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HomeMy WebLinkAbout188-070MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, March 4, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-24 PRUDHOE BAY UNIT W-24 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/04/2024 W-24 50-029-21833-00-00 188-070-0 W SPT 8638 1880700 3000 1519 1520 1520 1520 153 404 399 392 REQVAR P Kam StJohn 1/18/2024 AOGCC 2 Year MIT-IA AIO AA 3.B001 Max anticipated pressure 3000 psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT W-24 Inspection Date: Tubing OA Packer Depth 588 3251 3213 3201IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240119125925 BBL Pumped:6.1 BBL Returned:5.5 Monday, March 4, 2024 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg p DATE: Tuesday, January 11, 2022 P.I. Supervisor ����i b � SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC W-24 FROM: Austin McLeod PRUDHOE BAY UNIT W-24 Petroleum Inspector Src: Inspector Reviewed B P.I. Suprv` � — NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT W-24 Insp Num: mitSAM220108165139 Rel Insp Num: API Well Number 50-029-21833-00-00 Inspector Name: Austin McLeod Permit Number: 188-070-0 Inspection Date: 1/8/2022 Tuesday, January 11, 2022 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W 24 Type Inj G TVD 8531 - TUbing 2133 '1 - -- - 2133 - - 2129 2123 -- PTD 1880700T e Test yp .SPT TQSt pSl � 2900 - - � IA 667 31 - 1 3230 ' I 3171 3150 BBL Pumped: - - 5.2 " BBL Returned: 5.1 - OA o 'i 9 9 9 Interval - REQVAR P/F -- P ✓ _i Notes: 2 year to MA1P. AIO 313.001 Tuesday, January 11, 2022 Page 1 of 1 MEMORANDUM State of Alaska Permit Number: 188-070-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, January 15, 2020 P.I. Supervisor l Q!-0 SUBJECT: Mechanical Integrity Tests 1 BP Exploration (Alaska) Inc. Well W-24 FROM: Bob Noble PRUDHOE BAY UNIT W-24 Petroleum Inspector 1 8531 - Tubing Src: Inspector 1094 ' Reviewed By: 1093 P.I. Supry -JP-4z-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT W-24 API Well Number 50-029-21833-00-00 Inspector Name: Bob Noble Permit Number: 188-070-0 Inspection Date: 1/14/2020 ' InspNum: mitRCN200114151025 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-24 Type Inj I W ITVD 1 8531 - Tubing 1095 1094 ' 1094 " 1093 PTD 1880700 Type Test SPT Test psi 2133 - IA 120 2295 2273 2261 ' BBL Pumped: 4.2 -BBL Returned: 4.z OA 38 65 67 67 Interval REQvAR P/F P Notes: AA 38.001 requires a MIT -]A every 2 years to max injection pressure of 1580 psi.' Wednesday, January 15, 2020 Page 1 of I • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission �< DATE: Tuesday,January 23,2018 TO: Jim Regg ! 11Z-3(i P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. W-24 FROM: Chuck Scheve PRUDHOE BAY UNIT W-24 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J� - NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT W-24 API Well Number 50-029-21833-00-00 Inspector Name: Chuck Scheve Permit Number: 188-070-0 Inspection Date: 1/21/2018 Insp Num: mitCS180122062938 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I W-24 'Type Inj W TVD 8531 Tubing 1171 1171 1170 1173 - -- -- PTD 1880700 Type Test - 2491 - 2489 -SPT Test psi 2133 - IA 317 2500 BBL Pumped: 4.4 TBBL Returned: 4.4 OA 0 25 30 " 31 Interval REQVAR P/F P ✓ Notes: Tested per AIO 313.001 ✓ SCANNEU - Tuesday,January 23,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, February 06, 2016 11:24 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA); Pettus, Whitney Subject: NOT OPERABLE:Injector W-24 (PTD #1880700)Inner by Outer Annulus Communication Attachments: Injector W-24 (PTD #1880700)TIO and Injection Plot.docx All, Injector W-24 (PTD#1880700) passed a PPPOT-IC and MIT-IA to 2500 psi on January 26, 2016 indicating two competent barriers to formation. However,the well continues to demonstrate slow inner by outer annulus communication. At this time, the well has been reclassified as Not Operable and added to the Quarterly Not Operable Injector report. Please shut in and freeze protect the well as soon as operationally feasible. Plan Forward: 1. Well Integrity Engineer: Evaluate for Administrative Approval (AA) 2. Well Integrity Engineer: Additional diagnostics as needed A updated copy of the TIO and injection plot have been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) SCANNED MAY 1 9 2015 BP Alaska-Well Integrity Coordinator gd•: t; WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com : AK, D&C Well Integrity Coordinator Sent: - anuary 22, 2016 10:27 AM To: AK, OPS GC2 0 ' _ , !' GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wire i e•-rations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB ells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integri fig.neer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayer , sica; Dickerman, Eric; 'Regg, James B • • • Injector W-24(PTD#1880700) TIO Plot February 06, 2016 oak eje 1101.11 Injection Plot 3141 .1441 1110 1 et et 4 1400 Mt MX 114 owe 11/11111. one, oeoe ume ,an.,,e We. nasm 010116 mns mnx max masa z�x • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, January 22, 2016 10:27 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA); Pettus, Whitney Subject: UNDER EVALUATION:Injector W-24 (PTD#1880700) Possible Inner by Outer Annulus Communication Attachments: Injector W-24 (PTD #1880700) TIO and Injection Plot.docx All, Injector W-24(PTD#1880700) is showing anomalous inner annulus pressure trends while on water injection. The well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: Perform MIT-IA 2. Wellhead: Obtain updated PPPOT-IC 3. Downhole Diagnostics: Monitor TIO pressures for 5 to 7 days 4. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any comments or concerns. SCANNED MAY 2 6 2016 Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 • • Injector W-24(PTD#1880700) TIO Plot January 22, 2016 wrl 14434 2006 -111- -11I- 2 OM 1-2006 a 000 000,. .— 1222:5 132,15 110,5 1111115 /1/1115 •awls ;4315 12 1015 I29715 •aa+a 1231 15 010710 01 14 mrze rs Injection Plot i µy'µ21 -l6d 4400 A 4 000 200 3 300 600 1 100 3 400 ' 1000 3200 800 ]0.30 R00 100 i 6pD —1►I 2210 _Ay i y1 600 1133 —ar 360 1 600 1 40 wo :zoo 00 1330 SOL I zw 6ce 00 ra 1112115 112115 105115 11/1015 111115 1112415 121018 101055 1217tl5 12398 1213115 047/16 01r0014 342136 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. I?tj tJ 7 ZJ Well History File # Digital Data Added to LaserFiche File 0 CD's - # 0 DVD's - # 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # 0 Mud Logs # 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any ofthe information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~~ ~ FILE # L ~~eun~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission , 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 -Fax (907) 276-7542 • 0 RECEIVED STATE OF ALASKA APR 13 2012 . . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other 11 Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Development ❑ Exploratory ❑ 188 -0700 3. Address: P.O. Box 196612 Stratigraphic❑ Service © 6. API Number: Anchorage, Alaska 99519 -6612 50- 029 - 21833 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 028263 • PBU W -24 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9625 feet Plugs measured None feet true vertical 9138 feet Junk measured 9218 feet Effective Depth measured 9500 feet Packer measured SEE BELOW feet true vertical 9058 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 28' -108' 28' -108' 1490 470 Surface 2657' 13 -3/8" 68# L -80 27' -2684' 27' -2684' 4930 2270 Intermediate Production 9122' 9 -5/8" 47# L -80 26' -9148' 26' -8827' 6870 4760 Liner 720' 7" 26# L -80 8905' -9625' 8661' -9138' 7240 5410 Perforation depth Measured depth SEE ATTACHED feet r� True Vertical depth feet 40 � A r R 2 4 �� IZ Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 25'-8967' 25' -8705' 4 -1/2" HES X Nipple 2105' 2105' 4 -1/2" Baker S -3 Hydro PKR 8733' 8532' Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Otis HC PER 8874' 8638' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 3111 1095 Subsequent to operation: 2865 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development ❑ / Service Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG © GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nita Summerhays I Printed Name Ni a Summerhays Title Data Manager �iiii _ !� �� Signat =.4 ., ,.� ./.11w Phone 564 -4035 Date 4/12/2012 - p -� RBDMS APR 16 20 7 e LI' l 7 - /z-- Form 10-404 Revised 11/2011 Submit Original Only �/z W -24 188 -070 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W -24 8/16/88 PER 9,395. 9,415. 8,990.53 9,003.46 W -24 8/16/88 PER 9,430. 9,454. 9,013.13 9,028.58 W -24 9/14/90 APF 9,296. 9,302. 8,925.85 8,929.8 W -24 9/14/90 APF 9,506. 9,514. 9,061.9 9,067.02 W -24 9/19/90 RPF 9,395. 9,415. 8,990.53 9,003.46 W -24 9/19/90 RPF 9,430. 9,454. 9,013.13 9,028.58 W -24 9/29/91 SQZ 9,296. 9,302. 8,925.85 8,929.8 W -24 9/29/91 SQZ 9,395. 9,415. 8,990.53 9,003.46 W -24 9/29/91 SQZ 9,430. 9,454. 9,013.13 9,028.58 W -24 9/29/91 SQZ 9,506. 9,514. 9,061.9 9,067.02 • 1 W -24 10/30/91 RPF 9,395. 9,415. 8,990.53 9,003.46 W -24 9/14/95 APF 9,333. 9,346. 8,950.15 8,958.65 W -24 9/14/95 APF 9,351. 9,358. 8,961.92 8,966.48 W -24 9/14/95 APF 9,371. 9,379. 8,974.95 8,980.15 W -24 8/18/96 APF 9,274. 9,290. 8,911.32 8,921.9 W -24 8/18/96 APF 9,303. 9,330. 8,930.46 8,948.19 W -24 6/13/05 APF 9,244. 9,264. 8,891.36 8,904.69 W -24 6/14/05 APF 9,215. 9,244. 8,871.92 8,891.36 W -24 3/29/12 APF 9,244. 9,264. 8,891.36 8,904.69 W -24 3/29/12 APF 9,274. 9,290. 8,911.32 8,921.9 W -24 3/29/12 APF 9,296. 9,330. 8,925.85 8,948.19 W -24 3/29/12 APF 9,333. 9,346. 8,950.15 8,958.65 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • W -24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/19/2012 T /I /O =0/0/0 Freeze Protect tbg & flowline (Slickline) Pump 38 bbls 60/40 down tbg & 10 bbls 60/40 down flowline. RDMO. S -Line on well @ departure. FWHP =0/0/0 Operator notified. 3/19/20121 ** *WELL INJECTING ON ARRIVAL ** *(Pre adperf) ITAG STICKY BOTTOM @ 9,431' ELM (Target 9,346' elm) W/ 2 -7/8" x 20' DUMMY GUN. BOTTOM PERF @ 9,415' ELM, —16' OF RAT HOLE. ** *WELL INJECTING ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS * ** 3/20/2012 T /I /O = 1350/0 + /30. Temp = 126 °. IA FL (pre -MIT). On Inj. IA FL @ 70' (4 bbls). SV = C. WV, SSV, MV = 0. IA, OA = OTG. NOVP. 16:30. 3/26/2012 T /I /0= 1010/190/140. Temp= 129 °. WHPs (UIC). On inj. SV =C. WV, SSV & MV =0. IA & OA =OTG. NOVP. 1115 hrs. 3/27/2012T/I/0= 1176/214/173 Pre AOGCC MIT IA PASSED to 4000 psi (Reg 'Compl) /Freeze Protect Tbg & Flowline (Pert) * * *No Integral Installed * ** Pumped 7.6 bbls DSL down IA to achieve test pressure of 4000 psi. 15 min loss of 9 psi, 30 min loss of 2 psi, for a total Toss of 11 psi. Bleed IAP to 500 psi. FP TBG with 38 bbls 60/40 and FL with 10 bbls 60/40. Valve positions= SV WV closed SSV MV open CV OTG Pad Op notified FWHP= 1000/0/0 3/28/2012 ***WELL SHUT -IN UPON ARRIVAL * ** (E -LINE: PERFORATING) INITIAL T /I /0 = 360/0/0 PSI ARRIVE TO LOCATION. BEGIN SPOTTING EQUIPMENT AND RIGGING UP. :STAB ON AND BEGIN PT. FINAL T /I /0 = 360/0/0 PSI ** *JOB IN PROGRESS AND CONTINUED ON 29- MAR - 2012 * ** 3/29/2012; ** *JOB CONTINUED FROM 28- MAR - 2012 * ** (E -LINE: PERFORATING) INITIAL TWO = 360/0/0 PSI TIE INTO SLB CEMENT BOND LOG DATED 16 -AUG -1988. PERFORATE WELL FROM 9333' -9346' WITH 2.88" POWERJET OMEGA, 6 SPF, 60 DEG PHASING 'PERFORATE WELL FROM 9310' -9330' WITH 2.88" POWERJET OMEGA, 6 SPF, 60 DEG PHASING PERFORATE WELL FROM 9296' -9310' WITH 2.88" POWERJET OMEGA, 6 SPF, 60 DEG PHASING PERFORATE WELL FROM 9274' -9290' WITH 2.88" POWERJET OMEGA, 6 SPF, 60 DEG PHASING :PERFORATE WELL FROM 9244' -9264' WITH 2.88" POWERJET OMEGA, 6 SPF, 60 DEG PHASING SWAB = C, SSV = C, WING = C, MASTER = 0 FINAL T /I /0 = 250/0/0 PSI ** *JOB COMPLETE. WELL LEFT SHUT -IN UPON DEPARTURE * ** • • FLUIDS PUMPED BBLS 3 DIESEL 51 60/40 Meth 54 TOTAL TREE= 4-1/16" CM/ • • WELLHEAD = McEVOY SA NOT. H2S READINGS AVERAGE 125 ppm ACTUATO =' ' ' oils T —2 4 WHEN ON MI. WELL REQUIRES A SSSVSAFETY KB.elci= -- i .9' i NOTE. BF. ELEV = — 53.-99' ' kiii= — 6660' n;Ailile = so' 6 9500' I 2,105 —14-1/7 HES X NIP, ID = 3.813" Daturi 9230' DatUrnTVD= 8800' S 13-3/8" CSG, 68#, L-80, ID = 12.415" --I 2684' 8711' —14-1/2" HES X NIP, ID = 3.813" Minimum ID = 3.725" @ 8954' 8,732' H9-5/8" X 4-1/7 BKR S-3 RKR ml 4-1/2" OTIS XN NIPPLE I 8757' —14-1a HES X NIP, ID = 3.813" 1 8777' 1-14-1/7 X 5-1/2" X0, ID= 3.958" 1 14-1/7 TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" H 8,787' 14-1 f2' TUBING STUB (XX/XX/X) H 8782' 8779' H UNIQUE MA CHINE OVERSHOT 1 GAS LIFT MANDRELS I ST MD 1VD DEV TYPE VLV LATCH PORT DATE II 8838 8530 1:51 FLO Mt RK 0 03/14/03 Ill 8866' —14-1/7 PARKER SWS MP, ID = 3.813" MI g'■ 8874' H9-5/8" X 4-1/2" OTIS HC PKR, ID = 3.850" 'TOP OF 7" LNR H 8950' !---- im IN 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3,958" H 8967' I 8933' H41/2" PARKER SWS MP, ID = 3.813" 1 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9148' I 8954' 1 — 4-1/7' OTIS XN NIP, ID = 3.725" PERFORATION SUMMARY REF LOG: SWS-BHCS-GR ON 08/13/88; SWS CBT ON 08/16/88 1 8967' 1— 4-1/7' VVLEG, ID = 3.958" 1 ANGLE AT TOP PERE: 48' @ 9212' 1 8956' H anu TT LOGGED 10/07/90 N3te: Refer to Production DB for historical perf data SIZE ' SF F IIITERVAL Opn/Sqz DATE 2-1/2" 6 9212 -9264 0 06/15/05 2-7/8" 6 9244 - 9264 0 03/29/12/ 3-318" 4 9274 - 9290 0 08/18/96 / 1 9222' HT' MARKER J.:off 1 2-7/8" 6 9274 - 9290 0 03/29/12 1 5" 12 9296 - 9302 S 09/01/93 2-7/8" 6 9296 - 9330 0 03/29/12 3-3/8" 4 9303- 9330 0 08/18/96 2-7/8" 6 9333 - 9346 0 03/29/12/ 1 3-3ff' 6 9333 - 9346 0 09/14/95 1 3-3/8" 6 9351 - 9358 0 09/14/95 3-3/8" 6 9371 - 9379 0 09/14/95 3-318" 6 9395 - 9415 0 10/30/91 5" 6 9430- 9454 S 09/01/91 9218' HRH- SPINNER PIECES 1 5" 12 9506 - 9514 S 09101/90 li r PBTD 1--1 9500' 1 Aweme , .. - #******• .#4444#4, WAWA* I 7" LNR 26#, L .03E3 bpf, ID = 6276" H 9625' _ 1 DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 08119188 ORIGINAL COM PLETION 03/30/12 TTR/ PJC PERFS (3/29/12) WELL: W-24 09124/90 RWO PERMIT No: r 1 880700 05131/04 KAK RWO API No: 50-029-21833-00 06/15/05 GJB/PJC PEES SEC 21, T11N, R12E 02/16/11 IVB/JMO ADDED SSSV SAFETY NOTE 01/20/12 TMN/JMID ADDED FQS SAFETY NOTE 6 BP Exploration (Alaska) . , • • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator @bp.com] Sent: Monday, April 02, 2012 1:09 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) cRerf 4 -(2 1f 2 Subject: March 2012 AOGCC MIT Forms Attachments: Mar 2012 MIT Forms.zip Jim, Phoebe, Please find attached MIT -IA forms for March 2012. Please let me know if the tests are acceptable as we are waiting on pulling the standing valve set for the MIT -T on P2 -01 (PTD #1970730). P2 -01 (PTD #1970730) 1 TD #1801 0 W -24 (PTD 1880700) Already submitted MIT -IA forms for March 2012, please let me know if I should resubmit: S -111 (PTD #2050510) - Submitted on 03/08/2012 MPF -88 (PTD #2031930) - Submitted on 03/22/2012 NS31 (PTD #2010600) - Submitted on 03/25/2012 Thank you , ktfe4MED APR 1 0 2012 Mehree,, Vazir (4 /U rrrul c-: { "; . ra1d - t /iirph ) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reao(cialaska.aov; doa. aoacc.prudhoe.bavCcialaska.0ov; phoebe.brooksCcialaska.aov; tom.maundenaialaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / W ( /e ( 4(Z l ( DATE: 03/31/12 J/ OPERATOR REP: Mehreen Vazir AOGCC REP: Declined to witness (Lou Grimaldi) Packer Depth Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. Well W -24 - Type Inj. W ' TVD • 8,531' Tubing 1052 1070 - 1079 1089 " Interval 4 P.T.D. 1880700 " Type test P Test psi 2132.75 Casing 268 2505 ' 2503 2508 ' PIE P Notes: Used 3.8 bbl meth to increase IAP to test pressure OA 36 203 ' 199 204 Well W -24 Type Inj. W TVD 8,531' Tubing '1,087 - 1,087 ' 1,088 1,097 - Interval 4 P.T.D. 1880700 Type test P Test psi 2132.75 Casing ' 2,530 2,530 2,528 '2,534 P/F P Notes: Flowline temperature increased from OA 226 230 - 234 238 128 degrees F to 131 degrees F during testing Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU W - 24 03 - 31 - 12 t 0/01 /00 Sch[umberger NO. 5405 Alaska Data Consulting Services Company: State of Alaska 2525 Gambell Street, Sake 400 Alaska Oil Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Seth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date BL Color CD K -11 AY1M -00033 SBHP SURVEY I I /1(1 -li 09/12/09 1 1 14.30 AWL8 -00031 PRODUCTION PROFILE a 08/06/09 1 1 P2 -31 AP3O -00045 LDL 1 e, 144 07/11/09 1 1 01 -29 B6JE -00009 PRODUCTION PROFILE I 08/11/09 1 1 J -22A 969K -00013 PRODUCTION PROFILE 3 60 08/30/09 1 1 W -44 B14B -00071 INJECTION PROFILE t r1,,je I e I 09/06/09 1 1 12 -25 B581-00010 INJECTION PROFILE t ir, a(/ 08/22/09 1 1 15 -33 AYKP -00051 SBHP SURVEY 09/01/09 1 1 P2 -48 B69K -00015 SBHP SURVEY 'Fei(! oriEll 09/01/09 1 1 1 -28 B69K -00016 INJECTION PROFIL 09/19/09 1 1 O -02A AP3O -00054 IBP /LDL i. 07/24/09 1 1 N -10A AXBD -00040 MEM PROD PR FILE r tp (N C4 08/25/09 1 1 W -24 AWJI -00044 MEM INJECTION PROFILE t 41 :.15/09 1 1 V -03 B2NJ -00021 MEM PROD PROFILE 1Pl!'� 1,,7ti> IAMI 09/03/09 1 1 H -14B B2WY -00026 MEM PROD PROFILE ljxQ' 08(27/09 1 1 P1-01 AY1M -00031 INJECTION PROFILE 6 w... 08/20/09 1 1 P1-05 8581.00009 PRODUCTION PROFIL o- 08/20/09 1 1 NK -10 B2WY -00023 MEM INJECTION PROFILE 1 q b 08/22/09 1 1 13 -27A B2NJ -00019 MEMORY SCMT i "Q I a. 08/13/09 1 1 18.028 B2WY -00021 MEMORY SCMT ail e 08/19/09 1 1 A. NK -38A AYKP -00049 USIT ig� s 08/17/09 1 1 06 -09 SWL8 -00028 USIT 1 q 07/30/09 1 1 13 -03A 09AKA0150 OH 1:369K-00011 69K -69K M /LWD EDIT ai I lf y i;{ A i 07/06/09 2 1 C -188 B0001 �L it 08/26/09 1 1 1-35/0-25 00011 4Ci�L 1 04-35A AXBD -00025 MCNL a en n SMiltide 0A. 05/13/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gamheli Street. Suite 400 900 E. Benson Blvd. Anchorage. AK 99503-2838 4 ter) N t, ,r 2 1 2000 ~ ~_ ~ ~if"f~~~/Vf~~~~ PROAceive Dincnosric SeR~ncES, Inc_ ro: Ao~cc Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 9950'! (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Cafiper/ MTT~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaskaj, )nc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 ~, E,i~,~`~r ;'l_ ~, ~. _. t}~U~'. .+<.~, ~ x <„ and ProActive Qiagnostic Service:s, lnc. Attn: Robert A. Richey 13~ West tnternational Airport Road Suite C Anchorage, AK 99518 Fa~c (907] 245-8952 1 j Injection Profile 05,Jun-06 W 24 2) ~~ Signed : Print Name: v ~~ ~~ ~ -o~ l~ ~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 'I30 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (807~245-8951 Fax: (907~245-88952 E-MAIL : 7'^ WEBSITE C:~Documents and Settmgs\Ownet\Desktop\Transmit_BP.docx MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~`O~j 4'~(~r~ FROm: Chuck Scheve Petroleum Inspector State of Alaska r Alaska Oil and Gas Conservation Commission DATE: Monday, April 14, 2008 SUBJECT: Mechanical integrity Tests BP EXPLORATION (ALASKA) INC W-24 PRUDHOE BAY UNIT W-24 Src: Inspector NON-CONFIDENTIAi. Reviewed By: P.I. Supr~ C nmm Well Name• PRUDHOE BAY UNIT W-24 Insp Num: mitCS080411185422 Rel Insp Num: API Well Number: so-o29-2 t s33-oo-0o Inspector Name: Chuck Scheve Permit Number: 188-070-0 ~ Inspection Date: 4/9/2008 ~ _ _ _~_. _ Packer Depth Pretest Initial 15 MIn 30 Min. 45 Min. 60 Min. r_ , Well ~T a In w ~ _ ~ _ _ W za YP J ~ TVD ss3t ,s, I 40 4000 ~ 3960 ~ 3950 / _ 1880700 - , . ~ ~ - ___~ P.T. _TypeTest sPT Test psi zt3z.