DATE 1 1 1 111 1 1 1 11 , 10409' 1- 14 -1/2" PARKER SWS NIP, ID = 3.813" I 3 -3/8" 4 10846 - 10966 0 12/10/92 11111 11# 111/11111 1 1 • 3 -3/8" 10 10846 - 10876 REPERF 04/19/93 1111111111 10426' H4 -1/2" PARKER SWN NIP, ID = 3.725" I 1 1 1 • 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 A% 1 1 1 1 1 4 04 1 1 44-444 1 i 1 ii -4i i 10448' 1-14 -1/2" WLEG, ID = 3.958" I I EZSVI-1 9710' I 10420' H ELMD TT LOGGED 08/10/93 I 14-1/2" TBG, 12.6 #, 13CR, .01522 bpf, ID = 3.958" H 10448' I PBTD H 11360' I x\,,,11\1► \► • 7" TBG, 26 #, 13CR, .0383 bpf, ID = 6.276 H 11445 1 DATE REV BY COMMENTS ' DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/82 ORIGINAL COMPLETION WELL: S -07A 12/01/92 LCLE SIDETRACK COM PLETION PERMIT No: 1920980 08/11/93 LAST WORKIVER API No: 50- 029 - 20829 -01 09/23/05 EZL /TLH WAIVER SFTY NOTE DELETED Sec.35, T12N, T12E 06/23/06 RCT /PJC PULL PXN PLUG @ 10426' BP Exploration (Alaska) • BP Expioration (Ataska) Inc. Attn: Well Integrity 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 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, °~a-°g~ ~-°%`~" 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, k. . ~'~~`~i~~~`~~ ;,i ~j ~.. ~; ~~'' ~ ~~ <{ ` E ~ ~ ~, ~ ~ . ~ ~ ~ ~ JUL A 1 2009 ~I~~~a pi~ ~ C~~ ~Ar~s. Commi~Si~~ Anch~ra~~ Torin Roschinger BPXA, Well Integrity Coordinator . • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Seatant Top-off Report of Sundry Operations (10-404) S-pad ~ omR 6/25/2009 Well Name PTD S Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant data ft bbls ft na al 5-01 B 1952020 0.25 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 13.25 NA 1325 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 7951890 0 NA 0 NA 0.9 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 07A 1920980 0 NA 0 NA 0.9 5/26I2009 S-O88 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-i0A 191t230 0.5 NA 0.5 NA 3.a 5/31I2009 5-118 1990530 025 NA 025 NA 1.7 5/27I2009 S-72A 1851930 025 NA 025 NA 7] 6/1/2009 S-t3 1821350 8 NA 8 NA 55.3 6/1/2009 5-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 202W70 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-19 1861160 0.75 NA 0.75 NA 22 5/19l2009 S-20A 2010450 025 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 S-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 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-286 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 1960120 0 NA 0 NA 0.85 5/27/2009 S-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 5-32 1901490 0.5 NA 0.5 NA 3.a 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0. NA 0 NA .85in 5/31/2009 S36 1921160 0.75 NA 0.75 NA 425 5/27/2009 S-37 1920990 725 NA 125 NA 11.9 5/27/2009 S38 1921270 025 NA 0.25 NA 102 5/27/2009 S-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 S42 1960540 0 NA 0 NA 0.9 5/30/2009 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-~00 2000780 2 NA 2 NA 21.3 5/29/2009 S-101 2001150 125 NA 125 NA 11.9 5/29/2009 S-102L1 2037560 125 NA 725 NA 11.1 5/31/2009 5-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 5-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-t06 2010120 1625 NA 1625 NA 774.3 6/2/2009 S-107 2011130 225 NA 225 NA 28.9 5/18/2009 5-708 2017000 3.5 NA 3.5 NA a0 5/30/2009 5-109 2022450 2 NA 2 NA 21.3 5/30/2009 S-110 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 5-17~ 2050510 2 NA 2 NA 79.6 5/30/2009 S-t72 2021350 0 NA 0 NA 0.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 5-114A 2021980 125 NA 125 NA 102 5/30/2009 S-7t5 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-118 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 S-t77 2030120 t.5 NA 1.5 NA 15.3 5/29/2009 S-~~e 2032000 5 NA 5 NA 76.5 5/28/2009 S-17s 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 6~2 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 7.5 NA 20.4 5/26/2009 S-12a 2061360 1.75 NA 1.75 NA 11.9 5/26/2009 S-125 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 125 NA 15.3 6/1/2009 5-200 1972390 1.25 NA 125 NA t4.5 5/28/2009 5-207 2001840 0 NA 0 NA 0.&5 6/19/2009 S-273A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 187 6/1/2009 S-216 2001970 4.75 NA 4.75 NA 57 5/29/2009 5-217 2070950 025 NA 025 NA 1.7 6/1/2009 Sd00 2070740 2 NA 2 NA 9.4 5/28/2009 5-001 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 a STATE OF ALASKA a AlA~ Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED DEe 1 6 20D5 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations [] Perforate New Pool 0 Perforate 0 4. Current Well Class: Development M Stratigraphic D 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 67.3 KB 8. Property Designation: ADL-028260 11. Present Well Condition Summary: Total Depth measured 11447 feet true vertical 9221.38 feet Effective Depth measured 11360 feet true vertical 9140.18 feet Casing Length Size MD Conductor 80 20" x 30" 42 - 122 Surface 2688 13-3/8" 72# L-80 41 - 2729 Production 9430 9-5/8" 47# L-80 40 - 9470 Liner 2213 7" 26# 13CR80 9232 - 11445 Liner 6824 7-5/8" 29.4# HT-95 2400 - 9224 Perforation depth: Measured depth: 10846 - 10966 True Vertical depth: 8663.76 - 8774.75 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# Packers and SSSV (type and measured depth) Stimulate 0 WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory Service 192-0980 D 6. API Number: 50-029-20829-01-00 9. Well Name and Number: S-07A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Plugs (measured) Junk (measured) 10426 PXN None TVD Burst Collapse 42 - 122 41 - 2648.08 4930 2670 40 - 7479.26 6870 4760 7306.89 - 9219.51 7240 5410 2365.18 - 7301.1 8180 5120 13CR80 39 - 10448 7-5/8" Baker SBP Packer 7" Top Packer 4-1/2" Baker SABL-3 Packer 2390 9227 10379 12. Stimulation or cement squeeze summary: Intervals treated (measured): SC.I\NNEL C 2 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure SHUT-IN SHUT-IN 15. Well Class after Droposed work: Exploratory Development M! 16. Well Status after proposed work: Oil M Gas WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RBDMS BFt DEC X 9 2005 Contact Sharmaine Vestal Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Printed Name Sharmaine Vestal ?Lu OR I Tubing pressure Service WDSPl Title Data Mgmt Engr Signat~;~~ Form 10-404 Revised 04/2004 Phone 564-4424 Submit Original Only Date 12/15/2005 ~ e e S-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I~TIVI.1)'¡DATE I ,~o'·~tlIMI.~~1;~~32.;;iji~.\~A?7· ';~I 11/13/2005 ***WELL S/I ON ARRIVAL*** (secure well) DRIFT W/ 4.5" BLB & 3.62" G-RING TO 10,500 SLM. LRS LOAD TBG. W/ CRUDE.PUMED 260 BBLS CRUDE. RAN 41/2 XXN SAT DOWN @ 8414 SLM. #2 MANDREL, LEFT PLUG. SEVERAL ATTEMPTS PULLING PLUG *** JOB CONT ON 11-14-05*** 11/14/2005 *** JOB CO NT FROM 11-13-05*** (secure well) MULTIPLE RUNS TO 8411' SLM TO RETRIEVE 4.5" XXN MADE THREE ATTEMPS W/4 1/2 GR, @ 8414 SLM. SAW 2' MOVEMENT. RAN 41/2 GS SAT DOWN @ 8414 SLM. LATCHED PLUG, AND RECOVERED, GAUGE OBSTRUCTION W/ 3.62" G-RING FROM 8411' SLM ***JOB CO NT ON 11-15-05*** 11/15/2005 *** JOB CO NT FROM 11-14-05*** (secure well) BRUSHED PLUG PACKING OUT TBG TAIL. DRIFTED W/ 3.80" CENT TO XN @ 10,392' SLM. SET 4.5" PXN (4.5" XO TO 3.5" EQ SUB W/4 x 3/16" PORTS) @ 10,392' SLM. P-PRONG 96" LONG W/ 1 3/4" FN. LRS PREFORMED MIT-T TO 2000 PSI, IA TRACKING W/TBG. BP.REP. GOOD TO GO, RDMO. *** LEFT WELL SHUT IN,"fLJRNED WELL OVER TO PAD OPER. *** 11/16/2005 T/I/O=50/730/30. Temp=SI. Monitor WHP's (Post L & K). TBGP decreased 410 psi, lAP decreased 50 psi, OAP increased 10 psi from 11/15/05. 11/17/2005 T/I/O=420/730/40. Temp=SI. TBG & IA FL (For Secure). No change in lAP, OAP increased 10 psi over night. TBG FL @ 48'. IA FL @ 1134'. 11/18/2005 T/I/O= 480/730/45. Temp= SI. Monitor (For Secure). CLP? GL T blinded? Tbg pressure increased 60 psi, lAP unchanged and OAP increased 5 psi overnight. CLP (LDF) = 229 psi @ the pad and 165 psi @ GC2. GL T is blinded and blocked in behind the wellhouse. ALP= 400 p~i. 11/19/2005 T/I/O=470/730/45. Temp=SI. Monitor (For Secure). TBGP decreased 10 psi, no change in lAP, no change in OAP. 11/20/2005 T/I/O=470/730/40 Temp=S/I Monitor (For Secure) AIL line blinded at tree, lateral and gate valve blocked. Flow line shows 250 psi. OAP dropped 5 psi from yesterday. FLUIDS PUMPED BBLS 1 I ::::L 1 Problem Well Notification: S-07A (PTD #1920980) PTiJ ~ ,qz-oCf<b. Subject: Problem Well Notification: S-07A (PTD #1920980) Fr9m: "NSU, ADW Well Integrity Engineer" <N8UADWWellIntegrityEngineer@BP .com> Date: Sat,. 13 Nov 2004 20:27:26 ~09OO . '.. . . T~¡::ny o~ng,"Jirri~.'.. <y oUÎ1g)J@J3;P'.pom>,~ "OPB,. GC2 Ar~(i\ '¥gf',':' <QPBGC21f.@B~ ~c~m:>o/ "R~ssberg, _R Steven" ~Ros~be~@a?'COtn>,' "NSU,. A.D"'W elFqperati()nsSuperyisot",., ' . ;4i~UAD~enOperátiOtis~upe(Vi~or@ßP~c.om>~"GPJ3;>Wells.()p~:E~g!",:,.., ..:. "" ,. ~~~~~ri~=';T¡iif%~~~~~~;¡!:-1~1~~~~rø~~~':'j"" Cóþ1pl~ti()n Sup~ryisqr" <N~UAI)WWt&CompletionSupervl~9r@J3P .còITl>,:~'GPB;F~d :opst~a~',~,. <q~B;FI~()pS~äq@ßP';cöm>'::,,9PØt_()ps.::Mgr'~.<;GPa()psrvtgr.@Bþjc~.Il1?~'"*GPB,:.Well' Pads~W'~'~ ::. <âPBWéllP.ådsWZLY@J3i>~c01U?:..':" . . ':. ,.. ". .': . .:.' ..: ..,' '-' .; ..':. . : ::": . Cç: "NSU;. 'ADW :Well.Integrity : Erigineer" <NSU AD.WWetlIn~egrityEngilleer@BP.cöni?~' 'tMie~e,' ~<>:perlL.w<robert~inieIke@Bþ'.cò111><:' :. ..'.' c.' .:'.," ",:.,;.' . """:., ':"';", . All, Well S-07A (PTD #1920980) has sustained casing pressure on the OA and the well has been classified as a Problem well. TIO's on 11/13/04 were T/I/O = 1920/1920/1380. The plan forward for this well is as follows: 1. FMC: Service IC packoff 2. FB: CITOA to 3000 psi 3. DHD: TIFL 4. WAV: Eval for waiver Attached is a wellbore schematic. Please call if you have any questions. «S-07A.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: NSUADWWeIIIntegrityEngineer@bp.com Content-Description: 8-07 A.pdf Content-Type: application/octet-stream Content-Encoding: base64 JA:iA(þ scP ~ f 411z 4 I c:¡ 20 pJ; . I uS; 1\1 -J:A q II. )(q '51. 'I f/67o{5: I 'fzD f=>; L- ::s oÁ '1 S'/ß '()<. 13 "31 ß l\ f3Bo fS; 13~ùf:>~ 4~ fvtYyP 3oQZ-P5; o~ 2£\"61 ps\' ök.. ~~t 1/{6/(4- ~CANNEL) NO\j 2 3 2004 1 of 1 11/15/2004 8:57 AM lREE = 4" FI\.I'C WELLHEA D = FI\.I'C ÁCTUA TOR = AXElSON KB. ELBI = ----"-67~27' BF~"i3..