~s ~ OA ~ o o o ~ o , _ _. ..- - __: , ~ ._ __ -- Interval aYRTST p/F P .% Tubing i zozo zozo zozo ; zooo _. ...--- Notes' Pretest pressures observed and found stable. ~L~d`!P®l10~~ ~uL ~ ~ 2Ut1U Monday, April 14, 2008 Pagc 1 of 1 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 ) STATE OF ALASKA ) REC ALASKA OIL AND GAS CONSERVATION COMMISSION E/VEO REPORT OF SUNDRY WELL OPERATIONSJUL 15 2005 . S D Alaska Oil & Gas 6Ðf1Ytntom . timulate lin"".....ulliJLU rnlSSlv WaiverO Tinß'~íløeD ' Repair WellO Pull TubingD Operation Shutdown 0 PluQ Perforations D Perforate New Pool D Perforate ŒJ 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development D ExploratoryO Re-enter Suspended WellO 5. Permit to Drill Number: 188-0700 6. API Number 50-029-21833-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (fl): 82.00 8. Property Designation: ADL-028263 11. Present Well Condition Summary: StratigraphicD ServiceŒf 9. Well Name and Number: W-24 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool Total Depth measured 9625 feet true vertical 9138.2 feet Effective Depth measured 9500 feet true vertical 9058.1 feet Plugs (measured) None Junk (measured) 9218 Casing CONDUCTOR SURFACE PRODUCTION LINER Length 80 2657 9122 720 Size 20" 91.5# H-40 13-3/8" 68# L-80 9-5/8" 47# L-80 7" 26# L-80 MD TVD Burst Collapse 28 108 28.0 108.0 1490 470 27 - 2684 27.0 - 2683.8 4930 2270 26 - 9148 26.0 - 8826.8 6870 4760 8905 - 9625 8660.5 - 9138.2 7240 5410 Perforation depth: Measured depth: 9212 - 9264, 9274 - 9290,9303 - 9330, 9333 - 9346, 9351 - 9358, 9371 - 9379, 9395 - 9415 True vertical depth: 8870 - 8905, 8911 - 8922, 8930 - 8948, 8950 - 8959, 8962 - 8966, 8975 - 8980, 8991 - 9003 TubinQ ( size, qrade, and measured depth): 4-1/2" 12.6# L-80 @ 25 SCANNED JUL 2 0 2005 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Hydro Set Pack @ 8733 4-1/2" Otis HC Packer @ 8874 4-1/2" HES X Nipple @ 2105 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Oil-Bbl Representative Dailv Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 2825 960 3926 1200 Tubing Pressure 1542 1601 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD ServiceŒ] ßPtJ 7-1-9, -0:;,. WAG ~ GINJD WINJ~ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: 305-140 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature DeWayne R. Schnorr DeWayne R. Schnorr ~~ ~.Jr~ Title Petroleum Engineer Phone 564-5174 Date 7/14/05 Form 10-404 Revised 4/2004 ORIG!rJ 1\ 1._ RBDMS BFL JUL 1 9 200S -) ) W-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/06/05 ***WELL INJECTING UPON ARRIVAL*** (D&T, PRE-APERF) TAG TO WI 2 1/2" D.G., TEL, & S.B. @ 9424' ELMO. TARGET DEPTH FOR APERF = 9264' ELMO. SAMPLE OF SCMOO. RDMO. ***NOTIFY PAD OP & PCC TO PUT WELL ON INJECTION, FUSIBLE CAP INSTALLED*** 06/13/05 PERFORATED 9244'-9264' WITH 2.5" HSD 6SPF 60 DEG PHASED 2506 PJ GUN. TRIED USING CCL FOR CORRELATION, CCL DATA WAS VERY POOR, COULD NOT SEE SHORT JOINT TO TIE-IN AND NO LOG WAS AVAILABLE WITH ELM TUBING TAIL. POOH AND SWAPPED TO GRICCL CORRELATION TOOL AND FINISH FIRST PERF INTERVAL. LAY DOWN FOR NIGHT AND CONTINUE JOB IN MORNING. 06/14/05 PERFORATED 9215'-92441 WITH 2.5" HSD 6SPF 60 DEG PHASED 2506 PJ GUNS. USED GAMMA RAY TO CORRELATE TO SWS CBT LOG DATED 16-AUG-88. ALL SHOTS FIRED. TAGGED TO AT 94251. FLUIDS PUMPED BBLS o NO FLUIDS PUMPED o TOTAL Page 1 TREE = 4-1/16" CrN WELLHEAD = McEVOY ."".""..",.",,,,,,,...,..,,. ..,,,,,,,,,,,,,,,,, A CTUA TOR = OTIS KB. ELEV = 81.9' äF.äE\i' ;' " '" '5á~9'ii ''''''~''''~IW'IW'''':'''''''''''''''':''''''''''''~''''~ KOP = 6600' , ,,,,,,,..........,, '''''' '" " ,....."" " " ,,,.. Max Angle = ~,~@ 9500' Datum MD = 9230' ",,,,,,,..,,,,,,.,.,,,,,,..,..,,. ".,.."...", "..",..,.""..".....,..,.,f Datum TV D = 8800' SS '.) 13-3/8" CSG, 68#, L-80, ID = 12.415" l-i 2684' ~ Minimum ID = 3.725" @ 8954' g 4-1/2" OTIS XN NIPPLE I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 8,787' ~ 1 TOP OF 7" LNR l-i 8905' 14-1/2" TBG, 12,6#, L-80, .0152 bpf, ID = 3.958" l-i 8967' 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 9148' ~ PERFORA TION SUMMA RY REF LOG: SWS-BHCS-GR ON 08/13/88; SWS CBT ON 08/16/88 ANGLE AT TOP PERF: 48 @ 9212' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/2" 6 9212 -9264 0 6/15/2005 3-3/8" 4 9274 - 9290 0 08/18/96 5" 12 9296 - 9302 S 09/01/90 3-3/8" 4 9303 - 9330 0 08/18/96 3-3/8" 6 9333 - 9346 0 09/14/95 3-3/8" 6 9351 - 9358 0 09/14/95 3-3/8" 6 9371 - 9379 0 09/14/95 3-3/8" 6 9395 - 9415 0 10/30/91 5" 6 9430 - 9454 S 09/01/91 5" 12 9506 - 9514 S 09/01/90 I PBTD l-i 9500' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" l-i 9625' DATE 08/19/88 09/24/90 05/31/04 06/15/05 REV BY COMMENTS ORIGINAL COM PLErION RWO KAK RWO GJB/PJC PERFS DATE W-24 . I . ~ ::a ~ ~ r I :8: I- & I I f , ~ , I I I .., J!!I!IIJ.. REV BY COMMENTS ) SAFETY NOTES: I 2, 105' ~14-1/2" HES X NIP, ID = 3.813" I 8711' 8,732' 8757' 8777' 8779' 8782' ~14-1/2" HES X NIP, ID = 3.813" I ~19-5/8" X 4-1/2" BKR S-3 PKR I ~14-1/2" HES X NIP, ID = 3.813" I ~14-1/2" X 5-1/2" XO, ID = 3.958" I ~I UNIQUE MACHINE OV ERSHOT I ~14-1/2" TBG STUB I GAS LIFT MANDRELS MD TVD DEV TYPE I VLV LATCH PORT DATE 8838 8530 42 FLO DMY RK 0 03/14/03 8866' ~14-1/2" PARKER SWS NIP, ID = 3.813" I 8874' r-19-5/8" X 4-1/2" OTIS HC PKR, ID = 3.850" I 8933' r- 4-1/2" PARKER SWS NIP, ID = 3.813" r-14-1/2" OTIS XN NIP, ID = 3.725" I 8954' 8967' 8956' r-14-1/2" TBG TAIL WLEG, ID = 3.958" I l-f ELMD TT LOGGED 10/07/90 I 9222' l-i MARKER JOINT I 9218' l-i FISH - SPINNER PIECES I PRUDHOE BA Y UNrr WELL: W-24 PERMrr No: "1880700 A PI No: 50-029-21833-00 SEe 21, T11 N, R12E BP Exploration (Alaska) I,~' (Û.' 4~I·:J ¡f.'~1.¡1 ~~. :~.:, :- I,i?l· , I 1, \I~ I, I...., " I!U\ \ I ,=-" · [1""1'\') I I / i~1 \ '! [ i [ ~ b.JJ I J j '""'" ,...:=;1 i.¡~, '¡ Ir~,[""J I I 1 ; ¡ i ¡ Ii! i 1::1 i I I I IJ' '01.j ) rÃ\ ./p '\ !U-Û ) FRANK H. MURKOWSK/, GOVERNOR ALASKA. OIL AlVD GAS CONSERVATION COMMISSION 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Daniel Robertson Senior Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 o £0/ D1 \Cb Re: Prudhoe Bay W -24 Sundry Number: 305-140 SCAj~NED JUN 1 ~! 2005 Dear Mr. Robertson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form.. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a i ay or weekend. A person may not appeal a Commission decision to Superior ourt unless rehearing has been requested. -- DATED this-l:'day of June, 2005 Enc!. · .. bp ) ) 'W" RECF,,,:~\/C; ~ ~~ \\ liJ ~:~'~~~I , '" .I~'~ \ ~~i,i~ ~\~~;'!""':I ¡',' JUN 0 6 7,005 A\~'t]~J~ OH E:¡ ^r~t.horage June 2, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RE: Sundry Notice for W-24i Additional Perforations BP Exploration Alaska, Inc. proposes to add perforations in WAG injection well W -24i. Step Type Procedure 1 S Slickline drift 2 E Add perforations /. The objective of the additional perforations is to increase rate and recovery from offset producers via improved conformance with the injector in the intervals to be / perforated. Please contact Dan Robertson at 564-5546 with any questions. sinlL~ Daniel B. Robertson, PE t, R. ~ (..... ~ ~, I 'j . l ,¡ ,-( ¡ ¡ -"'¡' ¡: f \ ¡. j \., L~ .-. \[v'll\¿!-"\ C((f ~~y()6 ú6A- ~/7/2..(I() 5 ) STATE OF ALASKA p~ 6'6'K¢ ALASKA OIL AND GAS CONSERVATION COMMISSION RE ':i'~¡',,' !,",.~"",~' '",. APPLICATION FOR SUNDRY APPROVALJUN 062.005 20 AAC 25.280 StratigraphicD Service Œ] 9. Well Name and Number: W-24 / 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9500 8976.1 MD TVD . . '. ~ 1. Type of Request: D Suspend D D RepairWell D D Pull Tubing D Abandon Alter Casing Change Approved Program 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 82.00 KB 8. Property Designation: ADL-028263 11. Presen1 Total Depth MD (ft): 9625 Casing Total Depth TVD (ft): 9138.2 Length Size 80 720 9122 2657 20" 91.5# H-40 7" 26# L-80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 8553 - 8554.2 8911 - 8921.9 8930 - 8948.2 8950 - 8958.7 8962 - 8966.5 8975 - 8980.2 CONDUCTOR LINER PRODUCTION SURFACE Perforation Depth MD (ft): 0700 07G2 9274 - 9290 9303 - 9330 9333 - 9346 VJ{it'" 9351 - 9358 9371 - 9379 'tr~'r - '14' s Packers and SSSV Type: 4-1/2" Baker S-3 Hydro Set Packer 4-1/2" Otis HC Packer 12. Attachments: Description Summary of Proposal ŒJ Detailed Operations Proç¡ram 0 BOP Sketch 0 14. Estimated Da1e for Commencing Operation: /0" June 16, 2005 D D D ,1:\ I;~~;!( ~ J,:.u t~ :./!,,' ~, ~ \,~ , Perforate ŒJ <"" \W,\~~~~~~~ StimulateD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 188-0700 ./ Other 0 Operation Shutdown Plug Perforations Perforate New Pool 4. Current Well Class: Development D Exploratory D 6. API Number / 50-029-21833-00-00 /' Plugs (md): None Burst Junk (md): 9218 Collapse top bottom top bottom 28 108 28.0 108.0 1490 470 8905 9625 8660.5 9138.2 7240 5410 26 9148 26.0 8826.8 6870 4760 27 2684 27.0 2683.8 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2 " 12.6 # L-80 25 8967 Packers and SSSV MD (ft): 8733 8874 13. Well Class after proposed work: / Exploratory 0 DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD \NGk WAG Œ1 GINJD ServiceŒ) Abandoned D Date: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact WINd-OO- WDr;P E1 ) Prepared by DeWayne . SCh"n9F( 564-5174," Daniel Rob~ Printed Name Signature ,.m,niel Ro~e~son ~- ~4V~~~ ~-~ '/7,,/O.r- Title Phone Senior Petroleum Engineer 564-5546 6/2105 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Other: ~ BOP TestD Subsequent F: Approved by: Form 10-403 Revised 11/2004 Sundry Number: 305"-/(/.0 Mechanciallntegrity Test D Location Clearance D RBDMS 8Ft ./UN 0 8 700í ~~~~g~~~~ION Date: ~/oJ""" ORIGINAL SUBMIT IN DUPLICATE ~ ~ 8711' H4-1/2" HES X NIP, 10= 3.813" ~ 8,732' - 9-5/8" X 4-1/2" BKRS-3 PKR 1 875T - 4-1/2" HES X NIP, 10 = 3.813" 8: ~ 877T H4-1/2" X 5-1/2" XO, 0 = 3,958" 1 ø 8779' H UNIQUE MA. D-iINE OV ERSt-(H I ~ 8782' H4-1/2" TBG STUB 1 GA S L FT MA. NORELS 1 IST tv[) I TVO DEV TYPE VLV LATCHI FORTI DATE I 1 8838 8530 42 R.O OMY RK 0 03/14/03 8866' H4-1/2" PARKffi SWS NP, 10= 3.813" 1 , . ) TREE = 4-1/16" CIW WB...LHEAD = fv\:;EVOY '.....,~, ,.....,.,~,' ~ ~ ,",","",_, ,~'" ,.'" . , ',,","".' ,~. ",.' ,'M, " ,',.' ~ ", ,..,' ;..A8TUATOR = OTIS KB. ELEV = 81.9' ........ .............,...... BF. ELEV = 53.99' ¡<ÖP";; "'"-'~-6600' 'Max Angie·=·~'·"5õ'·@ j~5Òöi 'Öätüm rVio"';- . ......... '9236' '6aiurñTVÖ '';;'''''''''''asÖQi''às' 13-3/8" CSG, 68#, L-80, 10 = 12.415" 1-1 2684' ~ Minimum ID = 3.725" @ 8954' 4-1/2" OTIS XN NIPPLE 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3,958" 1-1 8,787' 1 TOP OF 7" LNR 1-1 8905' 14-1/2" TBG, 12.6#, L-80, ,0152 bpf, 10 = 3.958" H 8967' 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9148' ----..t ÆRFORA TlON SUMMARY REF LOG: SWS-BHCS-GR ON 08/13/88; SWS æT ON 08/16/88 ANGLE AT TOPPffiF: 48 @ 9274' Note: Refer to Production DB for historical perf data SIZE SFf' NTffiVAL Opn/Sqz OA TE 3-3/8" 4 9274- 9290 0 08118/96 5" 12 9296 - 9302 S 09/01/90 3-3/8" 4 9303 - 9330 0 08118/96 3-3/8" 6 9333 - 9346 0 09/14/95 3-3/8" 6 9351 - 9358 0 09/14/95 3-3/8" 6 9371 - 9379 0 09/14/95 3-3/8" 6 9395 - 9415 0 10/30/91 5" 6 9430 - 9454 S 09/01/91 5" 12 9506-9514 S 09/01/90 1 PBTO H 9500' 7" LNR 26#, L-80, .0383 bpf, 10 = 6.276" H 9625' DATE 08119/88 09124190 05/31/04 REV BY COMrvENlS ORIGINAL COMPLETION RWO KAK RWO DATE W-24/ I . I :8: -I :>< I 1 ! I I , j!jfjf!fj.,. REV BY COrvTv1ENTS ) I SAFETY NOTES: I 2,105' H4-1/2"HESXNIP,10=3.813" 8874' H9-5/8" X 4-1/2" OTIS HCPKR, 10=3.850" 1 I 8933' H4-1/2" PARKffi SWS NP, 10= 3.813" 1 H4-1/2" OTlS XN NIP, 10 = 3.725" I 8954' 896T 8956' H4-1/2" TBG TAIL WLEG, 10 = 3.958" 1--1 ELMOTT LOGGED 10/07/90 I .. 9222' 1-1 MARKER JOINT 1 I 9218' 1-1 FISH - SRNNffi RECES I PRUDHOE BAY UNIT WB...L: W-24 ÆRMT I\b: 1880700 APII\b: 50-029-21833-00 SEe 21, T11N, R12E 8P Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor X~q 10/11(04-- DATE: Wednesday, October 06, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-24 PRUDHOE BAY UNIT W-24 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 1~ 'OJ II J~- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT W-24 API Well Number: 50-029-21833-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG04IO05104754 Permit Number: 188-070-0 Inspection Date: 10/5/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-24 Type Inj. s TVD 8531 IA 0 2250 2]80 2]70 P.T. ]880700 TypeTest SPT Test psi 2132.75 OA 0 0 0 0 Interval 4YRTST PIF P Tubing 0 0 0 0 Notes: All zero pressures checked with test gauges. Wednesday, October 06, 2004 Page I ofI l" "R' ~- .,'~ E 4\ qr-" r) .," . )),r... 1,\ ~.I """','" I \ STATE OF ALASKA ( '\1",,~ \~ß " ~".;1 ;7 <\..,., ~",,',' ALASKAvlL AND GAS CONSERVATION COI\lIlv1ISSION N 4 REPORT OF SUNDRY WELL OPERATION~ 2 2004 1\ I ,"'. ~ ," ,~", " ,.." '"I' f' 0"",.,,; "'s;"' ,,? f~~daSf(a lJ¡~ d ~2~~ l,,[h ~~, -~ H~~~jl't.~ 'll.ì~,~ 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 82' t\;;;¿J~;Jr:;~ 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver II Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension II Pull Tubing 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 0 OthE 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic Test II Service 5. Permit To Drill Number 188-070 6. API Number: 50-029-21833-00-00 99519-6612 9. Well Name and Number: PBU W-24 ADL 028263 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 8. Property Designation: 11. Present well condition summary Total depth: measured 9625 feet true vertical 9138 feet Plugs (measured) None Effective depth: measured 9500 feet Junk (measured) 9218' true vertical 9058 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2684' 13-3/8" 2684' 2684' 4930 2270 Intermediate 9148' 9-5/8" 9148' 8827' 6870 4760 Production Liner 706' 7" 8919' - 9625' 8671' - 9138' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): 9274' - 9415' 8911' - 9003' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# L-80 8967' Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Otis HC packer; 9-5/8" x 4-1/2" Baker 'S-3' 8874'; 8732'; packer; 4-1/2" HES 'X' Nipple 2105' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 8ft JUM i:¡ltj '.' Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casino Pressure TubinQ Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run II Daily Report of Well Operations II Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 0 Development II Service 16. Well Status after proposed work: 0 Oil 0 Gas II WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ken Allen, 564-4366 304-124 Printed Name Terrie Hubble Signature /fP JtJ\, "-.t tIt). ~ Form 10-404 Revised 12/2003 Title Technical Assistant Phone 0 RIG 11\rAt 0 '" I,.... '2. L u:repared By Name/Number: Date I ~fD I' errie Hubble, 564-4628 ~~ { ( Well: Field: API: Permit: W-24 RWO Prudhoe Bay Unit 50-029-21833-00-00 188-070 Accept: Spud: Release: Rig: OS/23/04 N/A OS/29/04 Doyon 16 PRE-RIG WORK 09/23/03 A LEAK DETECT LOG WAS PERFORMED. LOG WAS CORRELATED TO WESTERN ATLAS PRODUCTION PROFILE DATED 1-SEP-96. LEAK FOUND AT PACKER AND GLM #1. 04/24/04 EQUALIZE XX- PLUG @ 8900' SLM. PULL XX-PLUG FROM 8900' SLM. RUN SBHP (LUB.=239.7 1 STOP @ 9130 MD = 3378.8 TEMP= 231.4 2 STOP @ 8980 MD=3345.6 TEMP= 229.4 LUB=251.2). ATTEMPT TO SET PXN PLUG BODY, SLIGHT PARRAFIN ON TOOLS, RIH TO BRUSH ALL NIPPLES. 04/25/04 BRUSHED X-NIP AND XN NIP. SET 41/2" PXN PLUG BODY @ 8926' SLM. SET PRONG (1 3/4"-FN, 1 3/4" BODY, 84 1/2" LONG) @ 8924' SLM. MAX PSI ON TUBING WHEN PLUG SET WAS 400 PSI WI FLUID LEVEL @ SURFACE. PLUG WAS SUFFICIANT DRIFT FOR CHEM CUTTER. COMBO MIT (TUBING, IA) TO 3500 PSI- TRI-PLEX RAN OUT OF FLUIDS, PUMP TRUCK WILL PERFORM MIT TXIA LATER. SET KEN CATCHER (OAL- 117") @ 8920' SLM. TURNED WELL OVER TO PAD OPERATOR. 05/12/04 A CHEMICAL CUTTER WAS PERFORMED TO CUT THE PIPE @ 8788'. THE CUT WAS MADE IN THE 1ST FULL JOINT ABOVE GLM#1. CUTTER HEAD WAS SOMEWHAT UNEVEN. A STRING SHOT AND TUBING PUNCH WERE ALSO PERFOMED TO PREPARE THE WELL FOR THE CUTTER. WELL WAS LEFT SHUT IN. PAD OPERATOR NOTIFIED. j ( ( BP Exploration Operations Summary Report Page 1 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-24 W-24 REENTER+COMPLETE Start: Rig Release: Rig Number: 5/20/2004 Spud Date: End: 5/29/2004 Date From - To Hours Task Code NPT Phase Description of Operations 5/22/2004 20:00 - 00:00 4.00 MOB P PRE - Move rig off of W-05. Three hrs. spent maneuvering rig back & forth to get off of W-05 due to tight working area between wells & edge of pad. 5/23/2004 00:00 - 04:00 4.00 MOB P PRE - Continue moving rig to W-24. - Spot rig, center over well, & shim rig. - Spot cuttings tank & tiger tank. - Install 2nd valve on tubing spool for double valve on fA. - Accept rig @ 0400 hrs 5-23-04 04:00 - 07:00 3.00 PULL P DECOMP - Take on S/W into tiger tank & pits utilizing two available trucks. - Little Red heating S/W in tiger tank to 140 deg. - R/U manifold for circulating out freeze protect fluids. 07:00 - 08:00 1.00 PULL P DECOMP - R/U DSM lubricator & pull BPV. LID lubricator. - No pressure on tubing or annulus - on vacuum. 08:00 - 09:00 1.00 PULL P DECOMP - PJSM - R/U circ. line to tree - fill lines & test to 2000 psi 09:00 - 11 :00 2.00 PULL P DECOMP - Circ. out freeze protect fluids wi 140 deg S/W @ 2.5 BPM 40 psi until catcing up wi fluids downhole. (19 bbls) - Stage up pump for remainder of circ - ICP 4 BPM 330 psi, FCP 8.5 BPM 1200 psi. - Total S/W pumped 750 bbls. 11 :00 - 12:00 1.00 BOPSUP P DECOMP - Monitor well - static. - BID lines - Install TWC & test from underneath to 1000 psi. - Bleed off pressure. 12:00 - 14:00 2.00 WHSUR P DECOMP - PJSM - NID tree & adaptor flange. 14:00 - 22:00 8.00 BOPSUF. P DECOMP - PJSM - N/U BOP stack. Break bottom rams & install mud cross between lower rams and blind rams. Install HCR valves. Hook up choke & kill lines to HCR valves. - N/U riser & flow line. 22:00 - 00:00 . 2.00 BOPSUF P DECOMP - Fill stack in preparation to test BOP's - Repair leak @ mud cross 5/24/2004 00:00 - 02:00 2.00 BOPSUP P DECOMP - Tighten nuts on top flange of mud cross. - Disconnect choke line, inspect & replace metal gasket between choke line & HCR valve. 02:00 - 11 :30 9.50 BOPSUP P DECOMP - Test BOP's per BP & AOGCC regs. to 250 psi I 4000 psi. - Test annular preventer to 250 psi 13500 psi. - Repaired leaking equip't - C/O manual choke valve - Obtained good test on all BOPE. - Pull test jt. & replace air boot on riser. - RID BOPE test equip't. 11 :30 - 12:00 0.50 BOPSUP P DECOMP 12:00 - 12:30 0.50 BOPSUR P DECOMP 12:30 - 13:30 1.00 BOPSUF P DECOMP 13:30 - 14:00 0.50 PULL P DECOMP 14:00 - 14:30 0.50 PULL P DECOMP - R/U DSM lubricator - pull TWC - RID DSM lubricator. - PJSM - - M/U Baker spear wi 3.947" double grapples on 4" DP. - Engage tubing hanger wi spear & pull 25K over to ensure grapples engaged. - S/O & BOLDS - Pull on tubing & unseat hanger wI 125K - Tubing movement wi 142K Printed: 6/1/2004 9:20: 42 AM ~ ( ( BP Exploration Operations Summary Report Page 2 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-24 W-24 REENTER+COMPLETE Start: Rig Release: Rig Number: 5/20/2004 Spud Date: End: 5/29/2004 Date From - To Hours Task Code NPT Phase Description of Operations 5/24/2004 14:00 - 14:30 0.50 PULL P DECOMP - Pull hanger to rig floor - up wt. 138K which includes 40K for TD. 14:30 - 16:00 1.50 PULL P DECOMP - Disconnect control lines @ hanger. - Break out & LID spear & jt 4" DP. - Break out & LID hanger. 16:00 - 18:00 2.00 PULL P DECOMP - R/U circ. head & lines. - CBU @ 8 BPM 570 psi. - Pumped 23 bbls before getting returns. - R/U CAMCO spooling unit while circulating. 18:00 - 20:30 2.50 PULL P DECOMP - PJSM - - POH & LID 53 jts out of 221 jts of 4 1/2" 12.6# TDS tubing. - Recovered control line, 27 control line protectors,S ss bands, SSSV. - Clear floor of control line spooling unit & protectors @ SSSV. 20:30 - 00:00 3.50 PULL P DECOMP - POH & LID jts 54 - 135 out of 221 & 2 GLM's 5/25/2004 00:00 - 04:00 4.00 PULL P DECOMP - Continue POH & LID remaining 85 jts of 4 1/2" 12.6# TDS tubing, 1 GLM, & 1 cut off 4 1/2" stub measuring 12.15' - Full recovery of all equipment above cut per program. 220 jts, 1 SSSV, 3 GLM's, 41/2" cut off jt equaling 12.15',27 control line protectors, 27 pins for protectors, & 5 ss bands. - Losses of 21 bbls while pulling tubing Top of fish @ 8792' 04:00 - 05:00 1.00 PULL P DECOMP RD 4-1/2" tbg handling equipment. Clear floor of tools & scrub rig floor. 05:00 - 09:30 4.50 BOPSUF,P DECOMP Set test plug, RU test equipment. Attempt to test lower pipe rams, test plug leaking. Experience trouble keeping test plug seated after functioning pipe rams. Pulled test plug check rubbers, re-dope and reset test plug. RILDS on test plug able to successfully test lower 2-7/8" X 5" variable pipe rams to 250 psi / 4000 psi. 09:30 - 10:30 1.00 BOPSUF. P DECOMP Pull test plug and install wear bushing. RD test equipment. 10:30 - 12:30 2.00 CLEAN P DECOMP PJSM with BOT and rig personnel on picking up BHA #1. PU AND MU BHA #1 to dress 4-1/2" tbg stub. 12:30 - 13:30 1.00 CLEAN P DECOMP RIH picking up DP from pipe shed. 13:30 - 14:00 0.50 CLEAN P DECOMP Service top drive and blocks. 14:00 - 18:00 4.00 CLEAN P DECOMP Continue RIH picking up DP to 4024', 124 jts. 18:00 - 18:30 0.50 CLEAN P DECOMP PJSM with HOWCO and rig personnel on running RTTS 18:30 - 19:30 1.00 PULL P DECOMP PU and MU RTTS. RIH and set RTTS packer at 29', Back off and POH. 19:30 - 22:00 2.50 PULL P DECOMP Pull wear bushing. BOLDS, MU packoff retrieving tool and work 9-5/8" packoff free, POH. MU and set new packoff. 22:00 - 22:30 0.50 WHSUR P DECOMP RILDS, pump full of packing material. Test packoff to 5000 psi. 22:30 - 23:30 1.00 PULL P DECOMP Install wear bushing. RIH and latch onto RTTS. POH and LD RTTS. 23:30 - 00:00 0.50 CLEAN P DECOMP Continue RIH with BHA #1 picking up DP from pipe shed. 5/26/2004 00:00 - 05:30 5.50 CLEAN P DECOMP Continue RIH to 8791' picking up DP. 05:30 - 06:00 0.50 CLEAN P DECOMP MU top drive, stage pumps to 6 bpm @ 680 psi. 163k up, 163k down, 163k rotating, torque 3k. Shut down rotary and RIH, tag up on tbg stub. PU and wash down over tbg stub while rotating. Dress tbg stub at 100 rpm and 3.5k torque. Printed: 6/1/2004 9:20:42 AM ~- ( (' BP Exploration Operations Summary Report Page 3 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-24 W-24 REENTER+COMPLETE Start: Rig Release: Rig Number: 5/20/2004 Spud Date: End: 5/29/2004 Date From - To Ho u rs Task Code NPT Phase Description of Operations 5/26/2004 05:30 - 06:00 0.50 CLEAN P DECOMP Top of fish @ 8791' 06:00 - 07:00 1.00 CLEAN P DECOMP CBU 8.5 bpm @ 1150 psi 07:00 - 07:30 0.50 CLEAN P DECOMP Monitor well - static. LD 1 jt of DP and blow down top drive. 07:30 - 09:00 1.50 CLEAN P DECOMP PJSM with all rig personnel. Cut and slip 98' of drill line. Service rig 09:00 - 13:00 4.00 CLEAN P DECOMP POH with BHA #1 13:00 - 14:00 1.00 CLEAN P DECOMP Break out and LD mill assembly. Brass tattle tales inside mill show good indication the mill no-go'd on top of the tbg stub. 14:00 - 14:30 0.50 CLEAN P DECOMP Clean and clear rig floor. 14:30 - 15:00 0.50 CLEAN P DECOMP PJSM with HOWCO and all rig personnel on making up and running 9-5/8" RTTS tool. 15:00 - 19:00 4.00 CASE P DECOMP RIH with RTTS to 8781' 19:00 - 19:30 0.50 CASE P DECOMP Stage pumps to 5 bpm, 164k up, 164k down. Set RTTS at 8781' 19:30 - 20:30 1.00 CASE P DECOMP Test 9-5/8" csg to 4000 psi for 30 minutes. 20:30 - 21 :00 0.50 CASE P DECOMP Attempt to test packer and tbg stub below RTTS, not holding pressure. Establish injection rate of 1/4 bpm at 3100 psi. 21 :00 - 22:00 1.00 CASE P DECOMP Close Hydril and pressure up to 1000 psi to release hydraulic setting pins on RTTS. Bleed pressure and PU to release RTTS. Blow down top drive, choke and kill lines. 22:00 - 00:00 2.00 CASE P DECOMP POH laying down DP. Midnight depth: 6880' 5/27/2004 00:00 - 08:00 8.00 CASE P DECOMP Continue POH laying down DP. Losses increased to 5-6 bbl/hr average. 08:00 - 08:30 0.50 CASE P DECOMP Break out and LD RTTS packer. Clean and clear rig floor, 08:30 - 09:00 0.50 EV AL P DECOMP PJSM with SWS and all rig personnel on rigging up and running US IT log. 09:00 - 10:00 1.00 EVAL P DECOMP RU logging equipment, lubricator and packoff. MU lubricator in Hydril. 10:00 - 11 :30 1.50 EVAL P DECOMP RIH with US IT tool to 8785'. 11 :30 - 14:30 3.00 EVAL P DECaMP Run USIT log from 8785' to 1800'. 14:30 - 15:00 0.50 EV AL P DECOMP RD logging tools. Clear rig floor. 15:00 - 16:00 1.00 RUNCOMP RUNCMP Pull wear bushing. RU to run 4-1/2" completion, including compensator and torque turn equipment. 16:00 - 16:30 0.50 RUNCOMP RUNCMP PJSM with BOT, Doyon Casing and all rig personnel on making up and running completion. 16:30 - 00:00 7.50 RUNCOMP RUNCMP Make up 4-1/2" tail pipe assembly with BOT stacker packer. Run 4-1/2", 12.6#, L-80, TC-II completion. Pick up each joint with compensator, torque turn and chart each connection. 5/28/2004 00:00 - 08:30 8.50 RUNCOMP Midnight depth: 3026', 71 joints ran. RUNCMP Continue to run 4-1/2", 12.6#, L-80, TC-II completion, Pick up each joint with compensator, torque turn and chart each connection. 08:30 - 11 :30 3.00 RUNCOMP RUNCMP RD compensator, MU head pin to tbg jnt #210. MU jnt #210: P/U 135 klbs, S/O 135 klbs Printed: 6/1/2004 9:20: 42 AM .~ ( , BP Exploration Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-24 W-24 REENTER+COMPLETE Date 5/28/2004 3.00 RUNCOf\IIP From - To Hours Task Code NPT Phase RUNCMP 08:30 - 11 :30 11 :30 - 12:00 0.50 RUNCOMP 12:00 - 12:30 0.50 RUNCOMP 12:30 - 16:30 4.00 RUNCOMP 16:30 - 17:00 0.50 RUNCOMP 17:00 - 17:30 0.50 RUNCOMP 17:30 - 18:00 0.50 RUNCOMP 18:00 - 19:00 1.00 RUNCOMP 19:00 - 20:00 1.00 RUNCOMP 20:00 - 21 :30 1.50 RUNCOMP 21 :30 - 22:00 0.50 BOPSUR P 22:00 - 00:00 2.00 BOPSUP. P 5/29/2004 00:00 - 01 :00 1.00 BOPSUR P 01 :00 - 04:00 3.00 WHSUR P 04:00 - 04:30 0.50 WHSUR P 04:30 - 06:00 1.50 WHSUR P RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP WHDTRE WHDTRE WHDTRE WHDTRE WHDTRE WHDTRE Page 4 of 4 Start: Rig Release: Rig Number: Spud Date: End: 5/29/2004 5/20/2004 Description of Operations Engage pumps and establish baseline parameters: 5 bpm @ 350 psi 3 bpm @ 170 psi RIH until no-go, pump pressure increase: 5 bpm @ 450 psi 3 bpm @ 260 psi Repeat process 2 additional times, no-go with 15k on tbg stub to verify tbg stub correctly seated in seal assembly. Space out seal assembly 2.34' above no-go on tbg stub. MU tbg hanger. Land tbg and RILDS. PJSM with Veco and all rig personnel on pumping corrosion inhibited seawater. RU circulation lines and vac trucks Pressure test lines to 4000 psi. Reverse circulate 120 bbls clean seawater, followed by 390 bbls corrosion inhibited seawater, 3 bpm @ 150 psi. PJSM with Little Red and all rig personnel on freeze protection and pressure testing. RU Little Red, test lines to 4000 psi. Pump 120 bbls diesel, 4.7 bpm @ 850 psi. Allow diesel to U-tube. Break out head pin, drop ball and rod assembly. MU head pin and RU Little Red. Pressure up tbg to 3500 psi to set 9-5/8" X 4-1/2" stacker packer. Test 4-1/2" tbg to 4000 psi for 30 minutes with Little Red. Bleed tbg pressure. RU Little Red to 9-5/8" X 4-1/2" annulus. Test annulus to 4000 psi for 30 minutes. Bleed down annulus pressure. LD landing joint. Set TWC in tbg hanger, (unable to test TWC). PJSM. ND BOPE. Set back & secure. Continue ND BOPE. Set back & secure. NU FMC 11" 5K x 4-1/16" 5K Tubing head adapter & 4-1/16" 5K Production Tree. Test tubing head adapter & tree to 5000 psi. RU DSM lubricator & pull TWC. DSM install BPV in Tubing Hanger. Secure well. RIG RELEASED @ 0600 hrs Printed: 6/1/2004 9:20:42 AM ( ~. Well: Field: API: Permit: W-24 RWO Prudhoe Bay Unit 50-029-21833-00-00 188-070 Accept: Spud: Release: Rig: OS/23/04 N/A OS/29/04 Doyon 16 POST RIG WORK 06/11/04 TAG B&R @ 8,743' SLM. POOH, RECOVERED B&R RBIH . TAG RHC @ 8,755 SLM. POOH, RECOVERED LOCK BODY. TAG CATCHER-SUB @ 8919' SLM. POOH RECOVERED SUB. TAG PXN PRONG @ 8,922' SLM POOH RECOVERED PXN PRONG . TAG PXN LOCK @ 8,925' SLM. 06/12/04 JAR ON PLUG +/- 1 H POOH DID NOT RECOVER PLUG. CHANGE OUT TOOL STRING. RBIH TAG PLUG @ 8,925 SLM. WORK TOOL STRING +/- 1 H POOH. RECOVERED PXN PLUG. TURN WELL OVER TO DSO TO POP. ; t TÆE= WB...LI-EAD = A crUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 4-1/16" CrN ~EVOY OTIS 81.9' 53.99' 6600' 50 @ 9500' 9230' 8800' SS { 'i ,," W-24 Completion 13-318" CSG, 68#, L-80. ID = 12.415' H 2684' ~ I 4-1/2" 12.6# L-80 TC - II Tubing H 8,787' 1 I UniqueOvershotAssy H 8,787' ~ 4-112' Tubing Stub H 8,782' I ......~ Gas Lfft Mandrel #1 8838'~ I TOP OF 7" LNR H 8905' ~ I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 8967' I 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I" 9148' ~ FERFORA TlON SUMMARY REF LOG: SWS-BI-CS-GR ON 08/13/88; SWS CST ON 08/16/88 ANGLE AT TOP PffiF: 48 @ 9274' Note: Refer to Production DB for historical perf data SIZE SFF NTffiVAL OpnlSqz DA lE 3-3/8" 4 9274- 9290 0 08/18/96 5" 12 9296 - 9302 S 09/01/90 3-3/8" 4 9303 - 9330 0 08/18/96 3-3/8" 6 9333 - 9346 0 09/14195 3-3/8" 6 9351 - 9358 0 09/14195 3-3/8" 6 9371 - 9379 0 09/14/95 3-3/8" 6 9395 - 9415 0 10/30/91 5" 6 9430 - 9454 S 09/01/91 5" 12 9506 - 9514 S 09/01/90 FROM DRLG . . 1 2, 105' ~ HES X Nipple ID = 3.813" ~ -------I 8,711' HI-ESX Npple ID= 3.813" 1 ~ 1 8,732' HBaker 9-518" x 4-112" &3 Packer 1 1 8,756' H HES X Nipple ID = 3.813" 1 JI ------J 8866' H4-1/2" PARKffi SWS NP, 10 = 3.813" 1 ¡----- ~ 8873' HOTlS LATCHASSY 1 ~.. 1 8874' H9-5I8" X 4-1/2" OTIS HC PKR, 10= 3.850" 1 I ~I 8954' H4-1/2" OTIS XN NIP, 10 = 3.725" I 896T H4-1/2"TBG TAIL WLEG, 10 = 3.958" I 8956' 1-1 ELMO TT LOGGEO 10/07/90 I 8933' H4-1/2" PARKffi SWS NP, 10 = 3.813" 1 ... 9222' 1-1 MARKER JOINT I Minimum ID = 3.725" @ 8954' 4-1/2" OTIS XN NIPPLE '.-., ~.. I PBTO 1-1 9500' I 1 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 9625' I OAlE 08/19/88 09/24190 03105101 09/08/01 10/07/02 03/14103 REV BY COMI\,£NTS ORlGNA L COMA..ET10N RWO SIS-LG FINAL RNfTP CORRECTIONS ?/TP GLV ENTRY JJ/l1.H GLV C/O OA TE REV BY 9218' HSANNERPIECES 1 co Mv1ENTS PRUDHOE BAY UNrr WB...L: W-24 FERMIT No: 1880700 API No: 50-029-21833-00 SEC 21, T11N, R12E 8P EXploration (Alaska) 1,N111r <-tttCSl Z-QV"t ()~ 1-/15/4- STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 0 Operation Shutdown 0 Perforate 0 Waiver 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 4. Current Well Class: 5. Permit To grill Number D Development D Exploratory 188-070 /' / D Stratigraphic Test aD Service / 6. API Number: / 50- 029-21833-00-00 9. Well Name and Number: PBU W-24/' 10. Field / Pool(s): ADL 028263 Prudhoe Bay Field / Prudhoe Bay Pool 11., '. .. '. ..'. . ';~~Elff.~â~:ØQliØI1ÌQNslN~Y-'. ..' " Total D;~5MD (ft): Total D~~8TVD (ft): I Effective ~~~~h MD (ft): Effective ~~~~h TVD (ft): P~~;3~(~~~~~): Casing. .' ,>~l:~l'\gth - .'. '. ..Siiff+r, . . . Mn¿;j"~~lWO~'~f/'.tT'<'Burst "'. Structural Conductor Surface Intermediate Production Liner 12. Attachments: aD Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name BiIIlsaacson Title Senior Drilling Engineer Si~nature 1. ).Jl- t,'~, Phone 564-5521 Date 1.f1~/~ ~ tOO1m:j,sion(JJ~'Ónly 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 82' 0 Suspend 0 Repair Well IBI Pull Tubing 99519-6612 8. Property Designation: 110' 2684' 9148' 20" 13-3/8" 9-5/8" 706' 7" Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 9274'-9415' 8911'-9003' Packers and SSSV Type: 9-5/8" x 4-1/2" Otis HC packer; 4-1/2" Otis 'HXO' SSSV Nipple April 24, 2004 / Date: 0 Other Junk (measured): 9218' Collçípse 110' 2684' 9148' 110' 2684' 8827' 4930 6870 2270 4760 8919' - 9625' 8671' - 9138' 7240 5410 Tubing Size: 4-1/2", 12.6# Tubing Grade: Tubing MD (ft): L-80 8967' Packers and SSSV MD (ft): 8874' 2123' 13. Well Class after proposed work: D Exploratory D Development aD Service 15. Well Status after proposed work: DOil DGas aD WAG D GINJ D Plugged DWINJ D Abandoned D WDSPL Contact Ken Allen, 564-4366 Prepared By Name/Number: Terrie Hubble, 564-4628 I Sundry Number: 3D 'i- I ò-'f D Plug Integrity D Mechanical Integrity Test Conditions of approval: Notify Commission so that a representative may witness D Location Clearance D BOP Test Other: Test (J ft.¡' . COMMISSIONER RECEIVED APR 1 4 2004 Alaska Oil & Gas Cons. Commission Anchorage ~~~~~~~ION Date 1: /ólf , IIIDMS Bfl Ub~D~I.tq\)ij,\ OR' G 1 t\1 L\ , To: Winton Aubert - AOGCC Date: April 8, 2004 From: Ken Allen - BPXA GPB Rotary Drilling Subject: W-24 Application for Sundry Approval - RWO to replace leaking tubing Approval is requested for the proposed stacker packer re-completion to replace the currently leaking tubing. Sundry approval was received to convert well W-24 to WAG injection 8/03 (reference Sundry # 303-250). Due to various mechanical integrity problems and lack of injectants, no injection has occurred to / date. The well is currently shut in with a tailpipe plug installed due to tubing leaks and a leak at the bottom GLM. Mechanical integrity diagnostic work has been ongoing intermittently since 11/01. Even if all the various leaks and potential corrosion leaks could be patched via non rig intervention, the non premium TDS tubing threads would still be prone to leakage while on MI injection. .- The W-24 RWO is currently scheduled for Doyon 16 beginning around May 15, 2004. The pre-rig work for this RWO will be priority scheduled immediately after the application for Sundry is approved. Scope Pre-Riq Work: 1. RU e-line. Run water flow leak detection log to determine if there is flow past the current production r" packer. 2. RU slickline. Pull XX plug @ 8933', Tag TD while performing drift for Chemical cut. Perform slickline static pressure survey. Set PXN plug in XN nipple ~54'. 3. Pressure test plug, tubing and IA to 3500 psi. 4. Set junk basket on plug at 8954'. 5. RU e-line. Chemical cut the 4-1/2" tubing -8,809' MD. Chemical cut must be in the middle of first full /' 40' joint above GLM#1. These depths are in reference to the Otis tubing tally dated 9/23/90. NOTE: A correction of 12.33' must be added to that tubing tally due to a RKBE error in original well bore. 6. Circulate well to sea water through tubing cut and freeze protect with diesel to -2100'. 7. Test the casing and tubing pack-offs to 5000 psi. Test the OA to 2000 psi. Function all Lock Down Screws. 8. Set BPV and test to 1000 psi. Secure well. Remove the wellhouse. If necessary, level the pad. Riq Operations: 1. MIRUDoyon16 2. Pull BPV. Circulate out freeze protection and displace well to sea watE;r. 3. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. /' 4. Pull 4-1/2" tubing from pre-rig cut. Inspect chemical cut once COHo Cut should be uniform and have minimal flaring. 5. PU Overshot and scraper on DP. RIH, washover to clean possible fill behind tubing stub and dress tubing cut. 6. Test 9-5/8" casing to 4000 psi. / 7. Contingency if 9-5/8" casing pressure test fails. RIH on drill pipe with RTTS and verify leak. W-24 Application for Sundry 8. Run 4-1/2", 12.6# L-80 TCII completion and Unique Machine custom overshot. Swallow 4-1/2" tubing / stub at 8,809'. Space out overshot -2' above no-go point. RILDS. Circulate inhibited sea water and freeze protect well to - 2100'. 9. Drop ball and rod, set PKR, test tubing and annulus to 4000 psi. 10. Set and test TWC to 1000 psi. 11. ND BOPE. NU and test tree to 5,000 psi. Pull TWC. /"'" 12. Set BPV and test to 1000 psi. 13. Secure well and RDMO. Post-RiCl Work: 1. Install well house, flowlines and instrumentation. 2. Slickline retrieve, ball and rod, junk basket and PXN plug. 3. Perforate -40'. 4. Acid Stimulation. 5. Perform water flow log to confirm cement isolation behind 9-5/8" casing. / Estimated Pre-rig Start Date: Estimated RWO Start Date: 04/24/04 05/15/04 Ken Allen Operations Drilling Engineer 564-4366 W-24 Application for Sundry TREE = 4-1/16" CrN . WELLHEAD = McEVOY .0... . we.____.... ". ACTUATOR = OTIS . .. -.--.----.... . .. KB. a.EV = 81.9' BF"" Ei.ËV-= 53.99' "Rap;'; "'----"""'66ÖO' ..... .. e ".........."........ Max Angle = 50 @ 9500' bãiùñî"MD = .-_w"923"ÖÖ Datum lVD = 8800' SS c,u-\\en-r- W-24 / I SAFETY NOTES: 2123' . 13-3/8" CSG, 68#, L-80, ID = 12.415" H r--JI ~ 2684' H4-1/2" OTIS HXO SSSV NIP, ID = 3.813" I GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH 4 3020 2938 0 FLO DMY RK 3 5281 5199 0 FLO DOME RK 2 7079 6982 14 FLO DMY RK 1 8838 8530 42 FLO DMY RK NOTE: LATCH BROKEN ON VALVE IN ST#3 Minimum ID = 3.725" @ 8954' 4-1/2" OTIS XN NIPPLE L . I ~ 8874' 8866' 8873' :8: I TOPOF7"LNRH 8905' ~ I XX Plug 8933' T 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 8967' I ~ 8933' 8954' 8967' 8956' 9-5/8" CSG, 47#, L-80, ID = 8.681" H ~ ~ 9148' PERFORATION SUMMARY REF LOG: SWS-BHCS-GR ON 08/13/88; SWS CBT ON 08/16/88 ANGLEATTOPÆRF: 48 @ 9274' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 9274 - 9290 0 08/18/96 5" 12 9296 - 9302 S 09/01/90 3-3/8" 4 9303 - 9330 0 08/18/96 3-3/8" 6 9333 - 9346 0 09/14/95 3-3/8" 6 9351 - 9358 0 09/14/95 3-3/8" 6 9371 - 9379 0 09/14/95 3-3/8" 6 9395 - 9415 0 10/30/91 5" 6 9430 - 9454 S 09/01/91 5" 12 9506 - 9514 S 09/01/90 9222' I PBTD H -.. ~ 9218' 9500' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 9625' DATE 08/19/88 09/24/90 03/05/01 09/08/01 10/07/02 03/14/03 REV BY DATE COMMENTS REV BY COMMENTS ORIGINAL COMA..ETION RWO SIS-LG FINAL RNlTP CORRECTIONS ?/TP GLV ENTRY JJ/TLH GLV C/O PORT DATE 0 03/14/03 20 0 03/14/03 0 03/14/03 H4-1/2" PARKER SWS NIP, ID = 3.813" I HOTIS LATCH ASSY I H9-5/8" X 4-1/2" OTIS HC PKR, ID = 3.850" I H4-1/2" PARKER SWS NIP, ID = 3.813" I H4-1/2" OTIS XN NIP, ID = 3.725" I H4-1/2" TBG TAIL WLEG, ID = 3.958" I H ELMD TT LOGGED 10/07/90 I -f MARKER JOINT I H SPINNER PIECES I PRUDHOE BAY UNIT WELL: W-24 PERMIT No: 1880700 API No: 50-029-21833-00 SEC21, T11N, R12E BP Exploration (Alaska) TReE = 4-1/16" CrN . W8..LHEAD = McEVOY e_'_m'._- e"---"--m- ACTUATOR = OTIS -- e_- ..e.. ....-.--- KB. ELEV = 81.9' ___'m__""" ,...e- ......_..e BF. ELEV = 53.99' ---~..._me.~ ..__m__'" KOP = 6600' .... -. .. .... .... ... ...... ..... ...... Max Angle = 50 @ 9500' . 'm- . '---"""-"",---""""" ....... Datum MD = 9230' . - c. Datum TVD = 8800' SS W-24 Pre-Rig H4-1/2" OTIS HXO SSSV NIP, ID = 3.813" I 2123' . r-J ~ 13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 2684' GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH 4 3020 2938 0 FLO DMY RK 3 5281 5199 0 FLO DOME RK 2 7079 6982 14 FLO DMY RK 1 8838 8530 42 FLO DMY RK NOTE: LATCH BROKEN ON V A LV E IN ST #3 PORT DATE 0 03/14/03 20 0 03/14/03 0 03/14/03 L Chemical Cut -8,809' I ?