ËV''';;'' . áfL75ï KOP = 1700' .. ..' .. ,Max Angle =.46 @ 7_900' Datum 1\¡1[) = 11 066' Datum lVD= 8800' SS S-07A 1 ~ ~ (8 TOP OF 7-5/8" CSG 1-1 2400' 1 ~ - 113-318" CSG, 72#, L-80, 10 = 12.347" H 2729' rJ Minimum ID = 3.725" @ 10426' 4-1/2" SWN NIPPLE 17-5/8" TIEBACK CSG, 29.04# HT-95 STL 1-1 9224' TOP OF 7" 13 CR TBG 1-1 9227' 19-5/8" CSG, 47#, L-80, 10= 8.681" 1-1 9470' ITOPOF CEfvENT 1-1 9470' PERFORATION SUI\i1\IIA RY REF LOG: BHCA/GR ON 11/23/92 (TIE-IN LOG) ANGLEATTOPPERF: 23@ 10846' Note: Refer to A"oduction OB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3- 318" 4 10846-10966 0 12/10/92 3-3/8" 10 10846-10876 REPERF 04/19/93 I EZSV 1-1 9710' -'= ~ 11 ~ 14-1/2" TBG, 12.6#, 13CR, 0.01522 bpf, 10 = 3.958" 1'1 10448' I SAFETY NOTES: 13 CR TBGANO LNR 2119' H 4-1/Z' OllS SSSV NIP, 10 = 3.813" I 2390' H 7 -5/8" SB PKR, 10 = 6,875" 1 2632' H OV A<R 1 ST IIIÐ 5 3183 4 5715 3 7405 2 8437 1 9161 GAS LlFTMANDR8.S lVO ŒV TYPE VLV LATCH 2938 40 OTIS BK 4743 44 OTIS BK 5939 45 OTIS BK 6662 44 OTIS BK 7188 42 OTIS BK PORT DATE 9219' 1- 7" BA KER TIEBA CK, SEAL ASSY XO TO 7 -5/8" CSG llEBA CK WINDOW 9470' 10353' H4-1/2" PARKER SWS NIP, 10= 3.813" 1 10379' 1-17" BAKERSABL-3 A<R, 10= 3.84" 1 10409' 1-14-1/2" PARKER SWS NP, 10= 3.813" 1 10426' H 4-1/2" PA RKER SWN NIP, 10 = 3.725" 10448' H4-1/Z' VVLEG, 10=3.958" 1 1 10420' H ELIIIÐ Tr LOGGEO 08/1 0/93 I PBTO 1-1 11360' 1 IT'TBG, 26#, 13CR, 0.0383 bpf, 10= 6.276" H 11445' I oo,lE 11/82 12/01/92 08111/93 03113/01 03115/01 COMrÆNTS ORIGINAL COMA..ETlON LCLE SIDETRACK CONPLEfION LAST WORKW ER SIS-M-I CONVERTEO TO CANVAS SIS-I\II) FINA L RBI BY OA TE REV BY COMrÆNTS 09/24/01 RN'TP CORRECTIONS PRU 01-0 E BAY UNIT WELL: S-07A PERm No: 92-0980 API rt>: 50-029-20829-01 Sec.35, T12N, T12E 8P Exploration (Alaska) ON OR BEFORE ~IAI I- UI- ALASKA ALA$'"~<'01L AND GAS CONSERVATION OOMMISSP REPORT C -SUNDRY WELL OPEnATIONS 1. Operations performed: Operation shutdown__ Stimulate x Plugging__ Pull tubing Alter casing __ Repair well Perforate__ Other__ 2. Name of Operator BP Ex/Noration (Alaska) Inc. 3. Address P. O. Box 196612, Anchoraoe, Alaska 99519-6612 4. Location of well at surface 1639' SNL, 1415' EWL, SEC. 35, T12N, R12E At top of productive interval 1751 SNL, 2090' WEL, SEC. 02, T11N, R12E At effective depth 1902'SNL, 1840' WEL, SEC. 02, T11N, R12E At total depth 1872' SNL, 1940' WEL, SEC. 02, T11N, R12E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 67.3 AMSL 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number S-07A(32-02-11-12) PBU number/a roval numbe 9. Permit ~ ~p ~. 82-155 / 10. APl number 50.029-20829 '" 0 J 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: meaSured true vertical Effective depth: measured true vertical 11445 feet BKB 9149 feet 10923 feet BKB 8972 feet Plugs (measured) Junk (measured) fill at 10923' MD (5/93) Casing Length Structural .. Conductor 110 Surface 2701 Intermediate 10872 Production Liner Perforation depth: Size Cemented Measured depth 20 x 30 8 c.v. 13 3/8 3720 c.f. 2729 9 5/8 1695 c.f. 94 70 1184 7 484 c.f 10633-11817 measured 10846-10966~11140c11213~ 11228'-11295~ 11310~11352' True vedical depth BKB 2648 8499 8305-9150 true vertica§ubsea 8596'-9065'(ss, four intervals Tubing (size, grade, and measured depth) 4 1/2" 12.6 f/IR, 13Cr NSCT Packers and SSSV (type and measured depth)7" TIW HBBP Packer at 10375', 4 1/2" SSSV at 2102' RECEIVED JUL 14 1998 13. Stimulation or cement squeeze summar~ee attachment Intervals treated (measured) Alaska 0il & Bas Cons. commiss Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1830 1642 114 987 3870 5731 1321 1184 241 255 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: OilX Gas Suspended Service Signed17. ~~~J~l hereby ce 'fy that t e fo oing, is _u d correct to the beStTitleofTechnica/Assistantl//my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN D~/PP~LICATE S-07A DESCRIPTION OF WORK COMPLETED Stimulation Operation O2/O7/98 A Acid Stimulation Treatment was performed using the following fluids: SUMMARY Move in rig up DS CTU #2. Pumped acid / xylene treatment as per program (used 12/10 HCL/Xylene based on sludge test results). Third and fourth diverter stages indicated good divert response. Well was turned over to Trico for flowback. Fluids Pumped BBLS. Description 61 Methanol 401 Sea water 326+75 95 2% KCL 64 Gel Sea Water 285 12/10 HCL/Xylene 906 Total Pumped PERMIT 92-098 92-098 92-098 92-098 92-098 92-098 92-098 92-098 92-098 92-098 92-098 92-098 DATA SURVEY AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 5475 T 10600-11420 AC/CN/DLL/GR 1 R 9470-11395 SPERRY SUN SURVEY DWOP R 9470-10845 ANADRILL 407 R 11/08/92-11/29/92 R COMP DATE:01/ll/93 STAT L 10669-10918 1 SSTVD L 10600-11421 MD 1 SPIN L 0.00-10916 PROD L 10916-10917 1 PROD L 1980-11210 1 PFC L 10710-11100 PFC L 9950-11300 1 92-098 DLL/GR 92-098 CNL/GR 92-098 CL L 10600-11390 L 10600-11363 L 9620-9720 BRIDGE PLUG REC 1 92-098 1 92-098 CCL/TUBING CTTR L 10100-10420 1 92-098 CCL/GR (JWL) L 10200-10926 1 BHC/AC/GR L 10600-11421 Page' 1 Date' 01/04/95 RUN DATE_RECVD 12/22/92 01/26/93 01/26/93 01/26/93 01/26/93 04/19/94 12/18/92 06/07/93 06/07/93 01/26/93 04/12/93 12/22/92 12/18/92 12/18/92 11/25/92 07/19/93 08/24/93 12/18/92 yes ~ And received? Are dry ditch samples required? Was the well cored? yes ~2Analysis & description received? required? yes /~F Received? yes ~~ Are well tests Well is in compliance . ~/~C'~ Initial COMMENTS yes ~ STATE OF ALASKA ALAE'~OIL AND GAS CONSERVATION COMMISSIC .... REPORT SUNDRY WELL OPEr,ATIONS Dpe ration ,-- __ Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X / 1. Operations performed: Operation shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1639'SNL, 1415' EWL, SEC. 35, T12N, R12E At top of productive interval 1751 SNL, 2090'WEL, SEC. 02, T11N, R12E At effective depth 1902' SNL, 1840' WEL, SEC. 02, T11N, R12E At total depth 1872' SNL, 1940' WEL, SEC. 02, T11N, R12E 5. Type of Well: Development X Exploratory Stratigraphic Service 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11445 feet BKB 9149 feet 10923 feet BKB 8972 feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE = 67.3 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8, Well number S-07A(32-02-11-12) PBU 9. Permit number/approval number 10. APl number 50- 029-20829 11. Field/Pool Prudhoe Oil Pool fill at 10923' MD (5/93) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 x 30 8 c.y. Surface 2701 13 3/8 3720 c.f. 2729 I nte r meal iate 108 72 9 5/8 1695 c.f. 94 70 Production Liner 1184 7 484 c.f. 10633-11817 Perforation depth: measured 10846-10966',11140'-11213', 11228'-11295', 11310'-11352' true vertical subsea 8596'-9065'(ss, four intervals Tubing (size, grade, and measured depth) 4 112" 12.6 #1ft, 13Cr NSCT Packers and SSSV (type and measured depth) 7" TIW HBBP Packer at 10375', 4 1/2" SSSV at 2102' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth BKB 2648 8499 8305-9150 14. ,j i',i 2 5 i994 .,,_,,, ~,s',-~a uu e Gas (;ons. Commission Anchorage Prior to well operation Subsequentto operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1830 1642 114 987 3870 ' 5731 1321 1184 Service Tubing Pressure 241 255 16. Status of well classification as: Oil X Gas Suspended 17. I hereby certify that the foregoipg is tr~e and correct to the best of my knowledge. FS;~mneldo ~:~%.~~, ~/'// }~-"/0/'~.~..,' Title Senior TechnicalAssistantl -4 4 ev 06/15/88 '~ Date SUBMIT IN DUISLIC/~TE 4/19/93 8/17/93 WELL S-07A(32-02-11-12) FRAC/REPERF The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 10846'-10876'MD Performed a Hydraulic Fracture using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST: 360 BBLS 20g GEL DATA FRAC: 30 BBLS 40g GEL PREPAD TO ESTABLISH RATE 135 165 30 98 32 6 10 13 17 19 22 211 167 BBLS 40g X-LINK GEL PAD W/4.0% ESL (225 GAL) BBLS 20g GEL DATA FRAC FLUSH BBLS 40g GEL PREPAD TO ESTABLISH RATE BBLS 40g X-LINK GEL PAD W/4.0% ESL (175 GAL) Dirty 1 PPG 2 PPG 3 PPG 4 PPG 5 PPG 6 PPG 7 PPG 8 PPG 20# LINEAR GEL FLUSH fjh 6/20/94 ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 14 April 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION W-il (14-28-11-12) A-03 (44-27-11-13) 1 PLS STATIC FINAL BL 3.~BL-~STATIC RF SEPIA 1 PLS INJ. FINAL BL ~"PLS INJ. RF SEPIA A-08 (23-36-11-13) 1 PLS INJ. FINAL BL ~%~PLS INJ. RF SEPIA A-39 (31-35-11-13) 1 PLS PROF. FINAL BL ~PLS PROF. RF SEPIA G-30 (12-07-11-14) 1 PL STATIC FINAL BL ~I~STATIC RF SEPIA ~-50~ H-24 e-51 1 PLS STATIC FINAL BL -.1 PLS STATIC RF SEPIA 1 PL$ STATIC FINAL BL -~ PLS STATIC RF SEPIA 1 PLS STATIC FINAL BL -T P~ STATIC RF SEPIA 1 PL STATIC FINAL BL -i P~ STATIC RF SEPIA 1 PLS STATIC FINAL BL %'PA~ STATIC RF SEPIA ~-I~ Z-04 (41-24-11-11) 1PLS STATIC FINAL BL /1PI~S STATIC RF SEPIA 1 PLS STATIC FINAL BL ~1 PLS STATIC RF SEPIA ECC No. Run # 1 5642.01 Run # 1 Run # 1 3038.01 Run # 1 Run # 1 6163.00 Run # 1 Run ~ 1 5999.02 Run # 1 Run ~ 1 3583.02 Run # 1 Run # 1 4735.01 Run ~ 1 Run ~ 1 5670.01 Run # 1 Run # 1 · Run ~ 1 6157.00 Run # 1 6160.00 Run # 1 Run # 1 6159.00 Run # 1 Run # 1 4129.02 Run # 1 Run # 1 5815.01 Run # 1 cont/ ~%[ S-15 (32-26-12-12) 1 PL STATIC FINAL BL ~ ~L STATIC RF SEPIA / 1 PLS STATIC FINAL BL ~'~S STATIC RF SEPIA Run # Run Run # Run # 5010.01 5897.02 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 · Attn. Rodney D. Paulson Received by: ~ :~x~jL Date: STATE OF ALASKA " ALAoKA OIL AND GAS CONSERVATION COMMISS~,*I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Perforate__ Pull tubing X AItercasing __ Repair well Other X Packerleak 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration Development x KBE = 63.14 feet Exploratory 3. Address StratJgraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1639' SNL, 1415' EWL, SEC. 35, T12N, R12E S-07A (32-02-11-12) At top of productive interval 9. Permit number/approval number 1760' SNL, 2055' WEL, SEC. 2, T11N, R12E 92-98/Conservation order 258 At effective depth 10. APl number 50- 029-20829-01 At total depth 11. Field/Pool 1881' SNL, 1866' WEL, SEC. 2, T11N, R12E Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured 11445 feet Plugs (measured) true vertical BKB 9222 feet Effective depth: measured 11360 feet Junk (measured) true vertical BKB 9141 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 10846'-10966' Reperf 10846'- 10966' true vertical Tubing (size, grade, and measured depth) 4-1/2", 13CR, 12.6~ tubing to 10448'MD Packers and SSSV (type and measured depth) 7" x 4" SAB3L Packer @ 10379' MD; 4-1/2" Otis "HXO" 9CR SL VN @ 2119' MD 13. Stimulation or cement squeeze summary K Intervals treated (measured) ~-._ ~ . ' ~ '~ ~ "','~ ~r~ ~ Treatment description including volumes used and final pressure Alaska 0il ~,. 