~~ Gas Lift Mandrel #1 8838' ~ ~ I TOP OF 7" LNR - 8905' r----¡ - I Slickline retrievable Junk Catcher -10' R XXN Plug 8954' I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 8967' I H4-1/2" PARKER SWS NIP, ID = 3.813" I HOTIS LATCH ASSY I H 9-5/8" X 4-1/2" OTIS HC PKR, ID = 3.850" I 8866' 8873' 8874' H4-1/2" PARKER SWS NIP, ID = 3.813" I 8933' H4-1/2" OTIS XN NIP, ID = 3.725" I 8954' H4-1/2" TBG TAIL WLEG, ID = 3.958" I 1--1 ELMDTTLOGGED10/07/90 I 8967' 8956' ~ ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" - 9148' - MARKERJOINT I 9222' ÆRFORA TION SUMMARY REF LOG: SWS-BHCS-GR ON 08/13/88: SWS CBT ON 08/16/88 ANGLEATTOPÆRF: 48 @ 9274' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9274 - 9290 0 08/18/96 5" 12 9296 - 9302 S 09/01/90 3-3/8" 4 9303 - 9330 0 08/18/96 3-3/8" 6 9333 - 9346 0 09/14/95 3-3/8" 6 9351 - 9358 0 09/14/95 3-3/8" 6 9371 - 9379 0 09/14/95 3-3/8" 6 9395-9415 0 10/30/91 5" 6 9430 - 9454 S 09/01/91 5" 12 9506 - 9514 S 09/01/90 " ~ - SPINNER PIECES I 9218' I PBTD H 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" - 9500' 9625' DATE 08/19/88 09/24/90 03/05/01 09/08/01 10/07/02 03/14/03 REV BY COMMENTS ORIGINAL COMPLETION RWO SIS-LG FINAL RNITP CORRECTIONS ?/TP GLV ENTRY JJ/TLH GL V C/O DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: W-24 ÆRMIT No: 1880700 API No: 50-029-21833-00 SEC21, T11N, R12E BP Exploration (Alaska) TRŒ = 4-1/16" CrN 4 WB..LHEAD = McEVOY KcTDATòR'= -5TIS - e.-- " ..."'."..---.. KB. B..EV = 81.9' --_c. c .. _e~~.- BF. B..EV = 53.99' kop ;-~-_...- -- ---"6600' Max Angle = 50 @ 9500' DäiümMO";;---._-"- 9230' Datum ìVD = 8800' SS W-24 Proposed Completion 4-1/2" HE5 X Nipple, 10 = 3.813", -2,100' 13-3/8" CSG, 68#, L-80,ID= 12.415" H ~ ~ 2684' 4-1/2", 12.6#, L-80 TCII Tubing 4-1/2" HES X Nipple, 10 = 3.813" - 9-5/8" x 4-1/2" BKR 53 PKR -:& Z / 4-1/2" HE5 X Nipple, 10 = 3.813" - -r Unique Overshot Assy =i-d w/ Top TBG stub -8,809' Gas Lift Mandrel #1 8838' ~ - ;::=--¡ I TOP OF 7" LNR H 8905' r--¡ - j - 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 8967' I , I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9148' ~ r.. ÆRFORA TION SUMMARY REF LOG: SWS-BHCS-GR ON 08/13/88; SWS CBT ON 08/16/88 ANGLEATTOPÆRF: 48@9274' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9274 - 9290 0 08/18/96 5" 12 9296 - 9302 S 09/01/90 3-3/8" 4 9303 - 9330 0 08/18/96 3-3/8" 6 9333 - 9346 0 09/14/95 3-3/8" 6 9351 - 9358 0 09/14/95 3-3/8" 6 9371 - 9379 0 09/14/95 3-3/8" 6 9395-9415 0 10/30/91 5" 6 9430 - 9454 S 09/01/91 5" 12 9506 - 9514 S 09/01/90 8866' 8873' 8874' H4-1/2"PARKERSWSNIP,ID=3.813" I HOTIS LATCH ASSY I H 9-5/8" X 4-1/2" OTIS HC PKR, ID = 3.850" I 8933' H4-1/2" PARKER SWS NIP, ID = 3.813" I 8954' H4-1/2" OTIS XN NIP, ID = 3.725" I 8967' 8956' 9222' H4-1/2" TBG TAIL WLEG, ID = 3.958" I H B..MD TT LOGGED 10/07/90 I H MARKER JOINT I Minimum ID = 3.725" @ 8954' 4-1/2" OTIS XN NIPPLE I PBTD H , ~ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 9500' I 9625' I DATE 08/19/88 09/24/90 03/05/01 09/08/01 10/07/02 03/14/03 REV BY COMMENTS ORIGINAL COMA-ErION RWO SIS-LG FINAL RNITP CORRECTIONS ?fTP GLV ENTRY JJfTLH GL V C/O DATE REV BY COMMENTS 9218' H SPINNER PIECES I PRUDHOE BAY UNIT WB..L: W-24 ÆRMIT No: 1880700 API No: 50-029-21833-00 SEC 21, T11N, R12E BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 09/30/03 NO. 2981 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D.S. 5-16B [ qt~ -- [ ~ LDL 09110103 P2-60, )_~ t -COt '\ PROD PROF,LE W/DEFT 09/13103 "'26 i~'~~ PR°D PROF"E 09117103 E-21A SBHP SURVEY 09/16/03 NK-29 PROD PROFILE W/DEFT 09109103 D.S. 3-29 '~ ~ ~q PROD PROFILE W/DEFT 09119103 D.S. ~s-~s ~q~-O(O~ SBHP SU~VE~ 0~/~/03 U-08A I~ - ~~ SBHP SURVEY 09/20103 W-24.. I ~ ~~ ~ / LDL 09123103 D.S. 9-06. ~ ~ I~ ~ PROD PROFILE W/DEFT 09120103 D S 2-08B ' - ~ . . )q3 ~~ 23379 CH Eg,T =CNL 09/3~/03 -23A ~ ... -- 23373 OH EDIT LWD IMPULSE DATA 04~30~03 W-23A~~-~(~ 23373 MDVISION RESISTIVI~ 04~30~03 W'Z3A/~ - .23373 ~D V,S,ON.~S,ST,V,W ' 04/30/03 ~-23A 23373 MD BOREHOLE PROFILE 04/30/03 MPS-0~ ~._1~ J0624637 CH EDIT SCMT GR (PDC) 08109103 MPS-02~~ /~ ~ 23435 SCMT 08109103 MPS-18~~,~ 10559235 CH EDITSCMTGR (PDC) 03103/03 MPS-18/~ ~ '~ 10559235 SCMT 03103103 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth L STATE OF ALASKA 'Oi ALAS OIL AND GAS CONSERVATION C ,,,vlISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonF~ Suspendr"] Operation ShutdownE] PerforateE] varianceE] Annuar Disposalr-~ After Casinc~E] RepairWellr-I Plu,q PerforationsE-] Stimulate['-] Time Extension[-] Other[] Change Approved ProgramE] Pull TubingE] Perforate New Pool~--] Re-enter Suspended WellE] WAG CONVERSION 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development r-~ ExploratoryF] 188-070 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic r"] Service · 50-029-21833-00-00 7. KB Elevation (ft): 9. Well Name and Number: 81.90 W-24 8. Property Designation: 10. Field/Pool(s): ADL 028263 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 9625 feet true vertical 9138 feet Plugs (measured) TD Tagged @ 9439 (01/16/2003) Effective Depth measured 9439 feet Junk (measured) true vertical 9019 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 138' 138' 40K 520 Surface 2656' 13-3/8" 2684' 2684' 80K 2670 Intermediate 9120' 9-5/8" 9148' 8827' 80K 4760 Liner 719' 7" 8906'-9625 8661 '-9138' 80K 7020 Perforation depth: Measured depth: Open Perfs 9274'-9290', 9303'-9330', 9333'-9346', 9351'-9358',9371'-9379', Open Perfs 9395'-9415'. Sqzd Perfs 9296'-9302', 9430'-9454', 9506'-9514'. True vertical depth: Open Perfs 8911'-8922', 8930'-8948', 8950'-8959', 8962'-8966', 8975'-8980', Open Perfs 8991'-9003' Sqzd Perfs 8926'-8930', 9013'-9029', 9062'-9067' Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 8967'. '"' ..... Packers & SSSV (type & measured depth) 9-5/8"x4-1/2" Otis HC PKR @ 8874'. ~" ''~ ..... 4-1/2" Otis HXO SSSV Landing Nipple @ 2123'. ¢~."~'~,' '''~ '',~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: ExploratoryE] Development[--] Service~ Copies of Logs and Surveys run __ 16. Well Status after proposed work: Oil[~ GasE] WAG· GINJF~ WINJF] WDSPLE] Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr I 303-250 Printed Name DeWayne R. Schnorr Title Techical Assistant Signature ,~"~'~g,~,~z..-' ,4~~C~->¢'/ Phone 907/564-5174 Date Sept22,2003 Form 10-404 Revised 2/2003 0 R!GINAE W-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/24/2003 FIRST IN]ECTOIN TEST FOR WELL W-24 THAT WAS REPORTED IN OMAR AS AN INJECTION WELL. 09/22/2003 UPDATE AS OF 09/22/2003. EVENT SUMMARY 0~2~03 FIRST WATER INJECTOIN TEST FOR WELL W-24 THAT WAS REPORTED IN OMAR AS AN INJECTION WELL. O9/22/O3 NO WATER OR MI HAS BEEN INJECTED INTO THIS WELL SINCE THE FIRST INJECTION TEST. FLUIDS PUMPED BBLS 0 TOTAL Page 1 L STATE OF ALASKA 'O!' ALAS OIL AND GAS CONSERVATION C ,..¢IlSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE] Suspend[~ Operation Shutdownl"-I PerforateD vafianceE] Annuar Disposalr-~ After Casin.a["l Repair WellE] Plum Perforations~"] stimulate[-~ Time ExtensionD Other. Change Approved Programr'-~ Pull mubing[~ Perforate New PoolE] Re-enter Suspended WellE] conversion to WAG 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development [~ Exploratory[-1 188-070 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic r-~ Service[] 50-029-21833-00-00 7. KB Elevation (ft): 9. Well Name and Number: 81.90 W-24 8. Property Designation: 10. Field/Pool(s): ADL 028263 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 9625 feet true vertical 9138 feet Plugs (measured) Tagged TD @ 9439 (01/16/2003) Effective Depth measured 9439 feet Junk (measured) true vertical 9019 feet Cas in g Length Size M D TV D B u rst Col lapse Conductor 110' 20" 138' 138' 40K 540 Surface 2656' 13-3/8" 2684' 2684' 80K 2670 Intermediate 9120' 9-5/8" 9148' 8827' 80K 4760 Liner 719' 7" 8906'-9625' 8661'-9138' 80K 7020 Perforation depth: Measured depth: Open Perfs 9274'-9290', 9303'-9330', 9333'-9346', 9351'-9358', 9371'-9379'. Open Perfs 9395'-9415' Sqzd Perfs 9296'-9302', 9430'-9454', 9506'-9514'. True vertical depth: Open Perfs 8911'-8922', 8930'-8948', 8950'-8959', 8962'-8966', 8975'-8980', Open Perfs 8991'-9003', Sqzd Perfs 8926'-8930', 9013'-9029', 9062'-9067' Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 8967'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" Otis HC Packer @ 8874'. 4-1/2" Otis HXO SSSV Nipple @ 2123'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubi,ng Pressure Prior to well operation: 0 850 Subsequent to operation: 1201 850 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentE] Service~ Copies of Logs and Surveys run ~ 16. Well Status after proposed work: oiil-"l Gasl-'l WAG~ GiNJI--I WiUJl--I WDSPLE] Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: Contact DeWayne R. Schnorr I N/A Printed Name DeWavne R. Schnorr -- Title Techical Assistant Signature ,~,-~.~~, '~)~.~,.~ Phone 907/564-5174 Date_. S epL12'~2._003 Form 10-404 Revised 2/2003 021GiNAL 08/12/2003 08/13/2OO3 08/14/2003 08/15/2OO3 08/20/2003 08/21/2003 08/26/2003 08/28/2003 09/13/2003 09/16/2003 08/12/O3 08/13/O3 08/14/03 08/15/03 O8/2O/O3 08/21/03 O8/26/O3 O8/28/O3 W-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COMM (AC-EVAL AND REPAIR) ANN-COMM (AC-EVAL AND REPAIR) ANN-COMM (AC-EVAL AND REPAIR) ANN-COMM (AC-EVAL AND REPAIR) ANN-COMM (AC-EVAL AND REPAIR) ANN-COMM (AC-EVAL AND REPAIR) ANN-COMM (AC-EVAL AND REPAIR) INITIAL INJECTION TEST. : TUBING TAIL PLUG : TUBING TAIL PLUG : TUBING TAIL PLUG : AC-BLEED; AC-FLUID LEVEL : AC-CMIT TXIA; AC-LLRT : AC-CMIT TXIA; AC-LLRT : AC-LLRT ANN-COMM (AC-EVAL AND REPAIR): AC-FLUID LEVEL WELL SHUT-IN, INJECTION PRESSURE, PSI: 0 TYPE: PW Vol: 0 EVENT SUMMARY ** WELL FOUND SHUT IN UPON ARRIVAL** PULLED 4 1/2" WHIDDON CATCHER SUB FROM 5472' SLM. ***WELL FOUND S/I ON ARRIVAL*** (AC-EVAL AND REPAIR). PULL 4 1/2" SLIP STOP C/S @ 5480' SLM. BAIL FILL OFF TOP OF TTP. EQUALIZE TTP @ 8940' SLM. CURRENTLY RUNNING IN HOLE W/4-1/2" GS TO PULL TTP. PULL TTP FROM XN @ 8935' SLMD. SET 4 1/2" XX @ 8919' SLM ( MAX PSI WHEN SET - 350 PSI, 25" OAL). PT TTP TO 650 PSI - GOOD TEST - BLED DOWN TO 300 PSI. ** LEFT WELL SHUT IN ** T/I/O:350/840/0. BLEED IA & TBG (PRE-CHIT); INITIAL IA FL @ 1440' (77 BBLS). TBG FL @ 100' (2 BBLS). BLED IA FROM 840 PSI TO 350 PSI AND THE TBG PRESSURE DROPPED TO 200 PSI. SI, BLEED AND MONITORED FOR 30 MINUTES AND BOTH THE TBG & lAP INCREASED 20 PSI. FINAL WHP's-220/370/0. T/I/O= STARTED TO LOAD IA FOR CHIT. T/I/O = 300/480/0. CHIT - T x IA FAILED. (PRE RWO). PRESSURED TBG AND IA TO 2500 PSI AND STARTED 30 MINUTE TEST. TBG AND IA LOST 300 PSI IN 15 MINUTES. RE-PRESSURED TO 2500 PSI. TBG/IA LOST 480 PSI IN THE FIRST 15 MINUTES AND 140 PSI IN THE SECOND 15 MINUTES. RE-PRESSURED TO 2500 PSI. TBG/IA LOST 280 PSI IN THE FIRST 15 MINUTES AND 100 PSI IN THE SECOND 15 MINUTES. BLED PRESSURES BACK. FINAL WHP's = 550/420/200. T/I/O = 300/300/60 LLRT IA TO TBG. AT 2500 PSI .PUMPED TOTAL OF 74 BBLS DEAD CRUDE. RETURNS TO W-200 F.L. LLRT -- 4.5 BPM @ 1300 PSI. FINAL WHP - 250/0/160 INITIAL WATER INJECTION TEST. Page 1 W-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/13/O3 T/I/O=650/260/10. TEMP = SI. TBG & IA FL. (LEAK DETECTION LOG). TBG FL @ 940' (14 BBLS). IA FL @ SURFACE. FLUIDS PUMPED BBLS 1 DIESEL FOR P/T OF SURFACE EQUIPMENT 213 CRUDE 214 TOTAL Page 2 STATE OF ALASKA (' J'~¢;/-~ <J;:~/Z~/.~ 2O AAC 25.28O 1. Type of Request: Abandon C~ Suspend [] Operation Shutdown D Perforated variance• Annuar DisposalF1 Alter Casinq [] Repair Well ~ Pluq Perforations [] Stimulate[] Time Extension• Other. Chanqe Approved Proqram ~ Pull Tubinq [] Perforate New Pool [] Re-enter Suspended Well• CONVERSION-WAG 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development, Exploratory[~ 188-070 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic [--I Service[--I 50-029-21833-00-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 81.90 W-24 / 8. Property Designation: 10. Field/Pool(s): ADL 028263 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):9625 ITotal Depth TVD (ft): IEffective Depth MD (ft): IEffective Depth TVD (ft): IPlugs (measured): I Junk (measured):0138 9439 (01/16/2003) 9019 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 110' 20" 138' 138' 40K 520 Surface 2656' 13-3/8" 28' - 2684' 28' - 2684' 80K 2670 Intermediate 9120' 9-5/8" 28' - 9148' 28' - 8827' 80k 4760 Production 719' 7" 8906' - 9625' 8661' - 9138' 80K 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: I Tubing Grade: Tubing MD (ft): 9274' - 9514' 8911' - 9067' 4-1/2", 12.6#I L-80 8967 ckers and SSSV Type: Packers and S.SS%MD (ft): -5/8"x4-1/2" Packer; 4-1/2" Otis HXO SSSVN Packer @~1~'7,.. '4~', SSSVLN @ 2123' 12. Attachments: Description Summary of Proposal. 13. Well Cla'~-~fter~ proposed work: Detailed Operations Program [-] BOP Sketch [~ Exploratoryr-] DevelopmentF~ Service, 14. Estimated Date for September, 2003 / 15. Well Status after proposed work: Commencin.(:] Operation: Oil r'-] Gas ~ Plugged r-~ Abandoned r-~ 16. Verbal Approval: Date: WAG~ GINJE] WINJE~ WDSPLF"] Commission Representative: Perpared by DeWayne R. $chnorr 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Amy Frankenburg Printed Name Amy Frankenbur~l Title Senior Engineer Signature ~....,,_~ ~_ .. ~ .......~ Phone 907/564-4503 Date Jun 19~ 2003 0 Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ c..~- 2 ~"(-~ Plug Integrity r'~ BoP Testr-] Mechancial Integrity Test[~ Location Clearance[--~ / Other: M-~T'" v-¢~ i.c,~'l~' · ..... / , ',i Subsequent Form Required: i O "" ~ O ~ , r' Approved by: COMMISlONER THE COMMISSION Date: BFL CANNED SEP 0 2, 2003 Form 10-403 Revised 2/2003 SUBMIT IN DUPLICATE bp BP Exploration (Alaska), Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, Alaska 99519-6612 (907)561-5111 22August 2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry notice for W-24 swap from producer to WAG injection BP Exploration Alaska, Inc proposes the following wellwork to prepare to swap W-24 from production to WAG (water alternating gas) injection with MI start-up estimated to occur in September, 2003 1 S 2 O 3 S 3 O set tubing tail plug CMIT (to test casing integrity. If CMIT passes, continue) run patch over broken latch in GLM #3 to restore tubing integrity MITIA to 4000 lbs. (witnessed by AOGCC) W-24 is shut in now due tubing integrity issues associated with a broken latch on GLV #3. The / plan forward is to test casing integrity and restore tubing integrity via running of a tubing patch. Facility tie-in as a WAG injector will be complete in September 2003. Once tubing integrity is restored, W-24 will be put on injection beginning with a slug of MI. A copy of the wellbore diagram is attached. Please contact Amy Frankenburg at 564-4503 with any questions Sincerely, Amy Frankenburg ~' EWE Production Engineer ACF (8/22/2003) 1 of 1 TREE = 4-1/16" CEN WR LI-EAD = McEVOY W24/ISAFETY NOTES: I A~U~ = OTi~ -- KB. F_LEV = 81.9' BF. ELEV = 53.99' KOP = 6600' ' H Max Angle = 50 @ 9500'.... I 2123' 4-1/2" OTIS HXO SSSV NIP, ID = 3.813" Datum MD = 9230' W Datum TVD = 8800' SS ST MD '[VD DEV TYPE VLV LATCH PORT DATE 4 3020 2938 0 FLO DMY RK 0 03/14/03 3 5281 5199 0 FLO DOME RK 20 ,-,. J 2 7079 6982 14 EEO DMY RK 0 03/14/03 Minimum ID 3.725" 8954' 1 8838 8530 42 FLO DMY RK 0 03/14/03 4-112" OTIS XN NIPPLE NOTE: LATCH BROKEN ON VALVE~N ST~3 J J J 8868' H4-1/2" PARKER SWS NP, ID = 3.813" I ~ 8873' HOTISLATCHASSYJ X ~ J 8874' HO-5/O"X4-1/Z'OTISHCPKR, ID=3.850"I I I ~O" OF 7" LNR H 8905' I B ~ J J J 8933' H4-1/2,,PARKER SWS NP, ID= 3.813" J I I J 8954' H4-1/2"OTISXNNIP, ID=3.725"J i J4-U2"TBG, 12.6#, L-80, .0152 bpf, ,D = 3.958"H 8967'I 18987' H4-U2"TBGTA,LWLEG,,D=3.958"J J 8956' H ELMD TT LOGGED 10/07/90 I I ~-~,~" L-80, ID =8.681" H 9148' ~ · {' J 922Z H MARKER JOINT J PERFORATION SUMMARY r 1 REF LOG: SWS-BHCS-GR ON 08/13/88; SWS CBT ON 08/16/88 J J L J ANGLE AT TOP PERF: 48 @ 9274' Note: Refer to Production DB for histodcal perf data Jl ' SIZE SPF NTERVA L Opn/Sqz DATE 3-3/8" 4 9274 - 9290 O 08/18/96 ri 5" 12 9296- 9302 S 09/01/90 Jl 3-3/8" 4 9303 - 9330 O 08/18/96 3-3/8" 6 9333 - 9346 O 09/14/95 3-3/8" 6 9351-9358 O 09/14/95 3-3/8" 6 9371-9379 O 09/14/95 3-3/8" 6 i 9395-9415 O 10/30/91 Il II 5" 12 9506 - 9514 S 09/01/90 H 9500' I I 7" LNR, 26~, L-80, .0383 bpf, ID = 6.276" 9625' DATE REV BY COMIVENTS DATE REV BY COIVIVIENTS PRUDHOE BAY UNIT 08/19/88 ORIGNAL COMFLETION WELL: W-24 09/24/90 RWO PERIVIT No: 1880700 03/05/01 SIS-LG FINAL APl No: 50-029-21833-00 09/08/01 RNfTP CORRECTIONS SEC 21, T11N, R12E 10/07/02 ?/TP GLV 13~ITRY 03/14/03 JJ/TLH GLV C/O BP Exploration (Alaska) PERFORATION SUMMARY REF LOG: SWS-BHCS-GR ON 08/13/88; SWS CBT ON 08/16/88 ANGLE AT TOP PERF: 48 @ 9274' Note: Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE 3-3/8" 4 9274 - 9290 O 08/18/96 5" 12 9296- 9302 S 09/01/90 3-3/8" 4 9303 - 9330 O 08/18/96 3-3/8" 6 9333 - 9346 O 09/14/95 3-3/8" 6 9351 - 9358 O 09/14/95 3-3/8" 6 9371 - 9379 O 09/14/95 3-3/8" 6 9395 - 9415 O 10/30/91 5" 6 9430- 9454 S 09/01/91 5" 12 9506 - 9514 S 09/01/90 . i <f- o7o !~?_.LL DATA ~D: 9~g ..~D.. 9I.Z{ YVD; ?BTB: 9q{9 ~ 9o/~ ~ Casing: ~.s/{" Shoe: 9/9~ ~ {~z7 ~; DY: ..... ~ -r~ Liner' 7'~ Shoe: ~&gf ~ ~[~{ ?~; %0~. ~o~l-m ~/ TVD Tub~=. g-'/~ Packer {~ ~ T'~; Sen an {{7~ . Annulus Press Test: ; !5 rain ; 30 mit ~w~_~CH;_Nv_C>J~ ZNTEGRZTY - PART ~2 Cemenn Volumes:- A~nt Liner . Cement Bond Log (Yes or No) '¥' ; In AOGCC File Production Log: Type Evaluation ALASKA OIL AND GAS CONSERVATION COMMISSION 'REPORT SUNDRY WELL OP[-'IATIONS 1. Operations performed: Operation shutdownm Stimulate X Plugging Perforate~ Pull tubing Alter casing Repair well__ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_c~e, Alaska 99519-6612 4. Location of well at surface 521' SNL, 1178'WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 626' NSL, 775' WEL, SEC. 16, T11N, R12E, UPM At effective depth 890' NSL, 625' WEL, SEC. 16, T11N, R12E, UPM At total depth 920' NSL, 608' WEL, SEC. 16, T11N, R12E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 81.90 AMSL 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number W-24 (44-16-11-12) PBU 9. Permit number/approval number 88-70 / 10. APl number 50- 029-21833 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9625 feet Plugs (measured) BKB 9138 feet 9580 feet Junk (measured) BKB 9109 feet Casing Length Size Cemented Structural -- Conductor 110 20 8 c.v. Surface 2656 13 3/8 3923 c.f. Intermediate 9120 9 5/8 1792 c.f. Production -- Liner 719 7 236 c.f. Perforation depth: measured 9395'- 9415', 9430'- 9454' true verticalsubsea 8909;8947' (two intervals) Measured depth 138 2684 9148 8906-9625 Tubing (size, grade, and measured depth)3 1/2" L-80 to 8827' with 3 1/2" tailpipe to 8936' Packers and SSSV (type and measured depth)9 5/8" TlW packer at 8827'; 3 1/2" SSSV at 20890' 13. Stimulation or cement squeeze summarysee attachment True vertical depth BKB 138 2684 8827 8661-9138 Intervals treated (measured) Treatment description including volumes used and final pressure ORI61NAL 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 680 1058 306 1094 480 754 114 792 261 225 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Ope~,ctions OiK Gas Suspended 17. I he~y~ify., tl~t the/tr.C're~going is tx and correct to the best of my knowledge. Sig ........ _ Title Technical Assistant IV Form 10-404 Rev 06/15/68 Service Date//h//¢¢ SUBMIT IN DUPLICATE W-24 DESCRIPTION OF WORK COMPLETED Stimulation Operation 06/22/99 Mud Acid Stimulation was performed using the following fluids: SUMMARY SI well at 4:30 am to allow fluids to stabilize (as per PE manual). MIRU Dowell and TRICO. Line up and pump down annulus and coil for cooldown stage. MU and RIH w/BHA #1. Tag bottom and adjust depth to last S/L tag 9,424'. Wait for acid crew. Begin pumping 1st HCI/Xylene stage. Begin reciprocating with acid at nozzle making four passes with both DAD acid and 4 passes with Mud acid over interval from 9,250'-9,425' (20 fpm). See gradual pressure rise with DAD acid on zone and weight gain while pulling through perfs which dropped off as the nozzle got above them - (catching on something?). Pump Mud acid followed by NH4CI displacement - pressure steady. With half of the 150 bbl NH4CI stage pumped S/D and drop ball and open circ sub. Park coil at 9,200', pump remainder of NH4CI and start in with diverter stage. See coil pressure increase as diverter passed through nozzle but little pressure response on the wellhead gauge. There was a gradual pressure increase of about 120 psi but no sign of break-back. Continue on with 2nd DAD acid stage and Mud acid stage. Noted drop in pressure with 2nd Mud acid stage on zone (~140 psi). Complete 2nd NH4CI stage and go into 2nd diverter stage. See gradual 20 psi increase as diverter went into perfs with no break back. WHP began to gradually increase with about 50 bbl of the 3rd stage of DAD acid out the nozzle and continued through 50 bbl into the last Mud acid stage (500 psi total increase) where pressure dropped -200 psi in 7 bbls. Pressure then gradually dropped throughout NH4CI displacement. WHP decreased to 410 psi and held steady. Switch to coil pump for remainder of displacement. Pressure increased to just over 1,000 psi and gradually dropped throughout the rest of displacement. SD RDMO Dowell and turn well over to TRICO. Fluids Pumped BBLS. Description 810 Freshwater w/3% NH4CI-'----'----~"--" '"--- - 216 12/10 HCI/Xylene (DAD Acid) 210 9/1 Mud Acid ~0'/ 33 Slurry of wax beads (600# of beads + 30 ppt HEC) Aj~lL~0i.!&G~C~n~.C~rnmi~ion Anchorage 1269 Total Pumped LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: B'06 (41-31-11-14) DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF CCL FINAL BL+RF CCL FINAL BL+RF Run ~ 1 ECC No. 4475.07 Run $ 1 4588.03 Run # 1 5602.04 Run $ 1 6079.04 Run W 1 6451.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 / Anchorage, AK 99518 Or, to (907) 563-7803 Received by:_ / ~-~- Date: Please sign andreturn~o~ Petrotechnical Data Cente: BP Ex,!oration (Alamka) In$ 900 East Benson Boulevard Anchorage, Alaska 99508 aecetVed b~ ............. " STATE OF ALASKA ALA,.SKA OIL AND GAS CONSERVATION COMMIS~,~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X' Pull tubing Alter casing Repair well Other (,~,~,, 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or BP Exploration (Alaska) Inc. Development × KBE= 81.90 Exploratory 7. Unit or Property name /~" I 3. Address Stratigraphic P. O. Box 196612, Anchorage, Alaska 99519-6612 Service Prudhoe Bay Unit 4. Location of well at surface 521'SNL, 1178' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 626' NSL, 775'WEL, SEC. 16, T11N, R12E, UPM At effective depth 890'NSL, 625' WEL, SEC. 16, T11N, R12E, UPM At total depth 920' NSL, 608' WEL, SEC. 16, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 9625feet true vertical BKB 9138feet Effective depth: measured 9580feet true vertical BKB 9109feet 8. Well number W-24 (44-16-11-12) PBU 9. Permit number/approval number 88-70/ 10. APl number 50- 029-21833 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20 8 c.y. 138 138 Surface 2656 13 3/8 3923 c.f. 2684 2684 Intermediate 9120 9 5/8 1792 c.f. 9148 8827 Production -- Lin er 719 7 236 c.f. 8906-9625 8661-9138 Perforation depth: measured 9395'- 9415', 9430'- 9454' true vertical subsea 8909'-8947' (two intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 8827' with 3 1/2" tailpipe to 8936' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 8827';3 1/2" SSSVat 20890' ~ F C F i V 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) M AR 1 5 199; Alaska 0il & Gas Cons. Treatment description including volumes used and final pressure Anchorage 14. Prior to well operation Subsequent to operation Re_oreserltatiye Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 680 1058 306 1094 480 754 114 792 Tubing Pressure 261 225 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby c~rtify that the forego.~g is true a~nd correct to the best of my knowledge. Sl'gned r,_ ~ ~(:~v-~,S/,~, t,. // ~ . d_..t.q.,-L~2 Title Senior TechnicalAssistant I Form 10-404'Rev 06/15/88 ,f~ Date SUBMIT IN DUPLICATE 9/24/91 9/25/91. 9/26/91 ~ELL W-24(44-16-11-12) NRWO/Reperf/Frac A NRWO was performed using the following fluids: FLUIDS: SQUEEZE #1 405 bbls PW to Load Well 5 bbls PW 24 bbls ACID 37 bbls PW 5 bbls EW(Preflush) 16 bbls Cement 24 bbls EW(Spacer) 40 bbls DUO Polymer(Contaminant) 205 bbls PW(Displacement) 48 bbls ACID 100 bbls PW 35 bbls MEOH(Freeze Portection CT) Well Cleaned Out to 9500" 449 bbls Load fluid behind pipe 9 bbls Cement Recovered ACID: 15% HCL/10% Xylene,.l% WS-36, .4% HAI-85, .45% Ferckek-A ACID to Free Stuck Pipe: 15% HCL CEMENT: 15.5 ppg class g cement containing, .2% CFR-3, .012% HR-12, .15 GAL/SK HALAD-344L ABORTED SQZ #1 A NRWO was performed using the following fluids: FLUIDS: 121 bbls PW to load well 5 bbls EW(Preflush) 12 bbls Cement 24 bbls EW(Spacer) 15 bbls Duo Polymer(Contaminant) 32 bbls PW(Displacement) 181 bbls PW(Reverse Out) 38 bbls PW(Jet Pass) 53 bbls PW(Final Reverse Out) 32 bbls MEOH(Freeze Protection CT) [~ E C E iV E D 10 bbls MEOH(Freeze Protection FL) Well Cleaned Out to 9454' 141 bbls load fluid behind pipe 8 bbls cement recovered Anchorage CEMENT: 15.5 ppg class g cement containing, .2% CFR-3, .017% HR-12, .235 GAL/SK HALAD-344 L SQZ #2 M AR 1 § t993 Alaska 0tl & Gas Cons. Comrms~ A NRWO was performed using the following fluids: 95 bbls PW to load well 5 bbls EW(Preflush) 12 bbls Cement 24 bbls EW(Spacer) 15 bbls Duo Polymer 17 bbls PW(Displacement) 222 bbls PW(Reverse Out) 83 bbls PW(Jet Pass) Page 2 WELL W-24(44.16-11.12) 38 bbls PW(Final Reverse Out) 32 bbls MEOH(Freeze Protection CT) Well Cleaned Out to 9414' 0 bbls load fluid behind pipe today Cement: 15.5 PPG Class G Cement Containing, .2% CFR-3, .012% HR-12, .15 GAL/SK HALAD-344L SQZ #3 9/29/91 A NRWO was performed using the following fluids: Fluids (#1/#2) 132 bbls PW to load well 05 bbls EW(Preflush) 12 bbls Cement 24 bbls EW(Spacer) 19/15 bbls Duo Polymer(Contaminant) 13/19 bbls PW(Displacement) 160 bbls PW(Reverse Out) 29 bbls PW(Jet) 160 bbls PW(Final Reverse Out) 32 bbls MEOH(Freeze Protection CT) 45 bbls MEOH(Freeze Protection Well) 10 bbls MEOH(Freeze' Protection Flowline) Well Cleaned Out to 9052' 4 bbls Cement Recovered CEMENT: 15.5 ppg Class G Cement Containing, .2% CFR-3, .012% HR-12, .15 Gal/SK Halad-344 L SQZ#4, SQZ#5 10/30/91 The following intervals were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9395' - 9415' MD 12/24/9 1 A Hydraulic Fracture Treatment was performed using the following fluids: DATA FRAC: 75 bbl 50# X-Link Ge1(63.2 bbl behind pipe) Treating pressure:4619 FRAC: 260 bbl 20# Linear gel, 8 bbt 50# Linear gel 75 bbl 50# Cross Linked gel, 142.7 bbl 20# linear gel 75 bbl Diesel(prime up & freeze protect) 10/11/92 fjh R£¢EIVED MAR 1 5 1993 Alaska Oil & I~as liOnS. {30illITiiSSi°" Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/05/91 T# 82969 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. W-24 ~D~D COMPLETION 10/30/91 #1 S-26~? PRODUCTION LOG 10/31/91 #1 8800.00- 9393.00 SCH 8850.00- 9052.00 $CH Information Control Well Records Adrian J. Martin STATE OF ALASKA !, :i:~ ,~ - ALASKA OIL AND GAS CONSERVATION COMMISSION :~ ~.~i ~- REPORT OF SUNDRY WELL OPERATION 1. Operations performed: Operation shutdown Pull tubing X Stimulate X Plugging Perforate X Alter casing Repair well Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 521' SNL, 1178' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 626' NSL, 775' WEL, SEC. 16, T11N, R12E, UPM At effective depth 890' NSL, 625' WEL, SEC. 16, T11N, R12E, UPM At total depth 920' NSL, 608' WEL, SEC. 16, T11N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical /il~ska O# & Gas Cons. .Commission AnChorage 9625feet Plugs (measured) 9138feet BKB 6. Datum elevation (DF or KB) KBE = 81.90 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-24 (44-16-11-12) PBU 9. Permit number/approval number 88-70 / 90-693 10. APl number 50- 029-21833 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 9500feet Junk (measured) 9058feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth 138 2684 9148 110 20 8 c.y. 2656 13 3/8 3923 c.f. 9120 9 5/8 1792 c.f. 719 7 236 c.f. 8906-9625 9296'- 9302', 9395'- 9415', 9430'- 9454', 9506'- 9514' True vertical depth BKB 138 2684 8827 8661-9138 true vertical subsea 8844'- 8848', 8909'- 8922', 8931'- 8947' 8980'- 8985 Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 to 8967' Packers and SSSV (type and measured depth) 9-5/8" Otis packer at 8874'; 3 1/2"Otis SSSV at 2123' 13. Stimulation or cement squeeze summary Acidize perfs w/63 bbls 15% HCL Intervals treated (measured) 9296'- 9302', 9395'- 9415', 9430'- 9454', 9506'- 9514' Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 760 1524 638 1326 740 896 484 1259 Tubing Pressure 286 276 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. Sicjned .~_~._ f~L~ ~/~~ Title SupervisorWorkover/Completions Form 10-404 Rev 06/15/88 .. Date SUBMIT IN DUPLICATE Attachment I Well W-24 Work~ver: Accepted rig at 1000 hours on 9/5/90. Pulled 3-1/2" tubing. Milled and recovered 9-5/8" packer. Circulated well to filtered brine. Cleaned out liner to 9568'. Perforated intervals, 9296' - 9302' and 9506' - 9514'. Tested liner lap and 9-5/8" casing to 3000 psi, ok. Performed pre- squeezed acid job. Performed cement squeeze job on all perforations. RIH with 6" bit and cleaned out to 9500'. Pressure tested perforations to 2000 psi. Middle set of perforations leaked. RIH and re-squeezed perforations to 2500 psi. RIH with 6" bit and 7" scraper and cleaned out to 9500'. Pressure tested squeeze perforations to 2000 psi, ok. Changed well over to filtered brine. Perforated well with underbalance drill pipe conveyed guns. Changed well over to clean filtered brine. RIH with 7" test packer on 4-1/2" tubing and 5" drill pipe. Pickled the drill pipe. Performed fracture treatment. Formation screened off with 7 ppg frac fluid. Reverse circulated sand out from 9000' to PBTD. Changed well over to filtered inhibited brine. Ran 4-1/2" completion. Set packer and tested tubing with 3000 psi. Tested annulus to 2500 psi, ok. Released rig at 0300 hours on 9/24/90. 18.7 Days DAILY WORKOVER REPORT: PRUDHOE BAY UNIT '~o "~mis~io~ As of 0600 Hrs. Thursday. Sgptember 6. ~ 990 WELL: W-24 (44-16-11-12),, Rig' Ogyon Rig ~16 Day' 1_. Expense AFE Number: Expense AFE Amount = 145023 Current Field Costs = Estimated Final Cost = Current Ooeration' Pulling 3-1/2" tubing. Summary. of Last 24 Hours Accepted rig at 1000 hours on 9/5/90. MIRU. Circulated diesel from tubing and annulus. ND tree and NU BOP's. Reviewed By: ~'.~-.., BP EXPLORATION (ALASKA), INC. DAII.Y WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Friday. September 7, 1990 WELL: W-24 (44-16-11-12) Rig: Doyon Rig #16 Day: 2. Expense AFE Number: Expense AFE Amount = 1,4.5023 Current Field Costs = Estimated Final Cost = Current Operation' RIH with PRT and packer mill. Summary of Last 24 Hours Pulled 3-1/2" tubing. RIH and recovered slick stick. Reviewed By: ~,., ~.. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Monday. September 10. 1990 WELL: W-24 (44-16-11-12), Rig: D0yon Rig #16 Day: 5 Expense AFE Number: Expense AFE Amount = 145023 Current Field Costs Estimated Final Cost Current Operation: . Recovering packer. ,Summary_ of Last 72 Hours RIH with PRT and packer mill to top of packer at 8818'. Found fill on top of packer. POH. RIH with burning shoe to top of fill. Work through fill and mill on packer. RIH with new mill and push packer to top of liner. RIH with spear and attempted to recover packer. No fish recovered. RIH with overshot and attempted to recover packer. No fish recovered. RIH with new spear to top of packer. Reviewed By: ~-~., BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Tuesday, September 11, 1990 WELL: W-24 (44-16-11-12) Rig: Doyon Rig #16 Day: 6 Expense AFE Number: Expense AFE Amount = 145023 Current Field COsts = Estimated Final Cost = Current Operation: Cleaning out 7" liner. Summary of Last 24 Hours RIH with spear and recovered packer. RIH with 8-1/2" bit and 9-5/8" scraper to liner top. RIH with 6" bit and 7" scraper to 9288'. Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday. September 12. 1990 WELL: W-24 (44-16-11-12~ Rig: Doyon Rig #16 Day: 7_ Expense AFE Number: Expense AFE Amount = 145023 Current Field Costs = Estimated Final Cost = Current OperatiQ.n: RIH with new mill. Summary of Last 24 Hours Reamed to 9443'. RIH with junk mill and ream to 9452'. Reviewed By' ~:.~. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAy UNIT As of 0600 Hrs. Thursday, September 131 1990 WELL: W-24 (44-16-11-12) Rig: D(~yon Rig #16 Day: 8 Expense AFE Number: Expense AFE Amount = 160549 Current Field Costs = Estimated Final Cost = Current Operation' POH. Summary_ of Last 24 Hours Milled on junk from 9451'- 9568'. RIH with 6" bit and 7" scraper. Circulated well to filtered brine. Reviewed By: ~'.l-~ · BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Fricl~,y. SeDtember 14. 1990 WELL: W-24 (44-16-11-12) Rig: Doyon Rig #16 Day: 9 Expense AFE Number: Expense AFE Amount = 160549 Current Field Costs = Estimated Final Cost = Current Qperation: RIH with 3-1/2" drillpipe and perform cement squeeze. Summary_ of La, st 24 Hours RIH with 5" wireline conveyed perforating guns. Perforated intervals, 9296' - 9302' and 9506' - 9514'. RIH with 7" RTTS and tested liner lap and 9-5/8" casing to 3000 psi, ok. Reset 7" RTTS at 9480' and attempted to establish circulation. POH. Reviewed By: ~ ~'. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Monday. September 17. 1990 WELL: W-24 (44-16-11-12) Rig: Dgyon Rig .'/fl 6, Day: 1 2 Expense AFE Number: Expense AFE Amount = 160549 Current Field Costs = Estimated Final Cost = Current Operation' Change well over to clean filtered brine. Summary of Last 72 Hours Performed pre-squeezed acid job. Performed cement squeeze job on all perforations. RIH with 8-1/2" bit and 9-5/8" scraper to liner top. RIH with 6" bit and cleaned out to 9500'. Pressure tested perforations to 2000 psi. Middle set of perforations leaked. RIH and resqueezed pedorations to 2500 psi. RIH with 6" bit and 7" scraper and clean out to 9500'. Pressure tested squeeze perforations to 2000 psi, ok. LD Reviewed By: ~'.~. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: .I?RUDHOE BAY UNIT As of 0600 Hrs. Tuesday. September 18. 1990 WELL: W-24 (44-16-11-12) Rig' D0Y0n Rig #16 Day: 1 ~ Expense AFE Number: Expense AFE Amount = 1605,1.9 Current Field Costs = Estimated Final Cost = Current Ooeration: Perforating Summary of Last 24 Hours Changed well over to filtered brine. RIH with 5" drilllpipe conveyed perforating guns. RIH with GR/CCL and position guns. Rig up control head and floor manifold. Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday, Se0tember 19. 1990 Day: WELL: W-24 (44-16-11-12). Rig: 14 D0y0n Rig #16 Frac. AFE Number: Expense AFE Number: Expense AFE Amount = F[i7W24 Current Frac. Cost= Estimated Final Frac.= Current Field Costs = Estimated Final Cost = Current Operation: POH with 5" ddllpipe. Summary of Last 24 Hours - Perforated well with underbalance drillpipe conveyed guns. Changed well over to clean filtered brine. RIH with 7" test packer on 4-1/2" tubing tubing and 5" ddilpipe. Could not passs thru liner top. Reviewed By: ~.'~. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Thur~da, y, $,eptember 20. 1990 Day: WELL: W-24 (44-1,6-11-!2~ Rig: , 15 Doyon Rig #16. Frac. AFE Number: Expense AFE Number: Expense AFE Amount = Current Ooeration: POH. Summary of Last 24 Hours F~;7W24 1605_49. Current Frac. Cost= Estimated Final Frac. = Current Field Costs = Estimated Final Cost = Lay down 5" drillpipe and 4-1/2" tubing. Change out crossover. RIH with 4-1/2" tubing and 5" drillpipe. Pickled the driilpipe. Performed fracture treatment. Formation screened off with 7 ppg frac. fluid. Unseat packer. Reviewed By' L, BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Frido, y. September 211 1990 Day: WELL: W-24 (44-16-11-12) Rig: 16 Doy0n Rig #16 Frac. AFE Number: F57W24 Expense AFE Number: 1 R0549. Expense AFE Amount = ~ Current Frac. Cost= Estimated Final Frac. = Current Field Costs = Estimated Final Cost = Current Operation: Washing down thru sand. Change over to clean filtered inhibited brine. Summary_ of La,~t 24 Hours POH and lay down 5" drillpipe and 4-1/2" tubing. Cleaned sand from rig floor and BOP's. RIH with muleshoe on 5" drillpipe. Tagged sand at 8871'. Reviewed By: ~ .~ · BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRIJDHOE BAY UNIT As of 0600 Hrs. Monday, Seotember 24, 1990 Day: WELL: W-24 (44-16-11-12) Rig' 19 Doyon Rig .'/fl 6 Frac. AFE Number: Expense AFE Number: Expense AFE Amount = F57W24 16O549 Current Frac. Cost= Estimated Final Frac. = Current Field Costs = Estimated Final Cost = Current Operation: Moving dg to W-17. Summary of Last 72 Hours - Reverse circulate sand out from 9000'. POH and lay down 5" drillpipe. RIH with 3-1/2" drillpipe. Wash down and reverse circulate sand down to PBTD. Change well over to clean filtered inhibited brine. RIH with 8.5" gauge ring to 8904'. RIH with 4-1/2" completion string. ND BOP's and NU tree. RIH with XN plug and set in tailpipe. Pressured up to 3000 psi and set packer. Tested annulus to 2500 psi, ok. Sheared RP valve and freeze protected the well. Installed BPV and secured wellhead and tree. Released dg at 0300 hours on 9/24/90. Reviewed By: F'. ~, BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 10/19/90 T#:81603 FROM' SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINAL,~ Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. ,~..--"~30 TEMP .,A-34A PROD-F .,,~:102 PROD-F I LEAK DET. 1~~_~ 84 PROD-F PITS .---X:~5 PROD-F ./-'Z~-13 PROD-F 10/08/90 10/08/90 10/06/90 10/06/90 10/05/90 10/07/90 10/07/90 10/04/90 10/03/90 #1 0.0-11050 CAMCO 5" #1 8850-9216 CAMCO 5" #1 3200-10510 CAMCO 5" #1 9790-11010 CAMCO 5" # 1 2883-10730 CAMCO 5" #1 8750-9497 CAMCO 5" #1 9450-11218 CAMCO 5" #1 2920-10807 CAMCO 5" #1 11920-12995 CAMCO 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS Alaska Oil & i~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (9O7) 561-5111 · o: o,~,~o~ ~ £ £ ~ tV £D Dat~:09/24/90 T#:81688 ,nformat,on Control , 0("oT 0 0 I[990 ~E I ~ ~ FROM' WeIIRo;ordsLR2-1 . ~,,Ga, Oens.~l"'o" /~~ ~~~ SUBJECT: BP CASED HOLE FINALS // ,--,-a Well Records at (907) 5~-~5. N-17 CL 09/16/90 #1 9123-9148 Atlas 5" R-11 CCL 09/18/90 #1 10250-10550 Atlas 5" W-24 CCL/GR 09/18/90 #1 9150-9340 Atlas 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES STATE OF ALASKA "~ ALAoKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well ~ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate X Change approved program __ Pull tubing X Variance__ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 521'SNL, 1178' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 626' NSL, 775' WEL, SEC. 16, T11N, R12E, UPM At effective depth 890' NSL, 625' WEL, SEC. 16, T11N, R12E, uPM At total depth 920' NSL, 608' WEL, SEC. 16, T11N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical BKB 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 81.90 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-24 (44-16-11-12) PBU 9. Permit number 88-70 10. APl number 50- 029-21833 11. Field/Pool Prudhoe Oil Pool 9625 feet 9138 feet Plugs (measured) Effective depth: measured 9580 feet true vertical BKB 9109 feet Junk (measured) Casing Length Size Structural -- Conductor 110 20 Surface 2656 13 3/8 Intermediate 9120 9 5/8 Cemented 8 c.y. 3923 c.f. 1792 c.f. Measured depth 138 2684 9148 True vertical depth BKB 138 2684 8827 Production -- Liner 719 7 236 c.f. 8906-9625 8661-9138 Perforation depth: measured 9395'- 9415', 9430'- 9454' true vertical subsea 8909'-8947' (two intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 8827' with 3 1/2" tailpipe to 8936' Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 8827'; 3 1/2" SSSV at 2090' REEEiVED AU G 5 0 1990 Alas Oil & Gas Cons. 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation September 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~::~k.~.,--.,~ ~,. ~,.~ %J'~)~'~ Title SupervisorWorkover/Completions FOR COMMISSION USE ONLY Date 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 J Approva, No.7 ' Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED B"/ LONNiE C S~!TH Approved Copy 8etufned SUBMIT IN TRIPLICATE . . 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26, 27. 28. 29. Attachment I W-24 Workover Outline Procedure' MIRU workover rig. Pull BPV. Circulate diesel out. Install two-way check valve. ND tree. NU and test BOP's to 5000 psi. Pull 3-1/2" tubing string. Test the 9-5/8" packoff and replace if necessary. Recover slick stick. RIH with mill and PRT and recover the 9-5/8" Packer and tailpipe assembly. RIH with 6" bit and 7" casing scraper to PBTD. RIH with 7" Test Packer and test 9-5/8" casing and 7" liner lap. Shoot squeeze perforations in channel. Set cement retainer on drill pipe immediately above squeeze perforations. Cement squeeze with Class G cement. Drill out cement to top of retainer and test. Re-squeeze if necessary. RIH with 9-5/8" casing scraper to 7" liner top. Reverse circulate hole clean. RIH with 6" bit and 7" casing scraper to PBTD. Reverse circulate hole clean and change over to filtered brine. RIH with drill pipe-conveyed perforating assembly, log into position with GR/CCL. Perforate and flow well to surface. RIH and perform bullhead acid wash. Perform a hydraulic fracture treatment of the Zone 4 Ivishak LOC. RIH with 6" bit and 7" scraper to sand top. Reverse circulate and change over to filtered inhibited brine. Run 8.5" gauge ring/junk basket to 7" liner top. Run 4-1/2" tubing completion. Set and test the 9-5/8" packer. Set two-way check valve. ND BOP's. NU and test tree to 5000 psi. Pull two-way check valve. Shear valve in the GLM and displace annulus to 140 bbls diesel. U-tube diesel to the tubing. Set BPV. Release dg. RECEIVED A U G ,t 0 1990 Alaska.Oil & Gas Cons. Commissi0[~ Anchorage BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSI WP TRIPLE RAM STACK J WORKO VER RISER I ANNULAR PREVENTER 2" KILL LINE MANUAL HYDRAULIC GATE GATE PI PE RAMS j ' , J I I PI PE RAMS i DRILLING SPOOL I 4" CHOKE LINE HYDRAULIC MANUAL GATE BLIND RAMS I I GATE R'EiEEi' ED AUG ,t 0 lJ)90 Alaska 0,1 &~na~S.~g; commissio[,' BP EXPLORATION BP Exoloration (Alaska) Inc. 900 East Benson Boulevard P,O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO:. DISTRIBUTION Date:04/27/90 T#:81127 FROM: SUBJECT: Information Control Well Records LR2-1 ~BP CASED H.O.L .E FINALS Enclosed is your copy of the material listed below. please contact BP Well Records at (907) 564-4445. If you have any questions, C-04 Gamma Ray 04/15/90 # 1 D-!4 Collar 04/17/90 # 1 D-17 "'Perf 04/20/90 # 1 E-25 Prod-F 04/21/90 # 1 H-08 CNL 04/18/90 # 1 J-09 Perf 04/19/90 # 1 J-16 Perf 04/19/90 # 1 K-14 Perf 04/21/90 # 1 W-24 Tubing Cutter 04/22/90 # 1 10298-10388 930O-9650 9750-10366 9500-11500 8850-9424 8300-9873 9300-9546 10300-11746 8700-8930 Atlas 5" Atlas 5" Sch 5" Sch 2" Sc.h ,' 5" Sch 5" Sch 5" Sch 8-m¥ P,'f~ 5" Distribution' ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS ARCHIVES E MAY - 2 1990 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: From: Subject: DISTRUBUTION Information Control Well Records LR2~i~ BP CASED HOLE FINAL LOGS Date: 04/22/90 · l Trar~smitta~l 81078 · o ,, Enclosed is your copy of the material listed below.. If you have any questions, please contact BP Well Records at (907) 564-4445. E-26 Spinner/Temp 12/15/89 #1 9300-9670 HLS 5" R-13 PRDO-F 12/19/89 #1 9600-9956 HLS 5" W-24 CCL 12/21/89 #1 8750-9100 HLS 5" W-37 Spinner/Temp 12/14/89 #1 9800-10228 HLS 5" Z-23 PERF 12/12/89 #1 9383-9731 HLS 5" Z-25 Temp/PITS 12/17/89 #1 i1250-11735 HLS 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS APR 5 ]990 Anchora BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 02/06/90 Transmittal: 80871 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. T-07 Positioning Record 01/20/90 #1 9080-9330 Sch 5" W-24 Tubing Cutter 01/22/90 #~ 8745-8914 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 02/01/90 Transmittal: 80849 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. W-24 TUBING CUTTER 01/25/90 #1 8715-8918 Atlas 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES ~40BIL PHILLIPS . ~'TATE OF ARCHIVES RECEIVED Oil & Gas Cons. Commissio[~ Anchorage BP EXPLORATION BP Exl31oration (Alaska) Inc. 900 East Benson Boulevarcl PO. Box 196612 Anctqorage. Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 01/23/90 Transmittal: 80809 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. C-04 M-23 X-07 W-24 CNL 2.5" Tool 01/14/90 ~1 9750-10659 Sch 5" PERF 01/16/90 #1 9500-10033 Sch 5" PERF 01/18/90 #1 10700-10990 Sch 5" TUBING CUTTER 01/15/90 #1 8746-8930 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR ARCHIVES IV£D Alaska 01! 8; Gas Cons. Comm~SS[Otl Anchorage BP EXPLORATION HOUSTON ARCO CHEVRON EXXON TEXACO 'TO: MOBIL PHILL IP S STATE OF ALASKA ARCHIVES INDEXED BP Exploration (Alaska) In~ ------ 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 9951~6612 (907) 561-5111 Date: 04-21-89 79995 REFERENCE: BP FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith, Please acknowledge receipt by signing a copy of this .letter and returning It to this office: W-24 04'-12-89 BHP--S tatic Gradient Camco Y-25 04-15-89 BHP--S tatic Gradient Camco Y-25 04-13-89 BHP--Static Gradient Camco Z-24 04-13-89 BHP--Static Gradient Camco Z-06 04~04~89 BHP--S tatic Gradient Camco Received Date Alaska Oil~ ~as Co,s~ C0mmissiol~ Anchorage Shirley R. McCurry ~NFORMAT~ON CONTROL We~ Records LR2-~ Standard Alaska Production Company 900 East Benson Bouleva~_ P.©. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION January 31, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-24 (44-16-11-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File RECEIVED Oil & ~as Cons. Cornmi~io~ ~nChorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. 1. Operations performed: Operation shutdown __ Pull tubing Alter casing 2. Name of Operator Standard Alaska Production Company 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Perforate Other Stimulate X Plugging Repair well 5, Type of Well: Development ~ Exploratory Stratigraphic, Service 4. Location of well at surface 521' SNL, 1178' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 626' NSL, 775' WEL, SEC. 16, T11N, R12E, UPM At effective depth 890' NSL, 625' WEL, SEC. 16, T11N, R12E, UPM At total depth 920' NSL, 608' WEL, SEC. 16, T11N, R12E, UPM 12. PreSent well condition summary Total depth: measured true vertical BKB Effective depth: measured true vertical BKB 9625feet Plugs (measured) 9138feet 9580feet Junk (measured) 9109feet 6. Datum elevation (DF or KB) KBE,, 81.90 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8, Well number W-24 (44-16-11-12) PBU 9, Permit number/approval number 88-70/8-931,8-961 10, APl number 50- 029-21833 11. Field/Pool Prudhoe Oil Pool Casing Length Structural -- Conductor 110 Surface 2656 Intermediate 9120 Production -- Liner 719 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 20 8 c.y. 138 138 13 3/8 3923 c,f. 2684 2684 9 5/8 1792 c.f. 9148 8827 7 236 c.f. 8906-9625 8661-9138 9395'- 9415', 9430'- 9454' true vertical subsea 8909'-8947' (two intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 8827' with 3 1/2" tailpipe to 8936' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 8827'; 3 1/2" SSSV at 20890' 1 13. Stimulation or cement squeeze summary see attachment 14. Intervals treated (measured) ~-- E ~ ~" ~''~" Treatment description including volumes used and final pressure '!~tska..Oil .& Gas Cons. C0mrnis~i~i~ Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 200 126 40 568 230 Subsequent to operation 850 368 306 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 1~.~4 Rev 06/15/88 ~/~ 1549 274 Title Manager Production Engineering Service Date/'3/'~. SUBMIT IN DUPLICATE WELL W-24 (44-16-11-12) PBU STIMULATION OPERATIONS A mud acid breakdown treatment was performed 12/7/88 on the following perforated intervals in Well W-24. 9395'- 9415' MD BKB 9430' - 9454' MD BKB Prior to the breakdown job a bullheaded HC1/xylene tubing wash was performed. The breakdown was performed as follows' a) b) ¢) d) 750 gal. 15% HC1 1000 gal. 9%HC1 - 3% HF 750 gal. 15% HC1 1000 gal. 15% HCI (dropped 180 7/8"OD 1.1 SG ballsealers evenly thoughout the fluid Steps a-d were repeated two more times, leaving balls out of the final stage, then the treatment fluids were displaced to within 5 bbls. of the top perforations with 85 bbls. dead crude. The well was surged three times to knock the balls off the perforations, then the well wasreturned to production and tested. jm 1/25/89 ..: gnchora[lo Standard Alaska ~-~' ProdUction Company 900 Fast Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION December 16 , 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-24 (44-16-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JAM Enclosures (6) cc: L. Burke (MB12-1) W-24 Well File ~/~4anager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ~ Operation Shutdown Re-enter suspended well ~ Alter casing Repair well Plugging Time extension __ Stimulate X Change approve~J program __ -----Pull tubing __ Variance ~ Perforate ~ Oth~ . 2. Name of Operator 5. Type of Well: 6. Standard Alaska Production Company Development X Exploratory ~ 3. Address Stratigraphic ~ 7. P. 0. Box 196612, Anchorage, Alaska 99519-6612 Service ~ 4. Location of well at surface 8. 521'SNL, 1178'WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 626' NSL, 775' WEL, SEC. 16, T11N, R12E, UPM At effective depth 890' NSL, 625' WEL, SEC. 16, T11N, R12E, UPM At total depth 920' NSL, 608' WEL, SEC. 16, T11N, R12E, UPM Datum elevation (DF or KB) KBE =, 81.90 AMSL feet Unit or Property name Prudhoe Bay Unit Well number W-24 (44-16-11-12) PBU 9. Permit number 88-70 10. APl number 50- 029-21833 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 9625 feet BKB 9138 feet Effective depth: measured 9580 feet true vertical BKB 9109 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural -- Conductor 110 20 8 c.y. Surface 2656 13 3/8 3923 c.f. Intermediate 9120 9 5/8 1792 c.f. Production -- Liner 719 7 236 c.f. Perforation depth: measured 9395'- 9415; 9430'- 9454' Measured depth 138 2684 9148 8906-9625 true vertical subsea 8909'-8947' (two intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 8827' with 3 1/2" taiipipe to 8936' Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 8827'; 3 1/2" SSSV at 20890' True vedic~ depth BKB 138 2684 8827 8661-9138 13. Attachments Description summary of proposal X , Detailed operations program BOP sketch 14. Estimated date for commencing operation December 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~ ~/~' Tide Manager Product[on £ngineering FOR COMMISSION USE ONLY Condit~ns of approval: Notify Commission so representative may witness Plug integrity BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- .,,~ ~.~ z/ I Approval No. / Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE P.. ~M!T~ Commissioner SUBMIT IN TRIPLICATE WELL W-24 (44-16-11-12) PBU STIMULATION PROPOSAL A mud acid breakdown treatment is proposed for the following perforated intervals in Well W-20. 9395' - 9415' MD BKB 9430'--9454' MD BKB ,~ · Prior to the breakdown job a bullheaded HCl/xylene tubing wash will be performed. The breakdown will be performed as follows: a) b) c) d) 750 gal. 15% HCI 1000 gal. 12%HCI - 3% HF 750 gal. 15% HC1 1000 gal. 15% HC1 (drop 180 7/8"OD 1.1 SG ballsealers evenly thoughout the fluid Repeat steps a-d two more times, leaving balls out of the final stage, then displace the treatment to within 5 bbls. of the top perforation with dead crude. The well will be surged three times to knock the balls off the perforations, then the well will be returned to production and tested. jm 12/2/88 Standard Alaska Production Company 900 Fast Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION December 6, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-24 (44-16-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Approvals, for the above-named well. proposal to stimulate the well. Application for Sundry This contains our Yours very truly, JAB:JAM Enclosures (6) cc: L. Burke (MB12-1) W-24 Well File nager Production Engineering A unit of the original Standard Oil Compdriy Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend __ Operation Shutdown ~ Re-enter suspended well Alter casing __ Repair well~ Plugging ~ Time extension __ Stimulate X Change approved program ~ Pull tubing Variance__ Perforate ~ Other ~ 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory Stratigraphic Service 4. Location of well at surface 521'SNL, 1178' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 626' NSL, 775' WEL, SEC. 16, T11N, R12E, UPM At effective depth 890' NSL, 625' WEL, SEC. 16, T11N, R12E, UPM At total depth 920' NSL, 608' WEL, SEC. 16, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 9625 feet true vertical BKB 9138 feet 6. Datum elevation (DF or KB) KBE = 81.90 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-24 (44-16-11-12) PBU 9. Permit number 88-70 10. APl number 50- 029-21833 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 9580 feet Junk (measured) true vertical BKB 9109 feet Casing Length Size Cemented Structural -- Conductor 110 20 8 c.y. S u rf ace 2656 13 3/8 3923 c.f. Intermediate 9120 9 5/8 1792 c.f. Production -- Liner 719 7 236 c.f. Perforation depth: measured 9395'- 9415', 9430'- 9454' Measured depth 138 2684 9148 8906-9625 true vertical subsea 8909~8947'~wo ~rvals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 8827' with 3 1/2" tailpipe to 8936' True vertical depth BKB 138 2684 8827 8661-9138 Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 8827'; 3 1/2" SSSV at 20890' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation December 1988 ":~ 6. 'If proposal was verbally approved Name of approver D~e approved 15. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~/~.~/'t,~~ Title Manager Production Engineering //'/ (./' (,/ FOR COMMISSION USE ONLY cond t~s of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Mechanical Integrity Test__ Approved by order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form required 10- Copy Heturned ORIGINAL, SIGNED BY ~ '~ ~ ~ommlssloner I Approval No-~.' ~/ Date ]~ -~ - .~' SUBMIT IN TRIPLICATE WELL W-24 (44-16-11-12) PBU STIMULATION ,PROPOSAL A mud acid breakdown treatment is proposed for the following perforated intervals in Well W-20. 9395' - 9415' MD BKB 9430' - 9454' MD BKB Prior to the breakdown job a bullheaded HCl/xylene tubing wash will be performed. The breakdown will be performed as follows: a) b) c) d) 750 gal. 15% HC1 1000 gal. 12%HCI - 3% HF 750 gal. 15% HC1 1000 gal. 15% HCI (drop 180 7/8"OD 1.1 SG ballsealers evenly thoughout the fluid Repeat steps a-d two more times, leaving balls out of the final stage, then displace the treatment to within 5 bbls. of the top perforation with dead crude. The well will be surged three times to knock the balls off the perforations, then the well will be returned to production and tested. jm 12/2/88 (~landa~d Alasl.. a Pe'oelu¢lion Company 900 Ea$! ~en,,on ~uJe~a~d Anchorage. AIo~o ~519-661 (907! 564-511 I HOUSTON i NOEXED ,. ARCO CHEVRON EXXON TEXACO STANDARD Al_AS?'/-,. PR©DUC Date: 10-7-88 TO: MO B IL TI: 79390 PHILLIPS -STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES SAPC 'CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: C-28 ~.-08 R-06 R-11 R-12 R-i9 S-06 W-24 Z-06 Leak Det. 9-25-88 #1 SURF-10100 Camco 5" Prod-F 9-21-88 #1 9800-10192 Camco 5" Prod-F 9-24-88 #1 9500-9787 Camco 5" Prod-F 9-23-88 #1 10100-19737 CAMCO 5" Prod-F 9-26-88 #1 10550-10949 Camco 5" Prod-F 9-26-88 #1 9500-9850 Camco 5" Inj. 9-20-88 #1 10000-10500 Camco 5" Prod-F 9-29-88 #1 9250-9450 Camco 5" Prod-F 9-27-88 #1 10020-10290 Camco 5" Shirley R. McCurry NFORMAT ION CONTROL Slanclarcl Alaska P~oduction Compa. 900 East ~en,.on Boule.,o,d 13 O. Bo~ 19661? An¢ hot oc;je. AIo,,t~ a (9071 564-.51 I I -HOUSTON ARCO CHEVRON EXiKON TE.YACO TO: MO B I L PHILLIPS STATE OF ALASKA GEOSC IENCES RES ERVO IR REFERENCE: ARCHIVES SAPC 'CASED HOLE FINAL LOGS INDEXED $'I'ANDARD AL ASI"'/~ PRODUCTION 10-13-88 Date: T~: 79417 The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: B-19 B-29 E-O1 M-05 U-04 U-05 W-17 W-24 W-40 Y-19 Z-Oi Completion 10-09-88 #1 9396-9716 Sch 5" Completion 10-09-88 #1 8731-9406 Sch 5" Completion 10-08-88 #I 8967-9707 Sch 5" Tempature 09-30-88 #1 Surfac&-2500 Camco 5" Tempature 10-02-88 #1 10850-11605 Camco 5" Tempature 10-02-88 #1 8900-9411 Camco 5" Production 10-07-88 #1 11550-11912 Sch 5" Production 10-07-88 #1 9300-9466 Sch 5" Production 10-02-88 #2 10250-10535 Camco 5" Tempature 09-30-88 #1 Surface-2500 Camco 5" Production 09-27-88 #1 ~ 10650-10720 Camco 5" Received Date A vn.I al Ihe o~(j;nol $1ondotd C~l Co..pont. Founded i. Cle..eland. O1~;o. ;. 1810 Sh±rle¥ ~. McCurr¥ I NFORMAT I ON CONTROL Wel I Records LR2-1 INDEXED HOUSTON aco STANDARD CHEVRON ALASKA PRODUCTION EXXON Date: 09/06/88 TEXACO TO: TI: 79280 MOBIL PHILLIPS STATE OF ALASKA ARCHIVES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to thls offlce: B-07 C-06 H-23 H-30 W-24 W-29 W-40 Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient 08/25/88 Camco 08/15/88 Camco 08/25/88 Camco 08/21/88 Camco 08/31/88 Camco 08/26/88 Camco 08/30/88 Camco Rec:o I ved Date A un~ Of eke o~g;nol Sla~do,d C~i Comg~ony Founded in Cleveland. C~o, ,. 