14. Re.~resentative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Rep°rt.°'f-'wl~ll./~/~'Ojperati°ns x Oil x Gas Suspended Service 17. I here~y~,~j/thft th~foregoing)is t,ru~e ~_~!~o thee best of my knowledge.i~I~ud~!/'ll~ ~"/~ Si~]ned /.~,,~-, .... /- ._- _ Title Drilling Engineer Supervisor Dat ...... Form 1'0~-~ 5/88 SUBMIT IN D .ICATE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: S-07A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-20829 PERMIT: APPROVAL: ACCEPT: 07/20/93 12:00 SPUD: RELEASE: OPERATION: DRLG RIG: WO/C RIG: DOYON 14 07/20/93 ( 1) TD:11445 PB:10631 PULL BPV MW:10.1 KCl MOVE RIG OVER HOLE, RU FLOOR. TAKE ON SW. PULL BPV & PUMP OPEN HYD VALVE. 07/21/93 ( 2) TD:11445 PB:l1360 07/22/93 (3) TD:11445 PB:l1360 TEST BOPE MW: 8.5 Seawater REV CIRC, RECVR DIESEL. CHG LINES & PUMP DOWN TBG. CBU. ND TREE, NU. CHG RAMS, INSTL FLOW NIPPLE, LINES. RU & PULL CK VALVE, RD. RU TO TEST BOP. LEAK IN CHOKE LINE, KILL LINE & MANIFOLD. TIGHTEN ALL CONNECTIONS. PU OVERSHOT MW: 8.5 Seawater CONT TEST BOP. CIRC, RU CSG CREW. PULL & LD JTS & CUT OFF TBG. CHG TOP RAMS & DP. PU KELLY & FISHING BHA. 07/23/93 (4) TD:11445 PB:l1360 07/24/93 ( 5) TD:11445 PB:l1360 POH FOR NEW GRAPPLE MW: 8.5 Seawater TEST RAMS, INSTL WEAR RING. PU FISHING BHA & RIH. BOP & SPILL DRILL. RIH TO 10225. PU KELLY INGAUGE FISH. WORK TO RELEASE LATCH. POH FOR BHA CHANGE. CBU MW: 8.5 Seawater CONT POH. RIH, POH W/FISH. MU BHA, SERV RIG. RIH TO 11370. MILL ON PKR. CBU. 07/25/93 ( 6) TD:11445 PB:l1360 RIH MW: 8.5 Seawater POH, LD MILL. RIH. PU SPEAR PKR, SERV RIG. POH W/FISH. LD PKR. PU BIT & RIH. 07/26/93 (7) TD:11445 PB:l1360 RU TO RUN COMPLETION MW: 8.5 Seawater SERV RIG. CONT RIH. REV HOLE CLEAN. CHG OVER TO FILTERED SW. POH. LDDP. PULL WEAR RING, CHG TOP RAMS. RU TBG TONGS. 07/27/93 (8) TD:11445 PB:l1360 CHG TBG SPOOL & PK OFF MW: 8.5 Seawater CONT RU TO RERUN TBG COMP. RUN JTS & COLLARS. PU PKR & SET. ND BOP, CHG PK OFF & REPLC W/TBG SPOOL. R EC WELL : S-07A OPERATION: RIG ' DOYON 14 PAGE: 2 07/28/93 (9) TD:11445 PB:l1360 PULL 2 WAY CHECK VALVE MW: 8.5 Seawater TEST PKOFF, NU BOP RISER & FLOW LINE. RELS STORM PKR & LD. RU & TEST CONTROL LINES. TEST SSSV LINES. INSTL 2 WAY CK, LAND TBG. RD. ND BOP, NU ADAPTER & TREE. TEST. PULL CK VALVE. SIGNATURE: (drilling superintendent) DATE: BP EXPLORATION BP Exploration (Alaska) lac, 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 08/18/93 T# 84902 BPX/PBU ~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. G_09~1-_.~9 /PRODUCTION LOG 08/11/93 #1 9800.00-10212.00 ATLAS 5 " H-22~-~5-'PERF 08/12/93 #1 9370.00- 9621.00 ATLAS 5 " P- -~ ~FC/CCL (PERFO~TION RECO 08/09/93 ~1 12800.00-12997.00 ATLAS 5 " p- SBL ~ ~ 08/08/93 ~1 12150.00-13014.00 ATLAS 5 S-07A~ CCL (JEWELRY LOG)/~ 08/10/93 %1 10200.00-10926.00 ATLAS 5 " U-14[ PFC/CC~E~O~TING RECO 08/10/93 %1 9100.00- 9421.00 ATLAS u_~~~l~~ 5 " (JEWELRY LOG) CCL/~ 08/09/93 %[ 8360.00- 9448.00 ATLAS 5 " u-[4~ SBL/G~CC~ 08/09/93 %[ 8800.00- 9448.00 ATLAS 5 X-0~a. Uq__. --. CNL ~/~ 08/08/93 ~1 [1400.00-12000.00 ATLAS 5 " Information Control Well Records AUG 2 4 Alaska 0ii & Gas CMs, MEMORANDUM STATE ALASKA ALASKA OIL AND GAS CONSER VA TION COMMISSION TO: David Johns_~.q.~~ Chairma~.-~.~' THR U: FR OM: Blair Wondzell P.I. Supervisor Doug Amos (~~ Petroleum Inspector DATE: July20, 1993 FILENO: aighguab. DOC PHONE NO.' 279-1433 SUBJECT: BOPE Test Doyon 14 BPX PBU S-7~ Prudhoe Oil Pool PTD No. ,q ~...-q~ Tuesday July 20, 1993: I traveled this date to BPX PBU S-7~t well to witness the BOPE Test on Doyon Rig No. 14. Rig 14 has been stacked for the past six months, and will be doing workovers on two wells on S-Pad and then move to Z-Pad. Because of the ~fferent configration required for the Stack Choke Line and other modifications need"Ror workover operations~ the BOPE test was delayed. Wednesday July 21, 1993: The testing commenced at 5:30 a.m. this date. As the attached AOGCC BOPE Test Report indicates, with the exception of the Gas Detectors being out of calibration, ! found the rig in good condition, with an experienced crew whose members were knowledgeable about the BOPE equipment and the AOGCC Test Procedure. The Blind Shear Rams and the 3 1/2" Pipe Rams could not be tested on this initial test because of a tubing hanger leak. After pulling the tubing a test plug will be installed and these two items tested. BPX representative Don Wester will contact an inspector when the rig is ready to conduct these two tests. IN SUMMARY, witnessed the BOPE TEST @ BPX PBU S-7a well, on Doyon 14, 3 Test Hrs, 1 Failure, 18 Valves Tested. Attachment AIGHGUAB.XL$ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Doyon Corp. Operator: BPX Inc. Well Name: PBU S-7a Casing Size: 9 5/8" Set @ Test: Initial X Weekly Rig No. 14 PTD # Rep.: Rig Rep.: 9, 726 Location: Sec. Other DATE: Rig Ph.# Don Wester 7/20/93 659-4510 B. Mod 35 T. 12N R. 12E Meridian Umiat MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: OK Well Sign OK Upper Kelly / IBOP Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly/IBOP Reserve Pit N/A Ball Type Inside BOP BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 250/5,000 P 250/5,000 P Not Tested N/A Not Tested N/A P 250/5,000 250/5,000 P 250/5,000 P N/A N/A 2 2 0 M U D SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Gas Detectors OK OK Test Quan. Pressure P/F N/A Not Tested N/A N/A Not Tested N/A N/A Not Tested N/A N/A Not Tested N/A CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 14 Test Pressure P/F 250/5,000 P 31 250/5, 000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 4 Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2,100 3,000 I P 1,700 I P minutes 55 sec. minutes 23 sec. Yes Remote: Yes Psig. Number of Failures: 1 ,Test Time: 3.0 Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The Gas detectors worked fine but need calibration. The blind rams and the 3 1/2" pipe rams could not be tested until after the tubing is pulled and a test plug can be installed. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES YES NO 24 HOUR NOTICE GIVEN YES YES NO Waived By: Witnessed By: FI-021L (Rev. 7/19) AIGHGTAB.XLS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/14/93 T# 84771 BPX/PBU ~OGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. S-07A TUBING CUTTER 07/12/93 %1 10100.00-10420.00 ATLAS 5 " Z-11~O,~~ PERF 07/12/93 #1 9000.00- 9973.00 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: 05/25/93 T# 84580 BPX/PBU~OGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at A_04,~'0~'9 PFC 05/13/93 #1 $-07~'O~ PRODUCTION LOG' 05/11/93 #1 C-29~~ CNA 05/12/93 #1 C-42~5'~ STATIC 05/12/93 #1 E-07~-~PROD-F 05/12/93 #1 E-13~'~ PRODUCTION LOG 05/12/93 #1 E-20~--~q PROD-F 05/13/93 #1 F-11~--~O~ PROD-F 05/10/93 ~1 F-16~q~ CNn 05/11/93 #1 F-17~[--~[ PFC 05/10/93 #1 F-429~%~ PRODUCTION LOG 05/09/93 ~1 F-46~~ PDK-100 05/08/93 ~1 H-i~-~0 PROD-F 05/09/93 ~1 M-21~-~ TUBING CUTTER 05/19/93 ~1 M-26A~ GR 05/11/93 ~1 P-04~{-~ PFC 05/18/93 ~1 R-30~-Q~ PFC 05/16/93 ~1 S-07k~.9~SPINNER/TEMP 05/14/93 ~1 X-26_., ~~ INJ/TEMP 05/20/93 ~1 below. If you have any (907) 564-4004. 10500 11540 11000 8750 9050 11000 9700 9200 8830 10380 2158 9000 10260 8400 9100 11400 11130 0 9100 .00-10893. .00-11785 .00-11811 .00- 9852 .00- 9400 .00-11350 .00-10140 .00- 9500 .00- 9564 .00-11165 .00-11300 .00- 9383 .00-10720 .00- 8474 .00-11110 .00-11750 .00-11400. .00-10916. .00- 9680. 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 5 00 ATLAS 5 " 00 ATLAS 5 " 00 ATLAS 2/5" 00 ATLAS 5 " Information Control Well Records STATE OF ALASKA AL~oKA OIL AND GAS CONSERVATION COMMISS,._.N Su~nd __ Operation Shutdown __ Re-enter su~ended well A~er ~i~ Repair well Plugging Time e~ension __ Stimulate Pull tubing Varian~ X Perorate ~her 1. Type of Request: Change approved program__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1639' SNL, 1415' EWL, SEC. 35, T12N, R12E At top of productive interval 1751 SNL, 2090' WEL, SEC. 02, T11N, R12E At effective depth 1902' SNL, 1840' WEL, SEC. 02, T11N, R12E At total depth 1872' SNL, 1940' WEL, SEC. 02, T11N, R12E 5. Type of Well: Development X Exploratory __ Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 67.3 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number $-07A(32-02-11-12) PBU 9. Permit number 10. APl number 50- 029-20829 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured Effective depth: 11445 feet Plugs (measured) truevertical BKB 9149 feet measured 10923 feet Junk (measured) true vertical BKB 8972 feet Casing Length Size Cemented Structural -- Conductor 110 20 x 30 8 c.y. Surface 2701 13 3/8 3720 c.f. Intermediate 10872 9 5/8 1695 c.f. Production/Tie Back 6820 7 5/8 708 c.f. Liner 1184 7 484 c.f. Perforation depth: measured 10846'-10966' true vertical subsea 8596'-8707' Tubing (size, grade, and measured depth) 4 1/2" 12.6 #/ft, 13Cr NSCT fill at 10923' MD (5/93) Measured depth 2729 9470 9219 9219-11445 True vertical depth BKB 2648 8499 7230 7230-9152 : ' ~ ':i ,/' '-. · -- · '~ , Packers and SSSV (type and measured depth) 7" TIWHBBP Packer at 10375', 4 1/2" SSSV at 2102' 13. Attachments Description summary of proposal × Detailed operations program~ BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved<_~ Name of approver R. Douglass ~" 5/18/93 Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby ~tify that the f/Q)rego/~ is true and correct to the best of my knowledge. Signed Title Supervisor Waterflood/Miscible Flood FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance ~ Mechanical Integrity Test Subsequent form required 10- Original Signed By Approved by order of the Commission Dab, id W., l(-~hnslf)lq Form 10-403 Rev 06/15/88 · ',[::;pr uvcd ~J~roval Returne~ .,_r_ No. Commissioner Date (,'"~; z_ 7¥? SUBMIT IN TRIPLICATE WELL S-07A(32-02-11-12) Request for Variance Well S-07A has tubing-inner annulus communication via a failed production packer at 10375' MD. The well has been scheduled for a RWO to install new tubing to eliminate the communication. BP Exploration Ak. is requesting a variance, pursuant to Article 3 section 20AAC, 25.200(d) to continue producing the well until a workover rig is available. The well was last tested @1890 BOPD, 895 GOR, 7% WC. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/27/93 T# 84513 BP/PBU~OGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. ~ ~-04 ,~PFC <,\~'%-33 A~DPRODUCTION 'L~-07A~ pfc ~ ~'&S-33 PFC 'f~v~-33 PDK-100 S-37 PFC 04/22/93 #1 LOG 04/21/93 #1 04/19/93 #1 04/20/93 #1 03/28/93 #1 04/19/93 #1 10665.00-10901.00 ATLAS 5 " 10900.00-11350.00 ATLAS 5 " 10710.00-11100.00 ATLAS 5 " 9163.00- 9232.00 ATLAS 5 " 9000.00- 9270.00 ATLAS 5 " 9252.00- 9596.00 ATLAS 5 " Information Control Well Records STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMP LETION REPORT AND LOG 1. Status of Well ;~"~-..~ ;. ~--~ i~~ Classification of Service Well OIL ~ ~S D ~ 2. N~e of O~mtor 7. Pe~it Numar BP ExpIorat~n 92-98 3. Address ~. APl Number P. 0. ~x 196612, Anchorage, Alaska 99519-6612 50- 029-20829-01 1~9' SN~ 1415'EW& SEC. ~, T12N, R12E ,.- , ...... ¢,~,-, ,,.:.¢ , Prudhoe Bay Unit 10. Well Number 1760'SN& 20~'WEL, SEC. Z T11N, R12E S-07A (32-02-1~- ~ 2) ~.~ ~' u ¢ ~'~ ~'.~-' ¢..¢ .... ~ 11. Field and P~I At Tot~ D~th ~ ..... ~Q ...... ~ Prudhoe Bay Field/Prudhoe Bay Pool I~1'SN& 1866' WEL, SEC. & T11N, R12E 5. Elev~ion in f~t (indite KB, DF, etc.) 16. Le~e Designation ~d Sedal No. KBE ~ 6Z3' [ ADL 28260 12. Date Spudded 13. D~e T.D. Re~ 14. D~e Comp., Su~. ~ Abed. I15. Waler D~th, if offshore 116. No. of Completions 11/1~92 11/2~92 1~10/92I N/A~t MSL I One 17. Tolal Depth (MD. TVD) 18. Plug Ba~ D~th (MD+TVD) ,g. Directional Su~ey ~0. O~,. where SSSV ,t p,. Thickness of Permafrost 11447'MD/9222'~D 11360'MD/9141'~D ~ ~ ~ DI 210~t MD/ 1900'Approx.) 22. Ty~ El~tric or Oth~ L~s Run DL~BHC/CN~GR 23. . OASIS, LINER ~D CEM~I~ ~ D~ MD CASING SBE ~. ~R ~. G~E 'T~ ' ~ ~E ~ C~~ R~D A~ ~D 20' Cond Weld 28' 138' 30" 8 cu yds ~ncrete 13-3/8' 72~ L-80 28' 2729' 17-1/2" 3720 cu ~ AS II 9-5/8' 47~ L-80 28' 9470" 12-1/4" 1565 cu 7-5/8' 29.~ HT95 2400' 9224' 8-1~" 714 cu ~ Class "G" F 2~ 130R80 9238~ 11~' 8-1~" 472 cufl Class "G" 24. PeHorations o~n to Pr~uction (MD+TVD of T~ and ~ttom ~d 25. ~R~RD inte~al, size and number) S~E DEP~ S~ (MD) PACKER S~ (MD) Gun Di~eter~3~" ~f 4-1/2" 13Cr 10~9' 10375' MD ~D 108~10966' 86~8~5' 26. ACID, F~C~RE, C~ ~UF~. ~C. DEP~ I~ERVAL (MD) A~U~ & KIND OF MATERI~ 27. ~O~N ~ST Date First Pr~uction lMethod of Operation (Flowing, gas lift, etc.) 1/11/93' D~e of Test Hours Tested ~O~~ ~R OIL-BBL ~F WATER-BBL C~~ IGAS~IL RATIO ~T P~D I ;Flow Tubing Casing Pre~ure C~CU~TED OIL-BBL ~F WATER-BBL OIL GRAVITY-APl (~rr) Press. 2~UR RATE 28. CORE DATA Brief description of lithology, porosity, fracture, ~mnt dips, and pr~en~ ol oil, gas or water. Submit ~re ~ips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS ~-,.,RMATION TESTS NAME Include inlerval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,,, Sag River 10706' 8534' Sh ublik 10748' 8573' Top Sadlerochit 10846' 8664' Zone 2 11110' 8908' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~ %-'?- ' Title Drilling Engineer Supervisor Date //'~ 2-,3/¢'~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection,, water injection, steam injection, air injection, salt Water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27, Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Im ......... jection, Gas Injection Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: S-7A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 11/08/92 ( 1) TD: 0 PB: 0 TAKE ON SEAWATER. MW: 8.5 Seawater MOVE RIG W/ H PAD. RIG ACCEPTED @ 05:00 HRS, 11/8/92. TAKE ON SEAWATER. 11/09/92 ( 2) TD: 0 PB: 0 11/10/92 ( 3) TD: 0 . PB: 0 · 11/11/92 ( 4) TD: 9770 PB: 9770 11/12/92 ( 5) TD: 9770 PB: 9770 11/13/92 ( 6) TD: 9770 PB: 9770 PULL 3-1/2" TBG. MW: 8.5 Seawater PULL BPV. CIRC DIESEL OUT. WELL DEAD. N/D TREE. N/U BOPE. TEST BOPE. PULL TBG HGR TO FLOOR. POOH W/ 3-1/2" TBG. L/D DP. MW: 8.5 Seawater POOH W/ 3-1/2" TBG. TEST BOPE. RIH W/ TSA MECH CSG CUTTER. SET CSG CUTTER @ 9770' CUT CSG. CIRC OUT CRUDE F/P & BRINE F/ ANNULUS. POH. L/D DP. RIH W/ 9-5/8" BP. MW: 8.5 Seawater POOH. L/D DP. RIH W/ 7" CSG SPEAR. ENGAGE CSG. PULL. NO GO. RELEASE SPEAR. POOH. N/D BOPE. REMOVE PACKOFF. N/U BOPE. RIH W/ SPEAR. PULL CSG FREE. POOH. L/D FTA, CSG. POOH W/ 7" CSG. TEST 9-5/8" CSG. R/U ATLAS. FISH OUT 2 7" STOP RINGS F/ STACK. RIH W/ GR/JB TO 9770' POOH. RIH W/ 9-5/8" BAKER BP. CIRC. MW: 9.8 WBM RIH W/ BP. SET @ 9710' POOH. R/D ATLAS. TEST CSG. OK. RIH W/ "K" SECTION MILL. DISP SEAWATER W/ 9.8 PPG MUD @ 9710' SPOT 18 PPG PILL. POOH. START SECTION MILL CUT @ 9475'. CIRC. POH W/SECTION MILL MW: 9.9 KC1 CIRC & COND FOR MILLING OPERATION, MILL SECTION OF 9-5/8" CSG F/9475'-9508', ROTATE @ 130 RPM & CIRC HI-LOW VIS SWEEPS TO CLEAN HOLE, START SHORT TRIP, PULL 3 STDS, STARTED PULLING TIGHT ON 39/) STD, CIRC HOLE, ATTEMPT TO SHORT TRIP, STILL PULLING TIGHT, RIH BACK TO 9508', ROTATE & RECIP. PIPE, CIRC & PUMP HI-LOW VIS SWEEPS TO CLEAN UP HOLE, 50% METAL RECOVERED POH W/SECTION MILL WELL : S-7A OPERATION: RiG : DOYON 16 PAGE: 2 11/14/92 ( 7) TD: 9770 PB: 9770 11/15/92 ( 8) TD: 9770 PB: 9465 11/16/92 (9) TD: 9465' ( 0) 11/17/92 (10) TD: 9602' ( 137) 11/18/92 (11) TD:10046' ( 444) SECTION MILL 9-5/8" CSG MW: 9.9 KCl POH W/SECTION MILL, M/U NEW SECTION MILL, L/D MWD TOOL, RIH W/NEW SECTION MILL, BREAK CIRC. EVERY 1000', REAM THRU OPEN HOLE SECTION F/9475'-9498', PU TO MAKE CONNECTION, MILL WILL NOT GO INSIDE CSG, APPEARS BLADES ARE STUCK OPEN, BACK REAM SECTION MILL W/BLADES STUCK OPEN @ 9745, BACK REAMING F/9745'-9645', ATTEMPTING TO WEAR OUT OR BREAK BLADES, CIRC HI-LOW VIS SWEEP TO CLEAN HOLE SECTION, WORK PIPE UP THRU SECTION TO MAKE CONNECTION, MAKE CONNECTION, REAM DOWN F/9498'-BTM STUMP @ 9508', MILL SECTION PUMP DRILL PIPE WIPER PLUG MW:10.0 KCl MILL SECTION OF 9-5/8" CSG TO 9530' (65' SECTION), MIX & PUMP HI-LOW VIS SWEEP, JET FLOW LINE, POH W/SECTION MILL TO BTM OF TOP STUMP @ 9465', JAR MILL THRU SECTION, MILL FREE, NO PROBLEM, POH W/MILL, PULLED TIGHT @ 7670', MIX & PUMP HI-LOW VIS SWEEP,M POH, L/D BHA & SECTION MILL, BLADES CLOSED, WORN 80%, RIH W/5" DP, BREAK CIRC EVERY 1000', WASH TO 9685', CIRC DRILL PIPE VOL, REV CIRC, BATCH MIX CMT, RIH TO 9685', R/U UP BJ, TEST LINES TO 3000 PSI, PUMP 32 BBLS H20, PUMP 40 BBLS CMT, PUMP 12 BBLS H20, DISPLACE CMT W/150 BBLS MUD USING BJ PUMPS TO BALANCE PLUG, CIP @ 0500, POH 15 STDS DP, PIPE DRY, DROP DP WIPER PLUG TO CLEAR DP TESTING BOPE MW: 9.9 VIS:106 PERFORM LOW PSI HESITAITON SQUEEZE, BUILD PRESSURE UP TO 2000 PSI, HOLD SQUEEZE PSI, BLED DOWN TO 1950 PSI, BLEED OFF, POH, L/D 40 JTS DP, P/U 8-1/2" BIT & DYNA-DRILL, M/U STEERABLE DRILG SYSTEM BHA, RIH W/BHA # 4, BRK CIRC EVERY 1000', CBI, 72 SPM @ 2000 PSI, MU STORM PKR, SET 2' BELOW WELLHEAD, N/D BOPE, PULL 7" PACKOFF F/SPOOL, N/U TBG SPOOL W/TEST PORT ON FLANGE, INSTALL NEW 9-5/8" PACKOFF BUSHING, TEST TO 4500 PSI, OK, N/U BOPE, CLEAN OUT METAL CTGS F/STACK, INSTALL 4-1/2" X 7' VBR IN TOP, BLINDS IN MIDDLE, 5" PIPE RAMS ON BTM ORIENT & KICKOFF WELL MW: 9.8 VIS: 62 COMPLETE N/U BOPE & CHG RAMS, SET TEST PLUG, TEST BOPE, PULL TEST PLUG, INSTALL WEAR RING, STING INTO STORM PKR & RELEASE, POH, L/D PKR, SET MOUSE HOLE, KELLY UP & WASH DOWN TO TOP OF CMT @ 9298', REPAIR DRAW WORKS BLOWER MOTOR, RIG REPAIR, DRILL FIRM CMT F/9298'-9470' KOP, ORIENT & SIDETRACK WELL W/8-1/2" STEERABLE DRLG ASSEMB. DRLG 8-1/2" TURN & DROP MW: 9.8 VIS: 57 DRILG F/9602' TO 9952', PUMP HI-LO VIS SWEEP PRIOR TO SHORT TRIP', POH 10 STDS TO 9021', OBSERVED 40 KIPS OVER NORMAL P/U WHEN PULLING TOP STABILIZER INTO SHOE, RIH W/10 STDS-NOT TAKING WT. HOLE COND. GOOD, DRILL F/9952' TO 10046" WELL : S-7A OPERATION: RIG : DOYON 16 PAGE: 3 11/19/92 (12) TD:10323' ( 277) 11/20/92 (13) TD:10817' ( 494) 11/21/92 (14) TD:10845' ( 28) 11/22/92 (15) TD:l1207' ( 362) 11/23/92 (16) TD:11447' ( 240) 11/24/92 (17) TD:11447 PB: 9216 11/25/92 (18) TD:11447 PB: 9216 RIH W/BIT#2 MW: 9.9 VIS: 62 DRLG F/10046' TO 10323' PUMP HI-LO VIS SWEEP, DROP ! MULTI-SHOT,POH, P.U BIT #2-GUAGE STABILIZERS, RIH W/BHA #4 DRLG 8-1/2" HOLE SECTION MW: 9.8 VIS: 64 RIH TO 10323', BREAK CIRC & REAM 60'MD TO BTM, DRILL F/10323' TO 10817' RIH TO 10559' MW: 9.9 VIS: 56 DRLG F/10817'-1-845', PRESSURE INCREASED TO 3200 PSI @ 94 SPM, DRILL STRING OBSTRUCTION SUSPECTED, NO LOSSES OBSERVED, HOLE COND. UNCHGD, POH TO 9-5/8" SHOE @ 9460', MIX & PUMP PILL, ATTEMPT TO REGAIN FULL CIRC, UNSUCCESSFUL, POH WET, L/D BHA #4, P/U BHA #5(LOCKED ASSEMB.), RIH, SLIP & CUT DRLG LINE, CONTINUE RIH, CIRC @ 9213', JET PLUGGED, CIRC JET CLEAN, RIH TO 9867', HOLE COND BECOMING TIGHT, REAM F/9867' TO 10559', HOLE STILL TIGHT, SHORT TRIP TO 9-5/8" SHOE MW:10.0 VIS: 54 REAM & WORK HOLE F/10559'-10845', CIRC HI-LO VIS SWEEP, DRLG F/10845' TO 11196', POH TO TOP OF SAD. WHILE REPAIRING - PUMP SWAB ELEMENTS, RIH TO 11186', DRLG F/11186' TO 11207', CIRC HI-LO VIS SWEEP, PREP F/SHORT TRIP TO 9401', TIGHT SPOT ENCOUNTERED @ 2 STDS OFF BTM, WORK THRU TIGHT SPOT, REMAINDER OF HOLE SECTION OK. R/U FOR O/H LOGGING MW:10.0 VIS: 51 REAM & WORK HOLE F/10888' TO 11207', DRILL F/11207' TO 11445', SHORT TRIP WHILE REPLACING SWAB ELEMENT IN PUMP, DRILL 11445'-11447', PULLED TIGHT 4 STDS & DOUBLE OUT OF HOLE, PROBABLE LEDGE @ SHALE/SAND, REAM THRU TIGHT SPOT, POH FOR OPEN HOLE LOGS RIH W/PROD LINER MW:10.0 KC1 RU WIRELINE-LOG. RD. CHG OUT BHA. RIH, WASH & REAM TO 11447. CIRC & COND MUD, RUN CENTRIFUGE, PUMP LO/HIGH VIS SWEEP. POH, LD HWDP, CLEAR FLOOR. PREP RIG, RIH W/7" CSG. POH, L/D 5" DRILL PIPE MW:10.0 KC1 