1870 Jennifer Dietz I NFORHAT I ON CONTROL Wel I Records LR2-1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 88-70 3. Address 8. APl Number P. 0. Box 196612, Anchora~le, Alaska 99519-6612 50- 029-21833 4. Location of well at surface 9. Unit or Lease Name  Prudhoe Bay Unit 521'SNL, 1178' WEL, SEC21, T11N, R12E 10. Well Number At Top Producing Interval I VER~/:ED ~. W-24(44-16-11-12) 4654' SNL, 775' WEL, SEC 16, T11N, R12E 11. Field and Pool At Total Depth Ji~. H. ~ Prudhoe Bay Field/Prudhoe Bay Pool 4360' SNL, 608' WEL, SEC 16, T11N, R12E !5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE= 81.90 ft. I ADL 28263 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 7-29-88 8-14-88 8-18-88I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 9625'MD 9138' TVD 9580'MD 9190' TVD YES [] NO [] 2090 feet MD I 1932 22. Type Electric or Other Logs Run DIL/SFL, BHCS, LDT/CNL, Poro Raw 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" COnductor Surface 110' 8 cu yds Concrete 13-3/8" 68# L-80 Surface 2684' 17-1/2" 3923 cu ft Permafrost 9-5/8' 47# L-80 NSCC Surface 4479' 12-1/4" 1792 cu ft Class G 9-5/8'~ 47# L-80 Butt 4479' 9148' 12-1/4" 7" 26# L-80 8919' 9625' 8-1/2" 236 cu ft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MD1 PACKER SET (MDI S.O.S. 5"@ 4 spf. 3-1/2" 9.3///ft L-80 8936'MD 8827'MD MD TVDss 9395'-9415' 8909'-8922' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9430'-9454' 8931'-8947' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PROD UCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 8-16-88 I Fl°win9 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SITF JGAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. .>4-HOUR RATE Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS : ...RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. SAG 8975' 8710' Shublik 9016' 8738' Zone 4 9180' 8848' (Top Sadlerochit) 31. LIST OF ATTACHMENTS 32. I hereby cedify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and 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 In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 SUB.$URFACE DIRECTIONAL URVEY [~ UIDANCE F~ONTINUOUS r-~ OOL Company STAN,,D,A,RD AL,AS, KA PRODUCTION COMPANY iii i I II I I ! I Well Name W-24 I4,4-16,-,11-121(521' SNL,1178' WEt,SEC 21,Tll, N, R12E) Field/Location PRUDHOE BA,,Y, N,O,,R,,T,H,SLOP,E, ALASKA , Job Reference No. . ..- 72901 -: ..... ' '"'~' Date 17-AUG-88 Computed By: KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR STANDARD ALASKA PRODUCTION CO. PRUDHOE BAY NORTH SLOPEr~L.~SKA SURVEY DATE: 17-~UG-88 ENGINEER: PORTER METHODS gF COMPUTATION T~gL LOC~TION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPSL&TION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 21 DEG 9 MIN EAST COMPUTATION DATE: 28-AUG-88 PAGE STANDARD ALASKA P~ODUCTION W - 24 PRUOHOE BAY NORTH SLOPE,ALASKA DATE OF SURVEY: 1T-AUG-88 KELLY BUSHING ELEVATION: 81.90 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/tO0 FEET FEET FEET DEG 0.00 0.00 -81.90 0 0 N 0 0 E 100.00 100.00 18.10 0 7 N 78 4] E ZO0.O0 200.00 118.10 0 4 S 13 34 W 300.00 300.00 218.10 0 9 S 62 55 E 400.00 400.00 318.10 0 I S 22 9 E 500.00 500.00 418.10 0 14 S BO 8 E 600.00 600.00 518.10 0 29 N 46 47 E 700.00 699.99 618.09 0 28 N 57 14 E 800.00 799.99 718.09 0 45 N 47 4 E 900.00 899.98 818.08 0 45 N 58 58 E 0.00 0.00 0.00 N 0.00 E 0.07 0.30 0.01 S 0.24 E 0.15 0.01 0.03 N 0.34 E 0.03 0.22 0.12 S 0.39 E 0.08 0.10 0.16 S 0.63 E 0.00 0.50 0.30 S 0.79 E 0.48 0.25 0.01 S 1.37 E 1.14 0.40 0.43 N 2.02 E 2.08 0.14 1.13 N 2.85 E 3.17 0.03 1.89 N 3.91 E 0.00 N 0 0 E 0.24 S 86 32 E 0.34 N 84 39 E 0.41 S 72 43 E 0.65 S 75 26 E 0.85 S 69 6 E 1.37 S 89 Z7 E ) 2.07 N 77 51 E 3.07 N 68 23 E 4.34 N 64 13 E 1000.00 999.97 918.37 1100.00 1099.95 1018.05 1200.00 1199.93 1118.03 1300.00 1299.91 1218.01 1400.00 1399.90 1318.00 1500.00 1499.90 1418.00 1600.00 1599.90 151~.00 1700.00 1699.89 1617.99 1800.00 1799.89 1717.99 1900.00 1899.89 15117.99 I 0 N 68 5~J E I I S 89 47 E 112 S 89 18 E 0 55 S 77 45 E 0 39 S 71 22 E 0 25 S 75 43 E 0 17 S 59 47 E 0 17 S 53 11 E 0 28 S 81 32 E 0 28 S 41 25 E 4.30 0.11 2.55 N 5.35 E 5.29 0.03 2.91 N 7.13 E 5.95 0.00 2.86 N 9.09 E 6.52 0.39 2.73 N 11.03 5 6.67 0.40 2.37 N 12.34 E 6.71 0.53 2.08 N 13.22 E 6.69 0.00 1.85 N 13.75 E 6.58 0.00 1.56 N 14.20 E 6.71 0.00 1.43 N 14.89 E 6.64 0.00 1.08 N 15.60 E 5.92 N 64 32 E 7.70 N 67 45 E 9.53 N 72 32 E 11.36 N 76 6 E 12.56 N 79 6 E 13.38 N 81 2 E 13.88 N 82 19 E 14.28 N 83 43 E 14.96 N 84 29 E 1.5.64 N 86 2 E 2000.00 1999.88 1917.98 2100.00 2099.88 2017.98 ZZO0.O0 2199.86 2117.96 2300.00 2299.85 2217.95 2400.00 2399.84 2317.94 2500.00 2499.83 2417.93 2500.00 2599.83 2517.93 2700.00 2699.82 2617.92 2800.00 Z799.8Z 2717.92 2900.00 2899.81 2817.91 0 39 S 42 32 E 0 49 S 41 35 E 0 50 S 38 31 5 0 54 S 27 18 E 0 51 S 21 32 E 037 S 3 4 E 034 S 2 56 W 037 S 3 4 W 0 32 S 8 42 W 0 19 S 27 42 W 6.17 0.17 0.35 N 16.19 5 5.60 0.00 0.60 S 17.06 E 4.90 0.00 1.72 S 18.0I E 3.97 0.00 3.01 S 18.79 E 2.88 0.02 4.44 S 19.4¢ E 1.88 0.00 5.62 S 19.72 E 0.88 0.00 6.69 S 19.74 E -0.10 0.18 7.73 S 19.71 E -1.11 0.17 8.77 S 19.60 E -1.74 0.00 9.38 S 19.41 E 16.19 N 88 45 E 17.07 S 8'7 59 E 18.10 S 84 32 E 19.03 S 80 53 E 19.94 S 77 8 5 20.51 S 74 5 E 20.84 S 71 16 E ) 21.17 S 68 35 E 21.4'7 S 65 53 E 21.55 S 64 12 E 3000.00 2999.81 2917.91 3100.00 3099.81 3017.91 3200.00 3199.81 3117.91 3300.00 3299.81 3217.91 3400.00 3399.81 3317.91 3500.00 3499.80 3417.90 3600.00 3599.80 3517.90 3700.00 3699.80 3517.90 3800.00 3799.80 3717.90 3900.00 3899.80 3317.90 0 17 S 31 18 W 0 25 S 0 56 E 0 1Z S 37 49 W 023 S 7 3H W 027 S 5 2g W 0 29 S 9 4 W 0 23 S 24 56 W 026 S 0 6 W 0 5 N 31 31E 0 7 N 98 42 W -2.27 0.00 9.85 S 19.17 E -2.86 0.31 10.39 S 18.95 E -3.30 0.03 10.83 S 18.85 E -3.72 0.70 11.20 S 18.63 E -4.42 0.06 11.94 S 18.59 E -5.26 0.00 12.78 S 18.47 E -6.09 0.63 13.60 S 18.29 E -6.82 0.00 14.32 S 18.11 E -7.26 0.76 14.83 S 18.20 E -7.21 0.33 14.73 S 18.09 E 21.55 S 62 47 E 21.61 S 61 15 E 21.74 S 60 7 E 21.74 S 58 59 E 22.10 S 57 18 E 22.46 S 55 18 E 22.79 S 53 21 E 23.09 S 51 40 E Z3.48 S 50 49 E 23.33 S 50 50 E COMPUTATION DATE: 28-AUG-BB PAGE Z STANDARD ALASKA PRODUCT[ON CO. W - 24 PRUDHOE BAY NORTH SLOPE,ALASKa DATE OF SURVEY: 17-AUG-88 KELLY BUSHING ELEVATION: 81.90 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET DEG/tO0 FEET FEET FEET DEG MIN 4000.00 3999.80 3917.90 4100.00 4099.79 4017.89 4200.00 4199.78 4117.88 4300.00 4299.78 4217.88 4400.00 4399.78 4317.88 4500.00 4499.77 4417.87 4600.00 4599.75 4~17.85 4700.00 4699.72 4517.82 4BOO.Q0 4799.68 4717.78 4900.00 4899.65 4817.75 027 N 5 52 W 037 N 6 1 W 041 N 7 55 W 0 21 N 7 47 027 N 13 49 E 0 54 N 3051 I 12 N 43 30 1 40 N 47 ZZ 1 29 N 43 58 1 14 N 44 36 -6.81 O.1B 14.25 S 17.95 E -5.95 0.00 13.29 S 17.84 E -4.94 0.00 12.13 S 17.68 E -3.97 0.58 11.06 S 17.59 E -3.33 0.00 10.43 S 17,73 E -2.26 0.81 9.44 S 18.14 E -0.47 0.52 7.98 S 19.33 E 1.88 0.18 6.18 S 21.20 E 4.51 O.6q 4.17 S 23.27 E 6.68 0.81 2.47 S 24.90 E Z2.92 S 51 33 E 22.25 S 53 19 E 21.45 S 55 32 E 20.78 S 57 49 E 20.57 S 59 31E Z0.45 S 62 30 E '~ 20.91 S 67 34 E ,; ZZ.08 S 73 44 E 23.64 S 79 50 E 25.03 S 84 19 E $000.00 4999.63 4917.73 5100.00 5099.63 5017.73 5200.00 5199.62 5117.72 5300.00 5299.62 5217.72 5400.00 5399.61 5317.71 5500.00 5499.60 5417.70 5600.00 5599.59 5517.69 5700.00 5699.58 5617.68 5800.00 5799.57 5717.67 5900.00 5899.56 5817.66 0 46 N 43 4 E 0 33 N 44 1E 0 22 N 23 22 E 0 33 Nll 19 W 0 44 N 34 24 W 0 52 N 43 15 W 0 54 N 45 5 W 0 54 N 45 7 W 0 52 N 47 51 W 0 44 N 46 49 W 8.31 0.52 1.21 S 26.14 E 9.36 0.35 0.37 S 26.89 E 10.08 0.09 0.22 N 27.36 E 10.79 O.1Z 0.93 N 27.50 E 11.59 0.23 1.96 N 27.06 E 12.29 0.00 3.05 N 26.16 E 12.95 0.27 4.19 N 25.06 E 13.62 0.11 5.33 N 23.96 E 14.22 0.26 6.43 N 22.79 E 14.68 1.05 7.34 N ZI.TZ E 26.17 S 87 21 E 26.89 S 89 12 E 27.36 N 89 32 E 27.52 N 88 3 E 27.13 N 85 51 E 26.34 N 83 ZO E 25.41 N 80 30 E 24.54 N 77 27 E 23.68 N 74 14 E 22.92 N 71 20 E 6000.00 5999.55 5917.65 I 6 6100.00 6099.47 6017.57 3 37 6200.00 6199.10 6117.20 5 44 6300.00 6298.41 6216.51 7 46 6400.00 6397.27 6315.38 9 15 6500.00 6495.85 6413.96 9 53 6600.00 6594.34 6512.44 10 2 6700.00 6692.79 6610.39 10 9 6800.00 6791.24 6709.34 lO 15 6900.00 6889.45 6807.55 11 44 N 48 7 W N 24 46 W N 11 35 W N 4 27 W N 1 33 W N 4 21 E N 9 54 E N 17 1E N 16 44 E N 7 9 E 15.20 1.48 8.26 N Z0.76 E 17.43 3.25 11.48 N 18.63 E 24.10 1.25 19.61 N 16.12 E 34.33 1.87 31.17 N 14.58 E 47.98 1.29 46.11 N 13.80 E 63.76 1.18 62.88 N 14.20 E 80.59 1.01 BO.OB N 16.35 E 97.96 1.28 97.14 N 20.40 E 115.47 2.87 113.71 N 133.93 2.69 132.16 N 22.35 N 68 17 E 21.88 N 58 21 E 25.39 N 39 25 E 34.41 N 25 3 E 48.13 N 16 39 E 64.46 N 12 43 E 81.73 W It 32 E ) 99.26 N 11 51 E 26.12 E 116.67 N 12 56 E 29.59 E 135.43 N 1Z 37 E 7000.00 6986.98 6905.08 13 51 7100.00 7083.58 7001.68 15 51 7200.00 7179.42 709?. 52 17 23 7300.00 7274.39 7192.49 19 0 7400.00 7368.56 7286.66 20 14 7500.00 7462.05 7380.15 21 21 7600.00 7554.80 7472.90 22 38 7700.00 7646.60 7564.70 24 4 7800.00 7737.26 7655.36 25 49 7900.00 7826.65 7744.75 27 22 N 1 29 E N I 20 W N I 55 W N 1 42 E N 5 44 E N 9 29 E N 14 33 E N 19 33 E N 23 30 E N 26 52 E 155.04 3.11 154.15 N 179.18 1.63 180.01 N 205.40 1.95 208.51 N 234.56 2.00 239.81 N 266.66 1.72 273.36 N 301.15 1.80 308.52 N 338.02 2.77 345.09 N 377.57 2.41 382.95 N 419.74 2.32 422.15 N 464.43 1.89 462.67 N 31.25 E 157.28, N 11 27 E 31.31 E 182.71 N 9 52 E 30.31 E 210.70 N 8 16 E 30.23 E 241.70 N 7 11 E 32.46 E 275.28 N 6 46 E 37.18 E 310.75 N 6 52 E 44.84 E 347.99 N 7 24 E 56.59 E 387.1L N 9 24 E 72.14 E 428.27 N 9 41 E 91.26 E 471.58 N 11 9 E COMPUTATION DATE: 28-AUG-S8 PAGE 3 STANDARD ALASKA PRODUCTION CO. W - Z4 PRUOHOE BAY NORTH SLOPEtALASKA DATE OF SURVEY: 17-AUG-88 KELLY ~USHING ELEVATION: 81.90 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 8000.00 7915.01 7833.11 Z8 21 8100.00 8002.90 7921.00 28 40 8200.00 8090.26 8008.36 Z9 34 8300.00 8176.37 8094.47 31 38 8400.00 8261.34 8179.44 31 59 8500.00 8345.23 8263.33 34 6 8600.00 8426.92 8345.02 36 18 8700.00 8506.25 8424.35 38 39 8800.00 8582.98 850X.08 41 14 8900.00 8656.87 8574.97 43 32 N Z8 47 E N Z3 47 E N 20 23 E N ;~0 Z E N 17 40 E N 1643 E N 18 26 E N 21 55 E N Z5 18 E 510.89 1.27 558.38 2.38 607.02 1.62 657.83 1.45 710.52 1.94 764.79 2.44 822.34 2.88 883.17 3.48 947.22 3.36 4.47 N .Z8 38 E 101~,.23 503.94 N 113.35 E 516.53 N 12 40 E 546.62 a 134.64 E 562.96 N 13 30 E 591.74 N 15Z.BZ E 611.16 N 14 28 E 639.50 N 170.18 E 661.76 N 14 54 E 689.35 N 187.38 E 714.36 N 15 12 E 741.39 N 203.28 E 768.73 N 15 19 E '~ 796.4Z N 2Z0.53 E 8Z6.39 N 15 Z8 E 853.55 N 241.44 E 887.04 N 15 47 E 912.24 N Z6?.ZT E 930.38 N 16 19 E 972.27 N 297.8Z E 1016.86 N 17 I E 9000.00 8727.27 8643.37 46 55 9100.00 8794.62 8712.72 48 Z 9200.00 8861.79 8779.89 47 40 9300.00 8928.46 8846.56 48 49 9400.00 8993.73 8911.83 49 40 9500.00 9058.03 8976.13 50 11 9600.00 9121.71 9039.81 50 28 9625°00 9137.62 9055.72 50 28 N 31 25 E 1084.31 N 31 22 E 1157.03 N 30 58 E 1229.96 N 30 23 E 1303.49 N 29 33 E 1378.33 N 28 41 E 1454.17 N 28 31 E 1530.63 N 28 31 E 1549.75 2.95 0.25 0.67 1.00 1.07 1.48 0.00 0.00 1033.54 N 333.66 E 1086.06 N 17 53 E 1096.58 N 372.27 E 1158.04 N 18 45 E t159.92 N 410.67 E 1230.48 N 19 29 E 1224.05 N 448.69 E 1303.69 N 20 7 E 1289.64 N 486.56 E 1378.38 N 20 40 E 1356.53 N 523.86 E 1454.17 N 21 6 E 1424.26 N 560.70 E 1530.66 N 21 29 E 1441.20 N 569.91 E 1549.80 N 21 34 E COMPUTATION DATE: 2B-AUS-88 PAGE 4 STANDARO ALASKA PRODUCTION CD. W - 24 PRUDHOE BAY NORTH SLOOEtALASK~ DATE OF SURVEY: 17-AUG-88 KELLY BUSHING ELEVATION: 81.90 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG M[N VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/ZO0 FEET FEET FEET OEG 0.00 0.00 -81.90 0 0 1000.00 999.97 918.07 1 0 2000.00 1999.88 1917.98 0 39 3000.00 2999.81 2917.91 0 17 4000.00 3999.80 3917.90 0 27 5000.00 ~999.63 4917.73 0 46 6000.00 5999.55 5917.65 1 6 7000.00 6986.98 6305.08 13 51 8000.00 7915.01 7833.11 28 21 9000.00 8727.27 8645.37 46 55 N 0 0 E N 68 58 5 S 4,2 32 5 S 31 lB W N 5 52 W N 43 4 E N 48 7 W N I 29 E N 28 47 E 0.00 0.00 0.00 N 4.30 0.11 2.55 N 6.17 0.17 0.35 N -2.27 0.00 9.85 S -5.81 0.18 14.25 S 8.31 0.52 1.21 S 15.20 1.48 8.26 N 155.04 3.11 15~,. 15 N 510.89 1.27 2.95 N 31 25 E 1084.31 0.00 E 0.00 N 0 0 E 5.35 E 5.92 N 64 3Z E 16.19 E 16.19 N 88 45 E 19.17 E 21.55 S 62 47 E 17.95 E 22.92 S 51 33 E Z6.14 E Z6.17 S 87 21 E , ~) 20.76 E 22.35 N 68 17 E 31.25 E 157.28 N 11 27 E 503.94 N 113.35 ~ 5.16.53 N 12 ¢0 E 1033.54 N 333.66 E: I086.06 N 17 53 E 9625.00 9137.62 9055.72 50 28 N 28 31 E 1549.75 0.00 1441.20 N 569.91 E 1549.80 N 21 34 E STANDARD &LASKA PROOUCTION CO. W- 24 PRUOHOE NORTH SLOPE,ALASKA COMPUTATION D&TE: 28-AUG-88 PAGE 5 DATE OF SURVEY: 17-AUG-88 KELLY ~USHING ELEVATION: 81.90 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASUREO VERTICAL VERTICRL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN D~G MIN 0.00 0.00 -81.90 0 0 N 0 0 E 81.90 81.90 0.00 0 8 S 67 35 E 181.90 181.90 100.00 0 I S 11 13 E 281.90 281.90 ZO0.O0 0 7 S 47 27 E 381.90 381.90 300.00 0 3 S 77 40 E 481.90 431.90 400.00 0 12 S 62 I E 581.90 581.90 500.00 0 27 N 50 59 E 681.91 681.90 600.00 0 25 N 65 35 E 781.91 781.90 700.00 0 42 N 48 Z E 881.92 881.90 800.00 0 44 N 60 5 E 981.93 981.90 900.00 1081.95 1081.90 1000.00 1181.97 1181.90 ltO0.O0 1281.99 1281.90 1ZOO.DO 1382.00 1381.90 1300.00 1482.00 1481.90 1400.00 1582.00 1581.90 1500.00 1682.01 1681.90 1600.00 1782.01 1781.90 1700.00 1882.01 1881.90 1800.00 0 58 N 68 2.9 E I 3 N 87 gE I 12 S 89 37 E 1 0 S 82 32 E 042 S 72 41 E 0 30 S 75 41 E 0 17 S 61 24 E 0 18 S 53 37 E 0 28 S 84 24 E 027 S 4~ 51E 1982.02 1981.90 1900.00 Z082.02 2081.90 2000.00 2182.03 2181.90 2100.00 2282.04 2281.90 2200.00 2382.06 2381.90 2300.00 2482.07 2481.90 2400.00 2582.07 2581.90 2500.00 2682.08 26~1.90 2600.00 2782.08 2781.90 2700.00 2882.08 28~1.90 2800.00 0 35 S 39 39 E O 48 S 41 29 E 050 S 39 I E 053 S 27 3 E 0 53 S 22 49 E 0 36 S 4 13 E 036 S I 24 W 035 S 3 7 W 0 34 S 7 46 W 0 18 S 25 20 W 2982.09 2981.90 2900.00 3082.09 3081.90 3000.00 3182.09 3181.90 3100.00 3282.09 3281.90 3200.00 3382.09 3381.90 3300.00 3482.10 3481.90 3400.00 3582.10 3581.90 3500.00 3682.10 3681.90 3600.00 3782.10 3781.90 3700.00 3882.10 3881.90 3800.00 017 S 30 34 W O25 S 9 OW 0 11 S 35 10 W 0 2O S 24 55 W 026 S 4 18 W 0 30 S 9 43 W 0 26 S 14 17 W 026 S 0 54 W 011 S 60 4 E 0 7 N 88 5~j W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/XO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0'00 E 0.06 0.44 0.01 S 0.20 E 0.16 O.ZB 0.05 N 0.34 E 0.04 0.27 0.10 S 0.35 E 0.07 0.35 0.16 S 0.63 E 0.00 0.38 0.28 S 0.72 E 0.35 0.29 0.11 S 1.26 E 1.03 0.34 0.37 N 1.90 E 1.88 0.00 0.97 N 2.68 E 2.99 0.00 1.77 N 3.71 E 0.00 N 0 0 E 0.20 S 86 52 E 0.34 N 82 16 E 0.36 S 74 44 E 0.65 S 75 28 E 0.78 S 68 50 E 1.26 S 85 0 E 1.93 N 79 4 E 2.85 Iq 70 1 E 4.11 N 64 30 E 4.09 0.07 2.43 N 5.05 E 5.16 0.48 2.91 N 6.80 E 5.82 0.00 2.86 N 8.71 E 6.46 0.89 2.78 N 10.73 E 6.65 0.18 2.44 N 12.13 E 6.69 0.58 2.12 N 13.08 E 6.71 0.00 1.90 N 13.67 E 6.60 0.18 1.62 N 14.12 E 6.67 0.07 1.45 N 14.74 E 6.70 0.21 1.19 N 15.50 E 5.61 N 64 18 E 7.39 N 66 51 E 9.17 N 71 48 E 11.08 N 75 28 E 12.37 N 78 37 E 13.25 N 80 47 E 13.80 N 82 5 E 14.22 N 83 28 E 14.81 N 84 22 E 15.55 N 85 37 E 6.26 0.26 0.50 N 16.06 E 5.72 0.25 0.41 S 16.89 E 5.03 0.00 1.51 S 17.85 E 4.1_6 0.00 2.76 S 18.66 E 3.08 0.16 4.18 S 19.34 E 2.05 0.00 5.43 S 19.71 E 1.06 0.34 6.51 S 19.74 E 0.08 0.05 7.54 S 19.72 E -0.93 0.26 8.59 S 19.63 E -1.65 0.00 9.29 S 19.45 E 16.06 N 88 12 E 16.90 S 88 37 E 17.91 S 85 9 E 18.87 S 81 34 E 19.79 S 77 47 E 20.45 S 74 36 E 20.79 S 71 45 E 21.11 S 69 4 E 21.43 S 66 21 E 21.56 S 64 28 E -2.18 0.00 9.78 S 19.22 E -2.73 1.04 10.26 S 18.96 E -3.24 0.20 10.78 S 18.88 E -3.61 O.7t 11.09 S 18.66 E -4.29 0.00 11.80 S 18.61 E -5.11 0.11 12.63 S 18.49 E -5.96 0.69 13.48 S 18.33 E -6.69 0.06 14.18 S 18.12 E -7.26 1.02 14.82 S 18.18 E -7.20 0.39 14.73 S 18.13 E 21.56 S 63 2 E 21.56 S 61 34 E 21.74 S 60 17 E 21.71 S 59 16 E 22.03 S 57 37 E 22.40 S 55 40 E 22.75 S 53 40 E 23.01 S 51 56 E 23.46 S 50 48 E 23.36 S 50 .53 E COMPUTATION DATE: 28-AUG-88 PAGE STANDARD ALASKA PRODUCTION CO. W - 24 PRUOHOE BAY NORTH SLOPE~ALASKA DATE OF SURVEY: 17-AUG-88 KELLY BUSHING ELEVATION: 81.90 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUS-SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERT[CAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 3982.10 3981.90 3900.00 408Z.11 ~081.90 4000.00 4182.11 4181.90 4100.00 4282.12 4281.90 4200.00 4382.12 4381.90 4300.00 4482.13 4481.90 4400.00 458Z.14 4581.90 4500.00 4682.17 4681.90 4600.00 4782.22 4781.90 4700.00 4882.25 4881.90 4800.00 0 24 N 6 51 W 036 N 6 OW 041 N 7 11 W 029 N 2 5 W 026 N 13 5 E 0 45 N 26 38 E I 8 N 43 15 E I 38 N 47 20 E I 35 N 44 22 E I 18 N 43 5 E -6.93 0.26 14.38 S 17.97 E -6.12 0.00 13.48 S 17.86 E -5.13 0.00 12.35 S 17.71 E -4.10 1.12 11.19 S 17.59 E -3.47 0.05 10.57 S 17.70 E -2.51 0.85 9.66 S 18.01 E -0.81 0.23 8.24 S 19.08 E 1.42 0.01 6.53 S 20.82 E 4.07 0.49 4.51 S 22.94 E 6.32 0.00 2.76 S 24.63 E ?.3.01 S 51 19 E 22.38 S 52 58 E 21.59 S 55 6 E 20.85 S 57 31 E 20.61 S 59 9 E 20.44 S 6I 47 E 20.78 S 66 37 E Z1.8Z S 72 35 E 23.38 S 78 52 E 24.78 S 83 36 E 4982.27 4.981.90 4900.00 5082.27 5081.90 5000.00 5182.28 5131.90 5100.00 5282.28 5281.90 5200.00 5382.28 5381.90 5300.00 5482.29 5481.90 5400.00 5582.31 5581.90 5500.00 5682.32 5681.90 5600.00 5782.33 5781.90 5700.00 5882.34 5881.90 5800.00 0 52 N 44 48 E 0 36 N 42 42 E 0 23 N ~_9 3 E 029 N 1 19 g 0 41 N 31 38 W 0 51 N 42 4 W 0 54 N 44 37 W 0 54 N 44 35 W 0 54 N 47 9 W 0 48 N 51 49 W 8.07 0.67 1.39 S 25.97 E 9.19 0.22 0.50 S 26.77 E 9.96 0.52 0.11 N 27.31 E 10.65 1.03 0.77 N 27.52 E 11.46 0.32 1.77 N 27.18 E 12.17 0.00 2.86 N 26.34 E 12.83 0.12 3.99 N 25.26 E 13.50 0.00 5.13 N 24.15 E 14.12 0.00 6.24 N 22.99 E 14.60 0.00 7.18 N 21.90 E 26.00 S 86 56 E 26.77 S 88 55 E 27.31 N 89 45 E 27.54 N 88 24 E 27.24 N 86 16 E 26.50 N 83 48 E 25.57 N 81 I E 24.69 N 78 0 E 23.83 N 74 48 E 23.04 N 71 50 E 5982.35 5981.90 5900.00 0 52 6082.41 6081.90 6000.00 3 5 6182.73 6181.90 6100.00 5 33 6283.35 6281.90 6200.00 7 28 6384.42 6381.90 6300.00 9 6 6485.83 6481.90 6400.00 9 51 6587.37 6581.90 6500.00 10 2 668.q. 94 6681.90 6500.00 10 9 6790.51 6781.90 6700.00 10 9 68917.29 6881.90 6800.00 11 32 N 48 36 W hi 28 14 W N 13 11 W N 5 9 W N 2 16 W N 3 22 E N 9 12 E N 16 13 E N 18 8 E N 7 20 E 15.09 1.27 8.06 N 20.99 E 16.73 3.18 10.56 N 19.09 E 22.68 1.58 17.95 N 16.48 E 32.34 2.07 28.97 N 14.76 E 45.69 1.19 43.62 N 13.88 E 61.44 1.27 60.45 N 14.03 E 78.43 0.87 77.91 N 15.98 E 96.01 1.38 95.27 N 19.84 E 113.80 2.71 112.10 N 132.43 2.69 130.63 N 22.48 N 68 59 E 21.81 N 61 3 E 24.37 N 42 33 E 32.51 N 27 0 E 45.78 N 17 39 E 62.06 N 13 4 E 79.53 N 11 35 E 97.31 N 11 45 E 25.62 E 114.99 N 12 52 E 29.39 E 133.89 N 12 40 E 6994.77 6981.90 6900.00 13 42 7098.25 7081.90 7000.00 15 50 7202.60 7181.90 7100.00 17 26 7307.94 7281.90 7200.00 19 7 7414.22 7381.90 7300.00 20 23 7521.32 7481.90 7400.00 21 35 7629.42 7581.90 7500.00 23 4 7738.76 7681.90 7600.00 24 43 7849.75 7781.90 7700.00 26 38 7962.42 7881.90 7800.00 28 4 N I 41 E N 1 17 W N I 53 W N Z 2 E N 6175 N 10 2O E N 16 13 F N 21 10 E N 25 16 E N 28 40 E 153.88 2.99 152.92 N 178.74 1.66 179.53 N 206.10 1.96 209.27 N 236.98 2.02 242.38 N 271.