MU 7" BAKER LINER HGR, CIRC, R/D TORQUE TURN, RIH W/7" LINER, BIlK CIRC @ 9-5/8" SHOE, M/U CMT HEAD, CIRC, PUMP 25 BBLS ARCO SPACER, BATCH MIX CMT, PUMP 84 BBLS CMT, REV CIRC, NO CMT RTNS, L/D CMT HEAD, POH W/DP, TEST BOPE, CHG OUT DOOR SEAL, P/U POLISH MILL, RIH TO 4200', SLIP & CUT DRLG LINE, RIH W/POLISH MILL,POLISH OFF LINER TOP @ 9219'. POH, L/D 5" DP TO RUN 7-5/8" LINER TIE BACK WELL : S-7A OPERATION: RIG : DOYON 16 PAGE: 4 11/26/92 (19) TD:11447 PB: 9216 11/27/92 (20) TD:11447 PB: 9216 11/28/92 ( 21) TD: 11447 PB: 9216 11/29/92 (22) TD:11447 PB: 9216 CMT 7-5/8" CSG MW:10.0 KC1 POH, L/D 5" DP, STD BACK TO RUN 7-5/8" ;OMER. R/U CSG CREW, MU 7" SEAL ASSEMB. TO 7-5/8" CSG . RIH W/CSG, M/U BAKER LINER HGR TOP PKR ON 7-5/8" CSG, CIRC CSG @ 8 BPM 2000 PSI, RIH W/LINER, MU CMT HEAD, STAB INTO 7" LINER TOP @ 9219', TEST TO 1500#, CIRC CSG VOL, BATCH MIX CMT, CMT 7-5/8" LINER W/108 BBLS LEAD CMT, FOLLOWED BY 19 BBLS TAIL CMT RIH W/6" BIT TO CLN OUT 7" LNR MW:10.0 KC1 DISPLACE CMT W/RIG PUMP TO 7" SEAL ASSEMB, STING INTO TIE-BACK, PRESSURE UP TO SET HGR, L/D CMT EQUIP, POH, L/D DP, MU 6" BIT & DC'S, RIH, PICKING UP 3-1/2" DP, TAG UP ON PLUGS, CMT, & LNDG COLLAR F/9137' TO 9218', CBU, POH, L/D BIT , M/U BIT & 7" SCRAPER, RIH W/3-1/2" DP TO CLEAN OUT 7" LINER. RIH W/4-1/2" CR COMP MW:10.0 KC1 CLEAN CMT STRINGERS INSIDE 7" LINER F/9215'-9275', RIOH W/3-1/2" DP, CLN OUT LINER TO PBTD @ 11360', TEST CSG, CLEAN PITS, HAUL GOOD MUD TO MUD PLANT, TAKE ON SEAWATER, REV CIRC WELL TO CLEAN FILTERED SEAWATER, ADD INHIBITOR, TEST CSG TO 3500 PSI OK, POH, L/D DP, L/D DC'S, CLEAR FLOOR, PULL WEAR RING, R/U TORQUE TURN, M/U CR COMP & RIH RELEASED RIG FOR MOVE TO A-PAD MW:10.0 KC1 RIH W/ 4-1/2" CR COMP., TEST TO 5000 PSI, LAND TBG, RILDS, ATTEMPT TO PRESSURE UP TO SET PKR, DP TO TBG XO LEAKE, WASHED OUT THREADS IN XO, BACKOUT & L/D LNDG JT, R/D TORQUE TURN, INSTALL TWC, N/D BOPE N/U ADAPTOR FLANGE & TREE, TEST TO 5000 PSI, OK, PULL TWC, PUMP 20 BBLS DIESEL DOWN ANNULUS, U-TUBE DIESEL, SET BPV, SECURE TREE RELEASE RIG @ 24:00 11/28 FOR MOVE TO A-PAD SIGNATURE: (drilling superintendent) DATE: *SPb,,RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/S-TA 500292082901 NORTH SLOPE COMPUTATION DATE: 12/ 1/92 DATE OF SURVEY: 11/22/92 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-20089 KELLY BUSHING ELEV. = 67.30 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 9470 7479,00 7411,70 43 42 S 5,50 E ,00 4866,00S 1446.00E 9504 7504,03 7436,73 41 56 S 9,75 E 9,93 4888,97S 1449,06E 9598 7574,61 7507,31 40 50 S 11,68 E 1,78 4950,08S 1460,62E 9691 7645,27 7577,97 40 40 S 16,07 E 3,08 5009,.17S 1475,21E 9785 7717,91 7650,61 37 36 S 21,83 E 5,08 5065,04S 1494,29E 5068.19 5090.84 5152.26 5212.80 5271.83 9877 7792,27 7724,97 35 4 S 25,30 E 3.53 5115,17S 1516,09E 9969 7869.44 7802.14 31 45 S 29,13 E 4,25 5160,46S 1539,30E 10063 7949,27 7881,97 30 25 S 33,41 E 2,77 5201,60S 1564,25E 10154 8029,27 7961.98 28 13 S 38,59 E 3.66 5237,96S 1590.58E 10247 8112.35 8045,05 25 16 S 43,17 E 3,87 5269,65S 1617,90E 5326.38 5376.85 5424.01 5467.14 5506.20 10340 8197.07 8129.77 23 0 S 48.81 E 3.47 5296.06S 1645.12E 10434 8283.81 8216.51 22 49 S 55.20 E 2.65 5318.61S 1673.97E 10525 8367.71 8300.41 22 45 S 61.41 E 2.64 5337.10S 1703.91E 10618 8453.34 8386.04 22 30 S 61.17 E .28 5354.24S 1735.21E 10711 8539.00 8471.71 22 25 S 57.90 E 1.35 5372.20S 1765.73E 5540,27 5571,25 5598,79 5625,52 5652,74 10806 8626,74 8559,44 22 30 S 56,51 E ,57 5391,84S 1796.22E 10897 8711,49 8644.19 22 19 S 57,04 E ,29 5410,99S 1825,46E 10991 8797,80 8730,50 22 20 S 57,73 E ,28 5430,10S 1855,32E 11085 8884,92 8817.62 22 12 S 58,01 E ,18 5449,07S 1885,53E 11179 8971,71 8904,41 22 6 S 58,16 E ,12 5467,76S 1915.53E 5681,55 5709,47 5737,56 5765,64 5793,38 11271 9057,07 8989.77 21 37 S 57,82 E ,53 5485,91S 1944,58E 11364 9144,51 9077,21 21 5 S 57,04 E ,65 5504,32S 1973.40E 11395 9173,44 9106,14 21 2 S 56,83 E ,29 5510,40S 1982.74E 5820.30 5847.38 5856.26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD, HORIZONTAL DISPLACEMENT = 5856.26 FEET AT SOUTH 19 DEG. 47 MIN. EAST AT MD = 11395 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 160.21 DEG. 'SPE ,Y-SUN DRTLLZNG SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRTLLING PBU/S-TA 500292082901 NORTH SLOPE COMPUTATION DATE: 12/ 1/92 DATE OF SURVEY: 11/22/92 JOB NUMBER: AK-EZ-20089 KELLY BUSHING ELEV. = 67.30 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9470 7479,00 7411,70 4866.00 S 1446.00 E 1991.00 10470 8316.19 8248.89 5326.38 S 1685.15 E 2153.81 162.81 11395 9173.44 9106.14 5510,40 S 1982,74 E 2222.54 68.73 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. "SPE .... Y-SUN DRTLLTNG SERVTCES ANCHORAGE ALASKA PAGE PRUDHOE BAY PBU/S-TA 500292082901 NORTH SLOPE COMPUTATZON DRZLLZNG DATE' 12/ 1/92 DATE OF SURVEY' 11/22/92 JOB NUMBER" AK-EZ-20089 KELLY BUSHZNG ELEV. = 67.30 OPERATOR' BP EXPLORATZON FT. ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASD DEPTH TRUE SUB-SEA TOTAL VERTZCAL VERTZCAL RECTANGULAR COORDZNATES MD-TVD VERTZCAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DZFFERENCE CORRECTZON 9470 9588 9720 9846 7479.00 7411.70 4866.00 S 1446.00 E 1991,00 7567.30 7500,00 4943,89 S 1459,34 E 2021,23 30.23 7667,30 7600.00 5026.92 S 1480,64 E 2052.98 31.74 7767.30 7700.00 5098.98 S 1508.66 E 2079.43 26.45 9967 10083 10197 10308 10416 7867.30 7800.00 5159.28 S 1538,66 E 2100.03 20.60 7967.30 7900.00 5210.26 S 1570.11 E 2116.62 16.59 8067.30 8000.00 5253,21 S 1603,20 E 2130.40 13.78 8167.30 8100.00 5287,39 S 1635,59 E 2140,96 10,56 8267.30 8200.00 5314.64 S 1668.26 E 2149.66 8.70 10525 10633 10741 1085O 10958 8367,30 8300.00 5337.01 S 1703.76 E 2158.13 8.47 8467,30 8400,00 5357.03 S 1740.28 E 2166.45 8.33 8567,30 8500,00 5378.40 S 1775.62 E 2174.65 8.20 8667,30 8600.00 5401.11 S 1810.24 E 2182.88 8.23 8767,30 8700.00 5423,41 S 1844.72 E 2190.99 8.10 11066 11174 11282 11389 11395 8867,30 8800.00 5445,26 S 1879.43 E 2199,07 8.08 8967,30 8900.00 5466,81 S 1914,01 E 2207.05 7.98 9067.30 9000.00 5488,07 S 1948.01 E 2214.79 7.74 9167.30 9100.00 5509.11 S 1980.76 E 2222.10 7.31 9173.44 9106.14 5510.40 S 1982.74 E 2222.54 .44 THE CALCULATZON PROCEDURES USE A LZNEAR ZNTERPOLATZON BETWEEN THE NEAREST 20 FOOT ND (FROM MZNZMUM CURVATURE') POZNTS MICROFILMED - P~E *********** SUR~Y PROGRAM *********** COMF'AHY PRUDHOE BAY DRILLING WELL N~M£ S-O?A LOCATION i PRUDHOE BAY LOCATI~ 2 NSB~ ALASEA MAGNETIC DECLINA.?D~4 29,85 DAT~: 11-N~-~ WELL NUMBER 0 WELL HEAD LOCATION: LAT(N/-S) 0.00 AZIMUTH FEllM ROTARY TABLE TO TARGE IS TIE IN POINT(TIF') : MEASURED DEF'TH TRUE VERT DEPTH INCLINATION AZIMUTH LATITUDE(H/-S) D~'ARTL~E(E/-W) 9470,00 7479.00 43,72 174,53 -4B~,O0 1446,00 DEP(E/-W) 128,65 S-07A MEASURED INT~AL U~TICAL DEPTH DEPTH ft ft ft 9470,00 0,0 7479.00 9707.~ 237,2 7655.33, 9739.20 32,0 7679.89 9770.63 3i.4 77(~.37 980!,30 30,7 7728.61 ******:******* ANADRILL ************** SURVEY CALCULATIONS **~*** MINiMk~ CURVATURE METHOD ******* TARGET ~ATION AZI~]TH LATITUDE SECTION INCLN, N/-S ft deg deg ft 4168,41 43,72 174~53 -4866,00 4290,07 40.46 16i,94 -5021,i0 4307,42 39,22 159,61 -5040,45 4324,43 38,43 158.25 -5056,83 4340,68 37,17 156,&~ -5076,21 D~ARTURE DISPLACEM~NT at E/-W ft ft 1446.00 5076.31 1477,75 5234.04 1464,49 5254,50 149i,57 5274.14 !498,74 5292,84 AZIMUTH de~ 163,45 163.60 163,59 163.57 163.55 DLS deg/ IOOf: 0,00 3,81 6,06 3,69 4.95 98Jl.49 9861.39 9892.6,-i %25.23 9956.43 30,2 7752,76 29.9 7776.9! 31,4 7802,57 · ~,4 7829,38 3i,2 7855,54 4356,88 ~.,55 156,28 -50~,83 4372,62 35,74 154,63 -5108,87 4389,08 34,88 152.86 -5125,17 4405,72 33.44 151,~2 -5141,29 4421,36 ~,54 151,37 -5156.24 1505.94 5310.61 163.53 1513.26 5326,27 163,50 1521,29 5346.18 163,47 1529,72 5364.04 163,43 1537,78 5360.67 14~,~ 2,37 4,22 4,23 4,74 3,04 oOAX 17 10017,47 I0(W7,11 10078,85 10108,89 29.7 7880.60 31,3 7907.63 29,6 7933.14 31.7 796O,53 30.0 7986.59 4435.96 31,20 149,05 -5169,87 4451,09 ~),74 i46.29 -5183.63 4465,43 30,54 145.7i -5196,29 4480,63 30,19 !44,1i -52C8,42 4495,28 29,47 142,51 -522i,40 1545,58 5395,96 163,36 1553,~ 54!1,54 163,31 1562,18 5426,04 163,27 1571,40 5441,26 163,21 1580.33 5455,32 163,16 6,11 1,95 4,46 2,78 3,56 10140,59 10170,75 10202,20 10232.66 10263,98 31,7 8014,28 30,2 8040,83 31,5 80&),75 30,5 8096,06 31,3 8124,40 4510.2_7 26.75 141,97 -5233,60 4524,27 27,~ 138,92 -5244,62 4538,53 26~97 I~..36 -5255,50 4551,87 2a,60 136,23 -5265,41 4565.11 24.82 134,85 -5274,94 1589.77 5469,72 163.t0 1596,87 5462,92 163.05 1608,44 5496,12 162,98 1617.56 5508,26 162.92 1626,93 5520,i3 162.86 2,41 5.60 2,99 5,46 3,10 10293,96 10325,29 10357.01 10367,64 104i9,38 30.0 8151,73 31.3 8i80,47 31,7 8209.64 30.8 8238,03 31,5 8267,08 4577,37 23.69 133,38 -5283,51 4589,82 23.28 132,14 -5291,99 4602,26 22,95 128,~? -5300,08 46!4.~3 22,99 I27.69 -5307,55 4626,55 22,8i 124,33 -5314,76 1635,76 5530,93 162,80 1644,93 554i.74 162,73 1654,39 5552,29 162,66 1&~.3,83 5562,23 162,59 1673,75 5572,08 162,52 4,30 2,03 4.03 1,65 4,19 1045i.15 10462,52 10543,82 10636,07 10727,07 3t,8 8296,37 31.4 8325,~) 6i,3 838i,88 92,2 8467,07 91,0 8551.17 4638,81 22.79 123,18 -5321,60 4650.86 22,68 121.26 -5328,06 4674,07 22.62 115,54 -5339.28 4706.76 22,53 !18.94 -5355,48 4743.12 22,38 121,26 -5372.90 168J,96 5581.69 162,44 1694,24 5590,95 162,36 1714,98 56.07.95 162,19 1746,45 5533,05 161,94 1776.52 5658,98 161,70 1,40 2,~ 3,59 1,42 0.~ PROJECTED SURVEY 10645,00 117,9 8660,21 4787.67 22,40 121.5~ -5396.23 1814,90 5693.25 161,41 0,02 BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/11/93 T~ 84215 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-08 l~'~/ PRODUCTION LOG 01/02/93 ~1 C-02~-~ SPINNER 01/02/93 ~1 F-08 ~'~ STATIC 01/02/93 #! F-15~/,/~ STATIC 01/04/93 #1 F-47 STATIC 01/04/93 #1 S-03~/-~ PRODUCTION LOG 01/01/93 #1 S-07A~$~ PRODUCTION LOG 01/01/93 #1 [S-34I I CCL 01/03/93 #1 S-34I~z' ~ SBA 01/03/93 #1 9200.00- 9655.00 ATLAS 5 " 9805.00-10136.00 ATLAS 5 " 10900.00-11241.00 ATLAS 5 " 9150.00- 9745.00 ATLAS 5 " 8500.00- 9381.00 ATLAS 5 " 11700.00-12101.00 ATLAS 2/5" 1980.00-11210.00 ATLAS 2/5" 9850.00-10400.00 ATLAS 5 " 9500.00-10540.00 ATLAS 5 " Information Control Well Records JAN 2 6 1993 Alaska 0il & Gas Cons. Commlss~o.~1 Anchorage AOGCC GEOLOGICAL blATERiALS iNVENTORY LIST COMPLET!O~ OATE I ! I~, / ~ CO, CO~TACT check off or list data as it is received.*list received date for 407. if not drilling history survev well tests cored core analysis d intervals uired list as NR core descri ital data i i , ' , ~. ~vr,~ ' i RUN INTERVALS sCALE ~0. [to the nearest i IIIn I I mil ~1 I I Illl ~ · Ill Il I Ill 91 ~h J T~~ .... t ..... 0 ~ t iq" .. , , ,,, ,, ............. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/16/92 T# 84182 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. B-04 ~,)1- PRODUCTION LOG 12/10/92 G-10 ~/"~ PRODUCTION LOG 12/09/92 12/09/92 S-07A ~ PFC 10300.00-10639.00 ATLAS 5 " 8400.00-10000-00 ATLAS 2/5" 9950.00-11300.00 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# 84163 BP/ PBU OH TAPE Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) S-07A OH/DLL FIN 11/23/92 #1 10600.00-11420.00 1600BPI API#500292082901 9194->TP# If you have any 564-4004. ATLAS REF#5762.01 Information Control Well Records ECEIYED DEC 2 2 199~ Alaska 0il & G~s Cons. Commission Anchorage 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 T9 84115 BP/ PBU OH/CH LOGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at A-23 ~2'%~PRODUCTION LOG 11/18/92 #1 B-07~?-~'' PRODUCTION LOG 11/20/92 #1 C-38~-b~ PRODUCTION LOG 11/18/92 91 M-32~Z-~ CCL/PERFj 11/21/92 #1 R-25~Z-~3 CCL/P~ ~ 11/23/92 #1 IR-301Z_$~PFC/CTa d~er~11/20/92 #1 R-30 CCL,~:~[i:~F~ ~ 11/23/92 #1 /S-07A ~BHCJ 11/23/92 ~1 %' ~S-07A~-~CNL/ 11/23/92 #1 · ~lS-07A-- D~ ~ 11/23/92 ~1 kS-07A SS TVD / 11/23/92 #1 S-36I ~'(~PFC ~(~¢k 11/22/92 ~1 x-03 ff.f$ cc~ j 11/21/92 #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 ' RECEIVED DEC 1 8 1992 Alaska 0ii & 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 DATE: 11/16/92 T# 84059 BP LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-12 g,-I'~ PRODUCTION LOG 11/07/92 #1/' A-18~;-Io8 CCL (CA~,~ ¢~+~,~1/10/92 #1~ B-21~-I~ PFC/~(~) 11/_Q9/92 ~1~ R-29~-~/ PFC/~ (~R~) 11/10/92 ~1~ R-30 ~-~ PRODUCTION LOG _,11/08/92 %1 ~ ........... (f~$A 11/11/92 ~1 ~ 8750.00- 9250.00 ATLAS 8100.00- 9270.00 ATLAS 9400.00- 9824.00 ATLAS 8500.00- 9330.00 ATLAS 10140.00-10320.00 ATLAS 11100.00-11550.00 ATLAS 9620.00-- 9720.00 ATLAS ~ 5 " 5 " 5 " 5 " 5 " 5 " Information Control Well Records ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 9950'1-3192 PHONIC: (907) 279-1433 TELECOPY: (907) 275-7542 October 5, 1992 Michael Zanghi Workover Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit S-O7A BP Exploration (Alaska), Inc. Permit No. 92-98 Sur. Loc. 1639'SNL, 1415'EWL, Sec. 35, T12N, R12E, UM Btmnhole Loc. 1872'SNL, 1940'WEL, Sec. 2, TllN, R12E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W~ Johnsto~ Chairman'. BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,~.-.., STATE OF ALASKA ALASi' )IL AND GAS CONSERVATION lia. Type of workRe.EntryDrill [][] DeepenRedrill~i ~. Name of Operator .BP Exploration 3. Address PERMIT TO DRILL 20 AAC 25.005 ¢IMISSION , lb. Type of well. Exploratory[] Stratigraphic Test [] Service [] Development Gas [] Single Zone [] P. O. Box 196612. Anchorage. Alaska 99519-6612 4. Location of well at surface 1639'SNL, 1415'EWL, SEC. 35, T12N, R12E At top of productive interval 1751'SNL, 2090' WEL, SEC. 2, T11N, R12E At total depth 1872'SNL, 1940' WEL, SEC. 2, T11N, R12E 12. Distance to nearest ~13. Distance to nearest well property line I ADL 28257/1872 feet S-30/1300'@ 7412'TVD feet 16. To be completed for deviated wells Kickoff depth 9,~zo~eet Maximum hole angle , 6 0 5. Datum Elevation (DF or KB) KBE = 67.3feet MD 9300 10400' 6. Property Designation. ADL 28260 7. Unit or property Name Prudhoe Bay Unit 8. Casing program size Length 11o0 1014' Deepen 8. Well number S-07A (32-02-11-12) Specifications Hole Casing Weight I Grade Coupling I 8-1/2" 7" 26t/ I L-80 NSCC 8-1/2" 7" FOX 9. To be completed for Redrill, Re-entry, and Present well condition summary Total depth: measured true vertical measured true vertical Effective depth: 9. Approximate spud date 10/5/92 Development Oil [] Multiple Zone [] 4. Number of acres in property 2560 0. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool 1 1. Type Bond(r~e 20 ^AC 2S.025 Number 2S 100302630-277 Amount $200,000.00 5. Proposed depth (MD ,,nd'rrb) 11414'MD/9149'TVCfeet 17. Anticipated pressure (se,, 20 AAC 25.035 (e)(2)) Maximum sudace 3330psig At total depth (TVD) Setting Depth Top Bottom TVD M D TVD 7290"- 10400' 8210' 8210' 11414' 9149' Operations. Plugs (measured) Junk (measured) 11817feet BKB 9149 feet 11559 feet BKB 8972 feet Quantity of cement (include stage data) 495 cuft Class "G" E, EL.r'IV P SEP 2, 1992 Alaska 0il & 6as 0ohs. Commission Anchorage Casing Length Structural Conductor 110' Surface 2701' Intermediate 10872' Production Liner 1184' Perforation depth: measured Size Cemented Measured depth True Vertical depth 8cuyd 138' I 8' 3720 cuft 2729' 26~!8' 1695 cuft 10900' 84~9' 20" 13-3/8" 9 -5/8" 7" 484 cuft 11140'-11213', 11228'-11295', 11310'-11352' true vertical 8607'-8760' (ss, three intervals) 10633'-11817' 8305'-9150' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l~l Drilling fluid program [] Time vs depth pict [] Refraction analysis• Seabed report• 20 AAC 25.050 requirementsF-I 21. I hereby carte, t~ie foregoing/,~,,~,~/~,,~:~_~is true and correct to the best of my knowledge ~ Signed /)" Title Workover Engineer Supervisor Date L/' Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~';2L-. ~" ~ ,. 150- 0..2, '7 - ~ o ¢..~ ?- o I I _,,-//~ '--.~-'-,~";~,~ , Jfor other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required [] Yes ~] No Hydrogen sulfide measures [] Yes ,~_ No Directional survey requ red "~ Yes [] No Required working pressure for BOPE r-12M; 1-13M; ,J~5M; I'-]10M; F']151~1; '?ther: Original Signed By by order of I Approved by David W. Johnston Commissioner [ne commission Date /'C/)-~,,~-~c.,~- Form 10-401 Rev. 12-1-85 Submit in triplicate S-07A REDRILL PROPOSED DRILLING AND COMPLETION PROGRAM OBJECTIVE: The objective of the S-07A Redrill is gas shut-off. Well S-07 has been shut-in since January 1992 due to Iow oil rate at high total gas to liquids ratio. The current wellbore has been unsuccessfully acidized, squeezed, and fracced. The proposed redrill will more effectively drain the reserves in the area, and will increase throughput in the S-06i pattern. The objectives of the S-07A redrill are to plug and abandon the original pedorations, pull the 3-1/2" 9.3# L-80 tubing, cut and pull the 7" tieback casing at 9800' MD, set a 9-5/8" bridge plug at 9700' MD, squeeze the leaking 9-5/8" DV tool and drill out, section mill a 60' window in the 9-5/8" casing, lay a cement plug across the section, kickoff and drill a new 8-1/2" hole +/- 1000' from the original wellbore, run open hole logs, run and cement a 7" 26# 13CR / L-80 liner, run a 7-5/8" casing patch across the DV tool at 2632' MD, recomplete with 4-1/2" 13CR tubing and 7" packer, and perforate the pay zone post-rig. Rig 2ES will be making a pad to pad move from DS 18-16A to well S-07A. The S-07A redrill is estimated to start up on 10/1/92. It will take approximately 19 days (7 days to P&A, squeeze and sidetrack, 7 days to drill and Icg, and 5 days to complete). CURRENT STATUS' Well S-07 is currently shut-in. The S-07 was drilled in 1982 and was worked-over in 1988. The current wellbore has 13-3/8" surface casing set at 2729' MD /-2574 ss TVD, 9-5/8" production casing set just above the top of the Sag River at 10,900' MD / -8432' ss TVD, a 7" production liner at total depth of 11,817' MD /-9083' ss TVD, and a 7" casing tieback to surface. The well is currently completed with 3-1/2" L-80 tubing and a 7" packer. PROPOSED PLUGBACK PROGRAM' (Operation to be Approved Under Sundry Notice) Rig up coiled tubing unit. Lay a cement plug from current PBTD of 11,194' MD (4' below the bottom perf) to at least 100' above the upper perforation (upper perforation @ 11,140' MD -- cement top to be no deeper than 11,040' MD). RU slickline unit. RIH and confirm cement top. RIH with jet cutter and cut the 3-1/2" tubing at 10,000' MD. Circulate well over to seawater and freeze protect well to 2000'. Set 4" BPV. When the rig moves on location, the tubing will be pulled from 10,000' MD. The 7" casing will be cut and removed from 9800' MD. A 9-5/8" bridge plug will be run and set and weight tested @ 9700' MD. The DV tool on the 9-5/8" will be squeezed and tested EEEIVED SEP 2 4 1992_ Alaska 0il & Gas Cons. Commission Anchorage PROPOSED DRILLING .~.,~D COMPLETION PROGRAM S-O7A REDRILL Paae #2 to 1000 psi. After milling the window from 9470' - 9530', a kick-off plug will be set with the base of the plug at 9630' MD. PROPOSED DRILLING PROGRAM: (Operations to be Approved Under Drilling Permit) The milling/drilling fluid program will consist of a 9.7 - 10 ppg water based mud in the 8- 1/2" hole. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. The plan consists of pulling the 3-1/2" tubing and milling an 60' section in the 9-5/8" casing from 9470'- 9530' MD. A cement kick-off plug will be set in the 9-5/8" casing across the window area from 9270'- 9630' MD. An 8-1/2" hole will be directionally drilled to a new target +/- 1000' northeast of the present well. A 7" chrome / L-80 liner will be run from TD to 150' inside the 9-5/8" casing kickoff point and cemented with Class G cement. The liner will be cleaned out to the 7" landing collar. The mud will be changed over to filtered and inhibited seawater completion fluid. The 9-5/8" casing, 7" liner and lap will be tested to 3500 psi. A 4-1/2" 13CR tubing completion will be run with the production packer in the 7" casing. A subsurface safety valve with dual control lines will be located about 100' below the base of permafrost. The well will be freeze protected with diesel. The production packer will be set and tested. A production tree will be installed and tested. The well will be perforated through tubing after the rig leaves. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. RECEIVED S E P 2 4 7992 Alaska Oil & Gas Cons. Commission Anchorage PROPOSED DRILLING, .,,ID COMPLETION PROGRAM S-07A REDRILL Page #3 APl NO. of S-07:50-029-20829-00 LOCATION' Surface' Target: BHL: 1639' FNL, 1415' FWL, Sec. 35, T12N, R12E 1751' FNL, 2090' FEL, Sec. 2, T11N, R12E @ 8675' ss TVD 1872' FNL, 1940' FEL, Sec. 2, T11N, R12E @ 9149' ss TVD ESTIMATED START: OPR. DAYS TO COMPLETE: CONTRACTOR; 5 October, 1992 19 (7 days prep & mill, 7 days drill, 5 days complete) Nabors rig 2ES WELLBORE: Item 20" CASING 13-3/8" CASING KOP - 9-5/8" CASING 8-1/2" HOLE - TOTAL DEPTH TVDss MD(BKB) Mud Wt. 110' 110' N/A 2574' 2729' N/A 7412' 9470' 9.7 9149' 11414' 10 LOGGING PROGRAM: 8-1/2" Hole: Resisitivity / Gamma Ray / SP / Sonic / Neutron LINER DETAILS: CASING 7" 26# 13CR-80 FOX 7" 26# L-80 NSCC CEMENT Measured Depth: Basis' DEPTH BURST 10400' - 11414' MD ..8.1-60~psi ' (8210' - 9149' ss TVD).~?y,~, 9300' - 10400' MD (7290' - 8210' ssTVD) COLLAPSE TENSILE ~ ~-76' klbs psi .~'~6' klbs CALCULATIONS' 7" LINER' ~~..;¢'~ 9300' (Hanger) - 11414' (Shoe) ~'~~ 1.40 X Ann. Vol. (11414' to 9470') + 150 cuft for lap & excess Total Cement Vol' 495 cuft or 427 sxs of Class G blend @ 1.16 Cu ft/Sk RECEIVED S E P 2 4 1992 Alaska Oil & Gas Cons. Commission Anchorage PROPOSED DRILLING, ,,~ID COMPLETION PROGRAM S-07A REDRIL[,, Paoe #4 -- TUBING DETAILS: 4-1/2" 12.6# 13CR-80 NSCT (0'- 10,500') MUD PROGRAM: DEPTH DENSITY PV YP INT 10MIN FL (MD) (PPG) (CP) (#/FT) GEL GEL c¢/30min OIL SOLIDS MUD (%) (%) TYPE 9470' 9.7 10 10 5 7 8 to to to to to to to 11,414' 10 16 15 10 15 5 (-7412' ss TVD - 9149' ss TVD) 0 5 Water to to Base 0 7 Mud MUD SOLIDS CONTROL (NABORS RIG NO. 2ES) EQUIPMENT: 2 - Continental Emsco Fl000 Mud Pumps 1 - Derrick FIoLine Cleaner Shale Shaker 1 - Mud Cleaner 1 - DRECOGas Buster 1 - Pioneer Sidewinder Mud Hopper 1 - 5 HP Flash Mixer Agitator 3 - Abcor 10 HP Agitators 1 - 50 bbl. Trip Tank 1 - Recording frilling fluid pit level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console S E P 2 4 7992 A.JaSJ(a 0JJ & Gas Cons. Commissior~ ;Anchorage LAND DIRECTIONAL DRILLING, ] .... Corporate Office ~1111 ~ast 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 3~9-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING W~I1 ......... : S-7A (P1) Field ........ ~ PRUDHOE BAY S-PAD Computat£on..: RINIMUM CURVATURE LEGAL DESCRIPTION Surface ...... ~ 1639 FNL 1415 FWL S35 T12N R12E UM Tie-in ....... : 1225 FNL 2424 FEL $02 TllN R12E UM Target ....... ~ 1751 FNL 2090 FEL S02 TllN R12E UM BHL .......... ~ 1872 FNL 1940 FWL $02 TllN R!2E UM Prepared ..... : 08/20/92 Section at...: S,51.35,H KB elevation.~ 67.30 X ASP ZONE 4 ¥ 619577.00 5979855.00 621100.82 5975013.53 621444.00 5974493.00 621596.54 59?4375.02 PROPOSED WELL PROFILE STATION IDENT I FI CATI ON TIE-IN E~D DROP & TURN ~.~EAS INCLN VERT-DEPTH5 SECT DIRECTION REL-COORDI NATES DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD 100 9470 43.72 7479 74!2 4168 S 5.47 E 4866 S 14~6 E <TIE 9500 42.69 7501 7434 4183 S 6.38 E 4886 S 1448 E 4.0 9600 39.33 7577 7509 4230 S 9.69 E 4951 S 1457 E 4.0 9700 36.08 7656 7588 4277 S 13.50 E 5011 S 1469 E 4,0 9800 32.97 7738 7671 4323 $ 17.94 E 5066 S 1485 E 4.0 9900 30.04 7823 7756 4358 S 23.17 E 5114 S 1503 E 4.0 10000 27.36 7911 7844 4411 S 29.36 E 5158 $ 1524 E 4.0 10100 25.01 8001 7934 4453 S 36.70 E 5195 S 15~8 E 4.0 10200 23.08 8092 8025 4493 $ 45.31 E 5225 S 1575 E 4.0 10263 22.14 8150 8083 4517 S 51.35 E 5241 S 1592 E 4.0 SAG RIVER SHUBLIK TOP £ADLEROCHIT TARGET ZONE 3 10700 22.14 8555 8488 4682 S 51.35 E 5344 S 1721 E 0.0 10741 22.14 8593 8526 4698 S 51.35 E 5354 S 1733 E 0.0 10832 22.!4 8677 8610 4732 S 51.35 E 5375 S 1760 E 0.0 10902 22.14 8742 8675 4758 S 51.35 E 5392 S 1781 E 0.0 11005 22.14 8837 8770 4797 S 51.35 E 5416 S 1811 E 0.0 ZONE 2 OOWC TD 11075 22.!4 8902 8835 4823 S 51.35 E 5432 S 1832 E 0.0 11264 22.14 907~. 90!0 4894 S 51.35 E 5477 S 1887 E 0.0 11414 22.i4 9216 9149 4951 S 51.35 E 5512 S 1931 E 0.0 RE£EIYED SEP 199 . Alaska Oil & Gas Co~s. Anchorage "~;IDD (c)92 P.~OTA B1.3.' 8:5D AM 2) A) TIE-IN D) TD PRUDHOE BAY DR ILL I NG ~ i)KB SECTN INCLN 9470 7479 4168 l~l~ BlS0 4517 ~.14 IDg~ B742 4~8 ~.14 11414 8218 4951 ~14 S-TA (P1) VERTICAL SECTION VIE}/ TYD Scale,, 1 tnch" 300 f~et O,p Scala., I ~nch ~ 300 f~t ~[P 2 4 1992 Dra,n ..... ~ DB/ZD/g2 ~bS~a.Oil& Gas Cons. bo ~issJo~ ~reat L~nd Directional I ) --l-i, -- B '! I I i I i ) i i I j I I 4050 4200 43S3 4500 4550 S~ct} PRODHOE BAY DRILLING S-TA (P1) PLAN VIEW DECLINATION., 29. B5 E SCALE ....... ~ 1 inch = 1ODD feg~ DRAVN ....... , OB/ZO/gZ E P 2 4 1992 Alaska Oil & Gas Cons. borrln ~remt Lond Dlrectlonol Drilli~ . ) F::xgO 0 5O0 ID00 1500 <- ~ST I EAST ~o00 3000 l 2500 4000 4500 5000 b'SOO ssion NABORS 2ES It°, 515' 4.95' 4.:~7' 4.85' 1.68' 1.88' 1.50' 2.17' 1.3 5/8" 5,000 psi Stack .. . KB TO BF r ~ RKB1 DRIP PAN RI I FL©~ HYDRIL j 12.19' PIPE RAM BLIND RAM MUD CROSS PIPE RAM I CROSS I ! ~1TBG SPOOL I ! ~ASE FLG~ 1.42' GROUND LEVEL R 16.37' 18.25' 22.20' I24.68' 26.85' S E P 2 4 1992 ~Jask_a .OJJ .& Gas Cons. L;ommisslon 28.25' s E P ~4 ~99~ Alaska 0il & Gas Cons. Gornt-niss~On ~Anchorage ~-~%07 PLUGBACK PROCEDU[ Procedure Outline: (Refer to attached wellbore schematic) 10. 11. 12. 13. 1. Notify an AOGCC representative prior to commencing operations. 2. Rig up coiled tubing unit. 3. RIH with coil tubing circulating seawater. Lay a cement plug from _+11,194' MD to 11,040' MD (4' below the bottom perforation that has not been squeezed to at least 100' above the top perforation). 4. RU slickline unit. RIH and confirm cement top at least 100' above top perforations. Note- Tag to be witnessed by AOGCC representative. 5. RU E-line and make a tubing cut at +/-10,000' MD based on completion tubing tally. 6. Circulate well over to seawater and freeze protect well to 2000'. 7. Bleed tubing, inner annulus, and outer annulus to 0 psi. 8. Set 4" BPV and prepare Pad for RWO. 9. MIRU dg. Pull BPV. Circulate out freeze protection. Pull 3-1/2" tubing. RIH w/a 7" mechanical cutter and cut the 7" tieback casing at 9800' MD. POOH w/ 7" casing tieback. RIH with a 9-5/8" bridge plug and set at 9700' MD. Test w/ 15,000#'s of pipe weight. Squeeze 9-5/8" D V packer at 2632' MD and test to 1000 psi. A kick-off plug will be set after milling the window. The base of this kick-off cement plug will be at +/- 9630' MD (100' below the window). RECEIV£D Alaska 011 & Gas Cons. Commission Anchorage ..,enerai Purpose Worksheet '~t~'~' ~-o7 PI~~¢ iFile ' ,,.j1 ' IPage No. Of i AR3B-6287 s EP ~ 4 199?- Alaska 0il .& Gas Gins, OomCss~°~ \ ~ .... -- I ~ ~ 7"c~s;~0 c~ ~ ~ ~%~' N~ ~L ~/1 / .... TREE: 4' ClW WELLHEAD: 13 3/8' FMC ACTUATOR: AXELSON [ ii i KB. ELEV- 67.2-7' 8F. ELEV - 38.75' 9 5/8' DV PKR 632' 1~ ~'8" 72'/'~'I j L-80, BTRS. 2729' KOP: 1400' I MAX ANGLE: 46' @ 11,625' 7', 26#Itt. L-80 U4S CASING 3 1/2', 9.3#/tt, L-80, EUESRD IPC TBG TUBING ID: 2.992' CAPACITY: .0087 BBL/FT ToP OF ~ ~ 1 0 ' ~ 3 ~ ~ I BAKER SEAL ASSY L-80, BTRS PERFORATION SUMMAR~ REF LOG: SWS. BHCS 11,140- 11,190' 11,190- 11,216' 11,228 - 11,295' 11,310- 11,352' 11-2-82 OPEN/SOlD OPEN/7-10-gl SQZD/7-7-gl SQZEV 4-7-91 SQZD/4-7-91 PBTD ;"", 26 #Itt; L-80, BTRS ( OTIS 'XDB' )( 2.750' ID) 1 995' GAS LIFT MANDRELS (OTIS WI RA LATCHI No_ MD(BKB1 'FVD=3_ 5 3293' 3022' 4 6451' 5259' 3 8821' 6938' 2 10,212' 7940' 1 10,401' 8074' SLIDING SLEEVE I 1 31/2' OTiS 'xA' 10,464' (2.750' MIN ID) 7' SBR / PKR TIW HP-BP 1 0. (2.992' MIN ID) __ 3 1/2' OTIS X NIPPLE (2.750- M~N ~O) 1 0,572' -- 3 1/2' OTIS X NIPPLE (2.750' MIN ID) 1 0.604' 3 1/2' OTIS TBG TAIL I t 0,637'~ (2.992" MIN ID) ELMD TBG TAIL I 10,631 'l ~--'J 11,194' ELMD r-P E .^c sAN -B^cK w, 2o-4o B/'LWP' PROPPANT (CARB), 7-12-91. ~----' 11,258' CTM ~ UARKER JO,NT 111.306' I · '(Et. MD) , DATE 11-1o-82 8-29-88 5-2-91 7-14-91 REV. BY COMMENTS COMPLETION ..: CJS RWO RDC REPERF A. TEEL PR EFRAC/SAND-BACK/NEW 'Fi' DEPTH PRUDHOE BAy UNIT WELL; S-07 f32-02-11-12'~ APl NO: 50-029-20829_ _~EO 3~;T 12N; R~12E BP Exploration (Alaska) RE'¢EIVED EP 2 4 1992 & ~as Cons. Commission Anchorage S-07A Summery Pr¢cedur Procedure Outline' I . . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Pre-dg work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 3-1/2" tubing at 10,000' MD. Circulate well to seawater. Freeze protect. MIRU workover rig. Pull BPV. Test 9-5/8" casing packoff. Circulate freeze protect fluid from well. Set two-way check valve. ND tree. NU & test BOP's to 5000 psi. PU on 3-1/2" tubing. Pull and lay down tubing. RIH w/7" cutter and cut at 9800' MD. POOH and lay down 7" casing. RIH and set a 9-5/8" bridge plug at 9700' MD. RIH and squeeze the 9-5/8" casing leak at 2632' MD. Ddll out and test to 1000 psi. RIH with section mill and cut 60' window in the 9-5/8" casing from 9470'-9530' MD. Set a kick-off cement plug from 9270'-9630' MD. RIH w/steerable system and kickoff through the section. POOH. RIH with 8-1/2" packed assembly and drill to TD (_+ 11414' MD). Run open hole logs. Run and cement 7" 26# 13 CR / L-80 liner in the 8-1/2" hole w/+/- 150' of lap. Clean out liner to PBTD and test to 3500 psi. Displace well to seawater. Run 7-5/8" casing patch over the 9-5/8" leak at 2632' MD. Test to 3500 psi. RIH with 4-1/2" 13CR completion string w/7" packer. Space out, land completion, set packer. Test down tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test 4-1/16" 5M tree to 5000 psi with diesel. Pull two way check valve. Set BPV. Release dg. Perforate well post dg. Anticipated BHP: 7.9 ppg equivalent. Drilling Fluid: 9.7-10 ppg, Workover Fluid' 8.4 ppg. R'E ¢EiVED S E P 2 4 1992 Alaska OiJ & Gas Cons. Commission Anchorage TJ Page 1 9/22/92 ,~-'",, STATE OF ALASKA ALA~ .OIL AND GAS CONSERVATION COMMISSI' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ,xx Suspend ~ Operation Shutdown ~ Re-enter suspended well Alter casing ~ Repair well~ Plugging x x Time extension ~ Stimulate Change approved program ~ Pull tubing ~ Vadance Perforate ~ Other x Plugback, for Reddll 2. Name of Operator 5. Type of Well: 6. BP Exploration Development xx Exploratory ... 3. Address Stratigraphic ~ 7. P. 0. Box 196612, Anchorage, Alaska 99519-6612 Service ~ 4. Location of well at surface 8. 1639' SNL, 1416' EWL, SEC. 35, T12N, R12E, UM At top of productive interval 9. 2273' SNL, 2390' WEL, SEC. 02, T11N, R12E, UM At effective depth 10. 2678' SNL, 2452' WEL, SEC. 02, T11N, R12E, UM At total depth 11. 2865' SNL, 2478' WEL, SEC. 02, T11N, R12E, UM 12. present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11817 feet BKB 9149' feet 11559 feet BKB 8972 feet Plugs (measured) Junk (measured) Length Size Cemented Measured depth 110' 20" 8 cu yd 138 2701' 13-3/8" 3720 cu ft 2729' 10872' 9-5/8" 1695 cu ft 10900' 1184' 7" 484 cu ft measured 11140'-11213', 11228'-11295', 11310'-11352' 10633~11817' true vertical subsea 8607'-8760' (three intervals) Tubing (size, grade, and measured depth) 3-1/2", L-80 top @ 10529' with 3-1/2" tailpipe to 10637' Datum elevation (DF or KB) KBE = 67.27 AMSL feet Unit or Property name Prudhoe Bay Unit Well number S-07 (32-02-11-12) Permit number 82-155 APl number 50- 029-20829 Field/Pool Prudhoe Bay Fie/d/Oil Pool True vertical depth 138 2648' 8499' 8305~9150' RECEIVE Alaska 0il & Gas Cons. Coif Packers and SSSV (type and measured depth) 9-5/8" Baker SBR/packer @ 10529'; 3-1/2" SSSV @ 1995' Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 10/1/92 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended __ Service 17. , hereby ~ ~'~/ certify that the f regoing is true and correct to the best of my knowledge. Signed _ Title WorkoverEngineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Original $1gned By gavid W. Johnston missi0~ Approval commissioner Date/ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ' ' [~? thru8']' · 2. 3. 4. 5. 6. 7. 8. '[ 9' thru 10 [10 & 13] 12. ?// 13. (4) Cas9 ~.]i~ .... ~- 14. [14 thru 2 15. (5) BOPE 16. 17. 18. 19. 20. 21. [ 23 thru 24. 25. 26. 27. 28. Company YES Lease & Well ,~/~O~ --~2~tO' .~_~DZ NO RE~RKS Is permit fee attached ............................................... . .... Is well to be located in a defined pool .............................. . .... Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a cor~servation order needed ................... I s admi n i st rat i ve approval needed ..................... Is 1 ease ncrnber appropr i ate .......................................... Does well have a unique name & number ................................ Is conductor st r lng provided ......................................... Wil 1 surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will 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 wel]bore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. i 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 ~-ooc~psig ..... v Does choke manifold comply w/API RP-53 (May 84) ...................... A/7~F. Is presence of H2S gas probable ...................................... l~. /) CB) Other /£~_ ?/~E~/~ A 29. [~9 thru 31] 30. 31. ,/, (7) Contact /~J//?~ 32. (8) Add]. 33. 9eology' engineering' DWO MT?vl ~ RAD~_~j~-5z LAG rev 08/18/92 jo16.011 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 ncrnber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE . ,, remarks' 0 --~ '-'cZ ~-~0 ~ m m 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, informati~)n 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. S - 07A PRUDHOE BAY MICltOFILl 10600 Run 1' 23 - Nov - 1992 ACICNIDLLIGR 1420 ~~~L~~ R £ C F. IV E D ~~~~~ DEC 2 2 1992. Alaska Oil & Gas Oons. Oommlssion Tape Subfile ~ is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME:' API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN1 5762.01 JOHN DAHL S. MANESS OPEN HOLE S - 07A 500292082901 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 14-DEC-92 RUN2 M. COOK 35 12N 12E 1639 RUN3 1415 67.20 66.20 32.90 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 REMARKS: 9.625 9465.0 AC/CN/DLL/GR CIRCULATION STOPPED: 23:30 22-NOV-92 LOG TIED TO ORIGINAL WELL S-7 AT CASING POINT. DEPTHS ARE REFERENCED TO THE ORIGINAL R.K.B. ACOUSTIC REPEAT SECTION NOT AVAILABLE DUE TO HOLE CONDITIONS. TIGHT SPOTS IN WELL CAUSING SOME CYCLE SKIPPING IN SHALES AS WELL AS TOOL STICKING. NEUTRON & LATEROLOG STANDARD REPEAT SECTIONS NOT AVAILABLE DUE TO HOLE CONDITIONS. DOWN PASS AT APPROXIMATELY 130 FPM PRESENTED FOR REPEAT PASS. CNC RECORDED ON SANDSTONE MATRIX WITH 8.5" HOLE SIZE CORRECTION & CHISM FILTERING ACTIVE. $ RECEIVED DEC 2 2 1992. Alaska 011 & G~s Ce. ns, Commissio~ Anchorage FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS 2435 DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA depth shifted and clipped curves; 0.5000 BASELINE DEPTH 10599.0 10661.5 10688.0 10689.5 10699.5 10701.5 10703.0 10706.5 10723.5 10743.0 10746.0 10747.0 10753.0 10759.5 10760.0 10760.5 10771.5 10772.0 10773.5 10777.5 10782.0 10786.5 10793.5 10795.5 10799.5 10805.0 10813.0 10816.5 10838.5 10843.5 10844.0 10844.5 10846.5 10858.5 10933.0 10969.5 10987.5 11007.5 11033.0 11034.0 START DEPTH STOP DEPTH 10600.0 11356.5 10600.0 11420.0 10600.0 11363.0 10600.0 11388.5 GR (MEASURED DEPTH) DT 10599.0 10661.0 10689.5 10701.0 10747.5 10754.0 10760.0 10772.5 10777.5 10782.5 10794.5 10800.5 10847.0 10969.5 10988.0 11034.0 -- EQUIVALENT UNSHIFTED DEPTH NPHI LL3 LLD 10599.0 10599.0 10599.0 10688.0 10699.5 10707.5 10747.5 10747.5 10760.0 10760.0 10773.0 10774.5 10794.0 10817.0 10844.0 10843.5 10969.5 11033.0 10703.5 10724.0 10743.5 10747.5 10760.0 10772.0 10787.0 10796.0 10805.0 10813.0 10838.5 10844.0 10858.5 10933.0 11007.5 all runs merged; no case 11035.5 11040.0 11079.0 11100.5 11136.0 11193.5 11194.0 11251.0 11265.5 11266.0 11272.0 11273.0 11274.0 11284.5 11286.5 11288.5 11311.5 11312.0 11316.0 11332.5 11350.5 11351.0 11370.0 11455.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS 2435 DLL $ REMARKS: 11035.0 11040.0 11079.0 11100.5 11136.0 11136.0 11193.5 11194.0 11193.5 11194.0 11251.0 11265.0 11265.5 11271.5 11273.0 11273.5 11284.5 11286.5 11288.0 11311.0 11311.5 11316.0 11316.0 11332.0 11350.5 11350.5 11351.0 11370.0 11455.0 11455.0 11455.0 11455.0 RUN NO. PASS NO. MERGE TOP MERGE BASE 1 5 10600.0 11356.5 1 5 10600.0 11420.0 1 5 10600.0 11363.0 1 5 10600.0 11388.5 FUCT & NUCT WERE SHIFTED WITH NPHI. MTEM, TENS, & TEND WERE SHIFTED WITH LL3. SP WAS SHIFTED WITH LLD. CNC RECORDED ON SANDSTONE MATRIX WITH 8.5" HOLE SIZE CORRECTION & CHISM FILTERING NOT ACTIVE. $ CN : BP EXPLORATION WN : S - 07A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA (ALASKA) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 4 67 465 06 6 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 NPHI 2435 68 1 PU-S 4 6 FUCT 2435 68 1 CPS 4 7 NUCT 2435 68 1 CPS 4 8 LL3 DLL 68 1 OHMM 4 9 LLD DLL 68 1 OHMM 4 10 SP DLL 68 1 MV 4 11 MTEM DLL 68 1 DEGF 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 82 4 84 653 71 4 20 789 90 4 20 789 90 4 98 211 23 4 98 211 23 4 98 211 23 4 30 739 95 4 30 739 95 4 30 739 95 4 30 739 95 44 Tape File Start Depth = 11455.000000 Tape File End Depth = 10599.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20557 datums Tape Subfile: 2 236 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 5 0.2500 VENDOR TOOL CODE START DEPTH GR 10600.0 AC 10600.0 2435 10600.0 DLL 10600.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 11384.0 11448.0 11390.0 11416.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 23-NOV-92 FSYS REV. J001 VER. 1.1 2330 22-NOV-92 818 23-NOV-92 11447.0 11428.0 10600.0 11420.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229EA/1229MA 3967XA 1603MA/1609EB 8.5O0 9465.0 0.0 KCL/POLYMER 10.00 51.0 MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : S - 07A : PRUDHOE BAY : NORTH SLOPE : ALASKA 9.5 5.8 192.0 0.121 0.049 0.110 0.000 0.262 0.000 THERMAL SANDSTONE 0.00 8.500 2.0 74.0 192.0 74.0 0.0 72.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 CHT AC 68 1 LB 4 5 TTEN AC 68 1 LB 4 6 SPD AC 68 1 F/MN 4 7 CNC 2435 68 1 PU-S 4 8 CN 2435 68 1 PU-L 4 9 LSN 2435 68 1 CPS 4 10 SSN 2435 68 1 CPS 4 11 RS DLL 68 1 OHMM 4 12 RD DLL 68 1 OHMM 4 13 ED DLL 68 1 MV 4 14 ID DLL 68 1 A 4 15 SP DLL 68 1 MV 4 16 TEMP DLL 68 1 DEGF 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 245 Tape File Start Depth = 11455.000000 Tape File End Depth = 10599.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 58226 datums Tape Subfile: 3 328 records... Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10650.0 2435 10650.0 DLL 10650.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 11290.0 11290.0 11290.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 23-NOV-92 FSYS REV. J001 VER. 1.1 2330 22-NOV-92 811 23-NOV-92 11447.0 11428.0 10600.0 11420.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229EA/1229MA 3967XA 1603MA/1609EB 8.500 9465.0 0.0 KCL/POLYMER 10.00 51.0 9.5 5.8 192.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0.121 0.049 0. 110 0.000 0.262 0.000 74.0 192.0 74.0 0.0 72.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 8.500 TOOL STANDOFF (IN) : 2.0 REMARKS: REPEAT PASS. ACOUSTIC REPEAT SECTION NOT AVAILABLE DUE TO HOLE CONDITIONS. NEUTRON & LATEROLOG STANDARD REPEAT SECTIONS NOT AVAILABLE DUE TO HOLE CONDITIONS. DOWN PASS AT APPROXIMATELY 130 FPM PRESENTED FOR REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : S - 07A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CN 2435 68 1 PU-L 4 4 LSN 2435 68 1 CPS 4 5 SSN 2435 68 1 CPS 4 6 CHT 2435 68 1 LB 4 7 TTEN 2435 68 1 LB 4 8 SPD 2435 68 1 F/MN 4 9 RS DLL 68 1 OHMM 4 10 RD DLL 68 1 OHMM 4 11 ED DLL 68 1 MV 4 12 ID DLL 68 1 A 4 13 SP DLL 68 1 MV 4 14 TEMP TEMP 68 1 DEGF 4 4 08 501 10 0 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 54 376 29 5 4 19 912 29 5 4 19 912 29 5 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 06 033 97 0 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 163 Tape File Start Depth = 11298.000000 Tape File End Depth = 10650.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59453 datums Tape Subfile: 4 248 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS 92/12/14 01 **** REEL TRAILER **** 92/12/15 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 15 DEC 92 8:16a Elapsed execution time = 32.02 seconds. SYSTEM RETURN CODE = 0