¢0 1.76 278.25 N 308.80 1.94 316.20 N 349.40 2.50 356.11 N 393.57 2.37 397.95 N 441.66 2.33 442.16 N 493.27 1.55 31.21E 156.07 N 11 32 E 31.33 E 182.24 N 9 53 E 30.28 E 211.45 N 8 13 E 30.29 E 244.26 N 7 7 E 32.95 E 280.20 N 6 45 E 38.51 E 318.54 N $ 56 E 47.89 E 359.32 N 7 39 E 62.15 E 402.77 N 8 52 E 81.18 E 449.55 N 10 24 E 488.36 N 104.80 E 499.47 N 12 6 E STANDARD ALASKA PROOUCTION CO. W - 24 PRUDHOE BAY NORTH SLOPE,ALASKA COMPUTATION DATE: 28-AUG-S8 PAGE 7 DATE OF SURVEY: 17-AUG-88 KELLY BUSHING ELEVATION: 81.go FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF SU~-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 8076.08 7981.90 7900.00 28 33 BlgO.40 8081.90 8000.00 29 29 8306.48 8181.90 8100.00 31 46 8424.30 8281.90 8200.00 32 21 8544.55 8381.90 8300.00 35 7 8668.97 8481.90 8¢00. O0 37 56 8798.57 8581.90 8500.00 41 12 8934.87 8681.90 8600.00 44 39 9081.00 8781.90 8700.00 47 57 9229.93 8881.90 8800.00 47 54 9381.74 8981.90 8900.00 49 30 9625.00 9137.62 9055.72 50 28 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG MIN N 25 4 E 546.95 N ZO 39 E 602.30 N ZO 3 E 661.21 N 17 9 E 723.45 N 17 10 E 790.02 N 20 4.2 E ~J63.94 N 25 16 E 946.28 N 29 57 E 103g.25 N 31 24 E 1143.14 N 30 46 E 1251.81 2.78 1.63 1.05 2.17 2.25 3.23 3.17 3.53 0.70 1.29 536.21 N 129.87 E 551.72 N 13 36 E 587.34 N 151.14 E 606.47 N 14 25 E 642.68 N 171.34 E 665.13 N 14 55 E 701.70 N 191.2'7 E 727.31 N 15 14 E 765.59 N 210.63 E 794.04 N 15 ZZ E 835.64 N 234.46 E 867.90 N 15 40 E '1 911.38 N 266.87 E 949.65 N 16 19 E · 993.42 N 309.72 E 1040.58 N 17 18 E 1034.53 N 354.91 E 1144.28 N 18 35 E 1178.95 N 622.05 E 1252.ZZ N 19 41 E N 29 41 E 1364.58 N 28 31 E 1549.75 1.14 0.00 1277.56 N 479.69 E 1364.65 N 20 34 E 1441.20 N 569.9! E 1549.80 N 21 36 E SCHLUMBERGER O l RECT ~ ONAL SURVEY COMPANY STANOARO ALASKA PROOUCTION WELL W-24 FIELD PRUOHOE BAY COUNTRY USA RUN 1 BATE LOOOEO 17 - AUG - 88 REFERENCE 72901 WELL ' (521' W-24 SNL, (44-16-11-1 HORIZONTAL PROJECTION 1178' WEL, SEu 21, TllN, R12E) I~F 72~)01 5CRLE = I/SO0 IN/FT WELL ' (521' W-24 (44-16-11-1~'-'~' -" VERTICAL SNL, 1178' WEL, St.,, 21, TllN, R12E) PROJECTION -~000 -~ 0 0 BO0 lO~ ~0 ZOO0 II IIii .~ ...... ] 111 ........ ..~-Y.L.~- L~ L~ ~:~ ~ ~..~ ~:~_~.~_~ ~ ~ ~ ~ ~~.~-..~-L..~ ..... 'T~] ~: i~' ?::?::t:::t ': '~ ~-t t:t ::~?- ~-~-i-~"~"T'~"~- &-L.~L.$.~.~-~-..~L.L....~.L.L..~ ..... L.L..L~ ..... YJ-~:~.Y-~-~.~ ...... ~..5-+.: ~..L~.L..L.- '.~-~..;...L.Z..~-i-~...~ ....... ~..~...L.~-+..L..~..~...i ..... L..L..L-L.. ~...~.-~-L-Y.., -~.~...Y-~... -i.-;-.~..; ...... ~...;...~..L..~...L..~...L..L. 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L~ L.~-.L..~-;...L., .4.+~:; ...... ~4.-~4-..~...~444-.~...;--.~.--~.+-~---~.--+..-+.+-~.-.+4-~.~-.-~ ~ ~ ~ ~ H--~+---+-.H...+.-.. -..~-~.-~.-4- ,..4--~...~..-~- ~--.~-..~-~-4-. F.4---~---~---;--4 -..+-.+-.-~-+-~-.+-.~-~ ~ ~ '~ ~ - ~"?~ "?'"~-?"~ ...... ~ ~ ~ ~ i i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i : : : : : : : : ~ ~ ~ ~ ~ ~_~_ : ~.~...~....,~...;..~...;_,...~..~...;...~.~..~.,.~.,.+..,~ "-~'"~ "'?-'?"?'~ .... ~'-?'~" ~'"?"~'"~-'?" "?'"?"~'-~-' "?"?"~' ~ ~" : :~:H:~: ::~::~:::~d: :::~::~::~:t: :::t:~:::::::~:: :::::::::::::::::::::::::::::::::: :~;;% %::;:~: PROJECTION ON VERTICAL PLANE ~1. - 20]. (~CAL£B IN VERTICAL DEPTHS HORIZ SCALE = ]/SO0 IN/FT Teleco Oilfield Ser s of Alaska Inc. 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 August 22, 1988 JOB #644 STANDARD ALASKA PRODUCTION CO. WELL: W- 24 EILEEN WEST END RIG: Nabors 22-E Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to Standard Alaska Production Company. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Dave Reimer Field Service Supervisor DR/el Enclosures A ,~1_~'!' COMPANY TELEC00ILFIELD SERVICES JOB 644 SURVEY CALCULATIONS **************************************** Date Page 08/12/88 Company: STANDARD ALASKA PROD. Well: W-24 Location: PRUDHOE BAY; E.W.E. Rig: NABORS 22-E CO. TELECO Job # 644 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 30.80 degrees 30.80 degrees 7.42 degrees RADIUS OF CURVATURE CALCULATION **************************************** MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** TIE INTO CDC SINGLE SHOT 5980.00 0.7 16.2 N 16 12 E 5979.49 28.95 25.22N 2.15E 25.31 N 4.873E 0.000 TELECO MWD SURVEYS 6172.00 5.3 345.8 N 14 12 W 6171.14 34.26 34.82N 2.08W 34.89i N 3.422W 2.162 6274.00 7.3 354.6 N 05 24 W 6272.52 44.94 45.84N 3.98W 46.01 N 4.969W 2.172 6355.00 8.9 357.1 N 02 54 W 6352.71 56.12 57.22N 4.81W 57.42 N 4.806W 2.022 6088.00 3.6 337.4 N 22 36 W 6087.40 28.40 28.64N 0.02W 28.64 N 0.054W 2.745 5993.00 1.1 315.9 N 44 06 W 5992.48 25.47 25.41N 2.10E 25.50 N 4.728E 7.523 TELECO Job # 644 TAK 08/12/88 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 6452.00 9.8 3.0 N 03 00 E 6448.42 71.74 72.98N 4.79W 73.13 N 3.761W 1.355 6548.00 10.1 8.7 N 08 42 E 6542.97 88.32 89.47N 3.10W 89.52 N 1.989W 1.072 6642.00 10.1 15.0 N 15 00 E 6635.52 104.74 105.59N 0.27E 105.59 N 0.150E 1.175 6736.00 10.1 21.7 N 21 42 E 6728.06 120.92 121.23N 5.46E 121.35 N 2.580E 1.249 6847.00 10.8 8.3 N 08 18 E 6837.22 140.83 140.63N 10.66E 141.04 N 4.335E 2.273 6943.00 12.6 3.7 N 03 42 E 6931.22 160.29 159.99N 12.69E 160.49 N 4.537E 2.110 7037.00 14.8 0.9 N 00 54 E 7022.54 182.46 182.23N 13.58E 182.74 N 4.265E 2.444 7094.00 15.8 358.1 N 01 54 W 7077.52 197.35 197.27N 13.45E 197.73 N 3.903E 2.182 7~08.00 17.7 358.8 N 01 12 W 7186.68 229.80 230.11N 12.56E 230.45 N 3.126E 1.676 7302.00 19.1 3.0 N 03 00 E 7275.87 259.28 259.77N 13.03E 260.09 N 2.873E 2.050 7398.00 20.3 6.9 N 06 54 E 7366.25 291.60 292.00N 15.82E 292.43 N 3.102E 1.854 7493.00 21.2 10.4 N 10 24 E 7455.09 325.25 325.27N 20.88E 325.94 N 3.674E 1.612 7589.00 22.4 15.3 N 15 18 E 7544.22 360.72 360.02N 28.81E 361.17 N 4.576E 2.270 7681.00 23.6 19.9 N 19 54 E 7628.90 396.10 394.27N 39.68E 396.26 N 5.747E 2.348 7777.00 25.3 24.1 N 24 06 E 7716.29 434.54 431.10N 54.56E 434.54 N 7,213E 2.532 7871.00 26.9 27.6 N 27 36 E 7800.70 473.77 468.31N 72.58E 473.91 N 8.811E 2.362 7966.00 28.3 30.1 N 30 06 E 7884.89 514.73 506.86N 93.82E 515.47 N 10.487E 1.912 TELECO Job # 64~4 TAK 08/12/88 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 8078.00 28.7 25.2 N 25 12 E 7983.32 564.86 554.18N 8171.00 29.3 22.4 N 22 24 E 8064.66 608.11 595.43N 8266.00 31.7 21.7 N 21 42 E 8146.51 654.76 640.12N 8334.00 32.0 20.6 N 20 36 E 8204.27 689.62 673.58N 8436.00 32.4 8531.00 35.0 17.8 N 17 48 E 18.1 N 18 06 E 8290.58 742.82 724.91N 8369.61 794.64 775.05N 8627.00 37.3 20.6 N 20 36 E 8447.12 850.04 828.47N 8728.00 39.6 24.1 N 24 06 E 8526.21 910.71 886.55N 8822.00 42.1 27.3 N 27 18 E 8597.31 969.08 941.94N 8987.00 46.8 9104.00 48.3 31.9 N 31 54 E 31.5 N 31 30 E 9171.00 48.3 8715.07 1076.02 1042.35N 8794.03 1154.71 1115.80N PROJECTED BOTTOM HOLE LOCATION 31.5 N 31 30 E 8838.60 1200.37 1158.44N 118.61E 566.74 N 12.081E 136.81E 610.95 N 12.940E 154.90E 658.60 N 13.604E 167.85E 694.18 N 13.993E 185.72E 748.32 N 14.371E 201.97E 800.93 N 14.606E 220.73E 857.37 N 14.919E 244.61E 919.67 N 15.425E 271.26E 980.22 N 16.066E 328.31E 1092.83 N 17.483E 373.67E 1176.70 N 18.515E 399.83E 1225.50 N 19.042E 2.117 1.596 2.554 0.961 1.514 2.742 2.846 3.135 3.468 3.452 1.307 0.059 ^ lO00 800 0 5500 8500 7000 LI.I 7500 8000 8500 9000 ,~. - : ~ ' ~ '-- ; [--~-..;~~-.--~~~....-~ ..... ~ ......... t-a---p--,-~ ("%-' ~i ;: i'~ ~'a~ ...... ~ ...... ~'-'~'~'~-~-'-+-*-~-~~-*-~"-' ~-~j ~ , .... -~" ~--"~"~~ , . .... ~ ~--'~'~--'. ~ ~ ~'~ t ' ~ '-~, '--~'~F. . ,. j' .... " 1 , I ~ . ' I i ' : · ' t__/ . ,~ . ' I I ! .., ,, ,. , _:~.~ ......L__L ~ . ...... i ..... ~ .... ~....~ ....... F'~--; .... ': .... , i ~ .~ ..........~ STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 29, 1988 at 0600 hrs Rig: Nabors 22E Well: W-24 (44-16-11-12) AFE # 120744 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: Water Used: ~1 Current Operation: Rig released from W-6 @ 2130 hours. Moving rig to W-24. Mud Type: WT: VIS: PV: YP: FL: Solids: Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDItOE BAY August 1, 1988 at 0600 hrs Rig: Nabors 22E Well: W-24 (44-16-11-12) AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 2700' Day: 3 72- Hour Ftg: 2590' Water Used: 2800 Current Operation: NU BOPs. Accept rig @ 1500 hours on 7/29/88; spud @ 2200 hours. Drill & survey 17-1/2" hole to 2700'. Run and cement 13-3/8" casing. · Mud Type: Gel WT:9.8 VIS:59 PV: 18 YP:29 FL:9.2 Solids: 10.5 Temp: °F STANDARD ALASKA PRODUCTION Rig: Nabors 22E Well: W-24 (44-16-11-12) Daily Drilling Report-- PRUDHOE BAY August 2, 1988 at 0600 hrs AFE # 120744 AFE Amount: Current Amount: Current Operation: 0600 Depth: 3635' Day: 4 24- Hour Ftg: 935' Water Used: 700 Drilling 12-1/4" hole. NU and test BOPE. Drill out and perform leak off test. Drill and survey 12-1/4" hole to 3635'. Mud Type: Ligno WT: 9.7 VIS: 41 PV: 12 YP: 5 FL: 8.4 Solids: 10 Temp: 59 °F STANDARD ALASKA PRODUCTION Rig: Nabors 22E Well: W-24 (44-16-11-12) Daily Drilling Report-- PRUDHOE BAY August 3, 1988 at 0600 hrs AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 4867' Day: 5 24- Hour Ftg: 1252' Water Used: 1000 Current Operation: Drilling 12-1/4" hole. Drill & survey 12-1/4" hole to 4867'. Mud Type: Ligno. WT: 9.8 VIS: 44 PV: 12 YP: 8 FL: 6.4 Solids: 11 Temp: °F STANDARD ALASKA PRODUCTION Rig: Nabors 22E Well: W-24 (44-16-11-12) Daily Drilling Report -- PRUDHOE BAY August 4, 1988 at 0600 hrs AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 6000' Day: 6 24- Hour Ftg: 1133' Water Used: 700 Current Operation: PU Dynadrill. Drill and survey 12-1/4" hole to 6000'. Mud Type: Ligno WT: 10.1 VIS: 46 PV: 17 YP: 7 FL: 5.2 Solids: 11 Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY August 5, 1988 at 0600 hrs Rig: Nabors 22E Well: W-24 (44-16-11-12) AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 6342' Day: 7 24- Hour Ftg: 342' Water Used: 600 Current Operation: Dyna-drill @ kick-off point. PU Dyna-drill. Dyna-drill to 6347'. Prepare to kick-off. Mud Type: Ligno. WT: 10.2 VIS:52 PV:22 YP:8 FL:5.6 Solids: 10 Temp: 82°F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY August 8, 1988 at 0600 hours Rig' Nabors 22E Hell' H-24 (44-16-11-12) AFE# 120744 AFE Amount' Current Amount' 0600 Depth: 8016' Day: l0 72-Hour Ftg: 2,074' Hater Used: 12,000 Current Operation' POH. LD Dynadrill. Drill and survey 12-1/4" hole to 6786. Dynadrill 12-1/4" hole to 7267. Drill and survey 12-1/4" hole 8016'. Mud Type' Ligno HT' 10.2+ VIS' 42 PV' 13 YP: 5 FL' 5.7 SOL' 12 Temp' lO0 °F .. STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY August 9, 1988 at 0600 hours Rig: Nabors 22E Nell: N-24 (44-16-11-12) AFE# 120744 AFE Amount: Current Amount: 0600 Depth: 8409' Day: ll 24-Hour Ftg: 393' Nater Used: 600 Current Operation: Dyna-drilling 12-1/4" hole. Dyna-dri 11 12-1/4" hole to 8409'. Mud Type: Ligno NT: 10.2 VIS: 42 PV: 15 YP: 6 FL: 5.5 SOL: 13 Temp: 108 °F STANDARD ALASKA PRODUCTION ~ ° Rig: Nabors 22E Well: W-24 (44-16-11-12) Daily Drilling Report-. PRUDHOE BAY. August 10, 1988 at 0600 hrs AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 8700' Day: 12 24- Hour Ftg: 291' Water Used: 500 Current Operation: Drilling 12-1/4" hole. Test BOPE. Drill and survey 12-1/4" hole to 8700'. Mud Type: Ligno WT: 10.3+ VIS: 46 PV: 19 YP: 7 FL: 5.0 Solids: 14 Temp: °F STANDARD ALASKA PRODUCTION Rig: Nabors 22E Well: W-24 (44-16-11-12) Daily Drilling Report -- PRUDHOE BAY August I1, 1988 at 0600 hrs AFE # 120744 AFE Amount: Current Amount: Current Operation: 0600 Depth: 9110' Day: 13 24- Hour Ftg: 410' Water Used: 500 Drilling 12-1/2" hole. Drill and survey 12-1/4" hole to 9110'. Mud Type: Ligno WT: 10.3+ VIS: 44 PV: 17 YP: 7 FL: 5.8 Solids: 14 Temp: 95 °F STANDARD ALASKA PRODUCTION Rig: Nabors 22E Well: W-24 (44-16-11-12) Daily Drilling Report .. PRUDHOE BAY August 12, 1988 at 0600 hrs AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 9171' Day: 14 24- Hour Ftg: 61' Water Used: 400 Current Operation: Cementing 9-5/8" casing. Drill 12-1/4" hole to 9171'. Run 9-5/8" casing. Mud Type: WT: 10.3 VIS:45 PV: 16 YP: 17 FL:5.2 Solids:13-1/2Temp: eF STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY August 15, 1988 at 0600 hrs Rig: Nabors 22E Well: W-24 (44-16-11-12) AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 9625' Day: 17 72- HourFtg: 454' Water Used: 900 Current Operation: POOH. Cement 9-5/8" casing. NY and test BOPE. Drill 8-1/2" hole to 9625'. Log 8-1/2" hole. Run sidewall cores. Make wiper trip. Run and cement 7" liner. Mud Type: Ligno WT: 9.5+ VIS: 40 PV: 12 YP: 7 FL: 8.2 Solids:9 Temp: 80 °F STANDARD ALASKA PRODUCTION Rig: Nabors 22E Well: W-24 (44-16-11-12) Daily Drilling Report-- PRUDHOE BAY August 16, 1988 at 0600 hrs AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 9625' PBTD Day: 18 24- Hour Ftg: Water Used: 400 Current Operation: POOH. Dress off tool. Clean out liner. Test casing to 3000 psi. Mud Type: Ligno WT: 9.5 VIS: 68 PV:20 YP: 18 FL: 10 Solids: Temp: · Rig: Nabors 22E Well: Wo24 (44-16-11-12) STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY August 17, 1988 at 0600 hrs AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 9580' PBTD Day: 19 24- Hour Ftg: Water Used: 400 Current Operation: IH to perforate. Displaced well to brine. Ran cased hole logs. PU perforating guns. Mud Type: NaC1 WT: 9.1 VIS: PV: YP: FL: Solids: Temp: cF STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY August 18, 1988 at 0600 hrs Rig: Nabors 22E Well: W-24 (44-16-11-12) AFE # 120744 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: Water Used: 9580' PBTD 20 200 Current Operation: Making up robing hanger. Perforated well. Ran robing. Mud Type: Brine WT: 9.2 VIS: PV: FL: Solids: Temp: °F STANDARD ALASKA-PRODUCTION Rig: Nabors 22E Well: W-24 (44-16-11-12) Daily Drilling Report -- PRUDHOE BAY August 19, 1988 at 0600 hrs AFE # 120744 AFE Amount: Current Amount: 0600 Depth: 9580' PBTD Day: 21 24- Hour Ftg: Water Used: 800 Current Operation: Moving rig to W-17. Nippled up and tested tree. Set and tested packer. Displaced annulus to brine and robing to diesel. Set back pressure valve. Released rig at 2400 hrs on 8/18/88. Mud Type: Brine WT: 9.6 VIS: PV: YP: FL: Solids: Temp: STANDARD ALASKA PRODUCTION CO. PAD W(441-16-II- 1:2 } W 24 Controlled Drilling Consultants, Inc. LES HENDERSON 333-1552 CON rtOLLED DRILLING CONSULTAN rs, INC. P.O. Box 190560 Anchorage, Alaska 99519-0560 (907) 333-1552 August12,1988 Mr. Brain Rose Standard Alaska Production Company Pouch 6-612 Anchorage AK. 99502 × Re: Magnetic Single Shot Survey Job No.A-O788-O29 Well W-24(44-16-11-12) Prudhoe Bay Field North Slope, Alaska Date of Survey: 7-29-88 to 8-11-88 Dear Mr. Rose' Please find enclosed the "Original" and six (6) copies of our Magnetic Single Shot Survey on the above well. The method used in calculating this survey Radius of Curvatur.e. The depth of the survey was O'to 9171'. Thank you for giving us this opportunity to be of service Yours very truly, Controlled Drilling Consultants, Inc. ., Les Henderson Directional Supervisor HORIZONTAL VIEW STANDARD ALASKA PRODUCTION CO. WELL W-24(44-16-11-12) RADIUS OF CURVATURE MAGNETIC SINGLE SHOT SCALE: I": 1,000' AUGUST 16, 1988 TVD = 8,838' TMD: 9~171' ALL DEPTHS SHOWN ARE TVD RECORD OK SURVEY TRUE MEAS. DRIFT VERTICAL SUB DRIFT 'TOTAL COORDINATES C L 0 S DEPTH ANGLE DEPTH SEA DI :E~R " DISTANCE D H DEG, 0 0 0 348 0 15 93~= 0 45 i490 0 30 2680 0 45 3t80 0 15 3672 0 4847' 5630 348,00 931,97 1489,94 2i52,88 2679,.82 3179 80 ~67i 79 4221 76 4846 68 ~29 5S 5979 48 6087 ~9 6182 08 6274 48 6~52 67 6448 S8 6542 94 6635 48 6728,02 69S0,96 7022,28 7077,26 7186,42 -8t,90 266,~0 850,07 1408,04 2070,98 2597,92 3097,90 3589,89 4139,86 4764,78 5547,68 5897,58 6005,49 6100,!8 6192,58 6270,77 6366,48 6461,04 6553,58 6646,!2 6849,06 6940,38 6995,36 7~04, 5°~ 5980 0 45 6088 3 36 6183 5 ~0 ~¢6 7 aO 6355 8 54 6452 9 48 6548 I0 6 6642 iO 6 6736 lO 6 694~ 12 36 7037 i 4 48 7094 t 5 48 7208 i 7 42 I 7 7 5 2 16 ~5 43 54 158 2;'.8 ,62 S ,t7 N ,92 N ,51 S ,¢.,8 $ ,84 S ,i3 $ ,82 S N O0 N 4i N 64 N 40 N 90 N ,02 N ,66 N ,28 N ,47 H ,5i N ,35 N 3,32.2 W i ,91 E 9,36 E It,62 E 8 92 E 6 91 E ~ i7 E 8 O0 E 9 68 E 7 19 E 5 83 E 2 04 E i 2~ E i 20 E 2 @5 E 6 23 E ii 4~ E 20 ~4, E 21 2~ E 2i lO E .--°0 , 2t E U R E S ANGLE O0 S 90 76 S 35 3 52 N 70 3 49 N 3~ 9 48 S 80 14 50 S 5~ i i ,88 S 48 .9 9~ S 44 6 63 $ 28 8 32 N 74 !9 04 N .30 3 iON 26 46 N 33 20 N 4.3 46 N 54,66 N 70,41 N 86.. 94 N I 03.21 N 1!9,2i N t59.53 N iSl , ,.'--- ,N. 196,65 N 229 n~ N DOC LEG :SEVER I 'TV DEG/t 0 OFT ,000 04.~ 075 04.7 i O0 05i O 4 '~ , 08'2 . i,4.S 2,639 2, 00:3 2.154 ,774 .943 , :3 S 7 i 2 348 'i 792 SRPC WELL W-24 S]!,tGLE SHOT SUF.:VEY ,JOS NO R-0788-.029 COMPUTER.- ~',5 AUC. S;i;', RECORD OF SURVEY HEAS, DRIFT DEPTH ANGLE D M TRUE VERTICAL DEPTH SUB SEA DRIFT DIREC DE6, 7302 19 6 7398 20 18 7493 21 t2 7589 22 24 76$I 23 36 7777 25 18 7871 26 54 ' 7966 28 18 8i7i 29 i8 8266 3i42 8436 32 24 8627 37 i8 8728 39 36 ~ · 08z2 42 8987 46 48 9104 48 18 7275 61 7365 99 7454 83 7543 96 7628 64 7716 03 7800,44 7884,63 8064,27 8146.J2 8290,2i 8446,9i 8526,00 8597,10 87t4,85 8793,82 7193,71 N 3, 7284, 09 N 6,90E 7372,93 Ni O. 40E 7462,06 NI 5.30E 7546.74 Ni 9 , 9OE 7634, t 3 N24, i OE 77! 8,54 N27 , 6OE 7802,73 N3O, I OE 7992,37 N22,4OE 80~4,22 N2~ . 7OE 8208,3~ Ni7,SOE 8365, Ol N20. 8444,t0 N24,1OE 85J5,28 N27..3OE 8632,95 NSl ,gOE 87i t,92 N3~ ,50E THE FOLLOWING IS EXTRRPOLATED TO TD 9171 48 18 8838,3'3 8756,49 N31,50E BOTTOM HOLE CLOSURE t226,29 FEET RT H TOTAL COORDiNaTES "*~ 01 N ~O 68 E 290,25 N 23,47 E 32~,52 N 28,53 E 358,26 N ~6.45 E ~92,.~° N 47,TM~ E 429.35 N 62,20 E 466,56 N 80,23 E 505,10 N I0~,46 E 593,61 tq 145,ii E 838,36 N I63,2i E 723,19 N 193,69 E ~26,22 N 229,57 E 884,29 N 253,45 E 939,68 N 280,t0 E i048,09 N 3J7,~5 E ti~3,54 N 382,5~ E C L 0 D I STANCE S U R E S ANGLE D 2.58,84 N 291 19 N 324 77 N 360 1t N 395 36 N 433 83 N 473 4 i N 515 2O N 611 09 N 659.8~ N 748,67 N 857,52 N 9i9,89 N 980,54 N 093,37 N 177,4l N , ',".4 ~.v E 4 ~7 2i E 5 2 22 E 5 48 36 E 6 52' 2'7 E 8 14 2:6 E 9 45 ;25 E 11 2i 29 E iS 44 i2 E i4 28 35 E i4 59 76 E ~5 3~ 4~ E i5 59 33 E 16 ~ 54 E t7 5F 6 E ~8 57 28 E 1156, 19 N 408,65 E t226,29 N 19 27 55 E t3 27 55 E nn:" LEG SEVER ~ TV rjEG,..' i 0 OFT t i i I i ! 2 2, '7 564. 3;i. 2 0 6 4,53 53i 948 ~4 777 677 .000 '-3 E C T }: 0 N D i $ 'f ,q ~--: C E 258 52 29 0 85 .324 49 359 97 .'.:", 9~ 34 4 ,,'3 S79 4'? 3 0 i 5i3,98 607.38 654, 03 742, ~ 4 948,94 na 074 -92 I53.6i 1199.29 DEPTH TRUE VERTICAL SUB DEPTH SEA HD-TVD DIFFERENCE VERTICAL CORRECTIOH TOTAL COORDINATES 182 282 382 482 582 682 782 882 982 ~082 ;182 i282 ;382 1482 ;582 ;682 1782 1882 1982 2082 2182 2282 2382 2482 2582 2682 2782 2882 2982 3082 3182 3282 3382 3482 O# 182, 282. 382, 482, 582, 682. 782, 882. 982, 1082, 1282. ~382, 1482. t582 1682 ;782 ;882 ;982 2082 2182 2282 2382 2482 2582, 2682 2782 2882 2982 3882 3282 3382 3482 -82 100 200 300 400 500 600 700 800 900 I200 ~400 JSO0 1600 1700 ~808 2000 2100 2200 2300 2400 2500 2600 2700 2808 2900 3000 3100 3200 3400 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ,00 ,05 N ,,22 S ,73 8 1.01 $ 4,07 8 ,79 S ,I7 S ,70 N t,72 N 2,60 N 3.18 N ~,42 N 3,34 N 2,96 N '~ 54 N '" 05 N ~,48 N ,81 N ,04 N ,83 S ~,82 S 3,05 S 4,45 S 5 ~o S 7,~7 $ 8,70 S 9,66 S ~,92 S 9.51 S 8,68 S 7,83 S 7,44 S 7,22 S 7, S 0 S S ,00 ,,55 1,7t 2.46 3,34 2, 98 1,t4 94 I ,7, 6o ~ 66 7 04 ~ 36 9 7~ ~0 89 ~1 66 i2 O0 ii,Si iO 88 9 :E', 7 9 03 8 ?2 970 W W W W W E E E E E E SE E E E E E E E E E E E E E .SAPC WELL W-24 MEASURED DEPTH MEAoURED DEPTH ~INGL. E SHOT ._,JRVE ,JOG: i',40 AND OTHER DATA FOR EYERY EVEN 100 FEET OF SUB A.-0788-029 DEPTH TRUE VERTICAL SUB MD-TVD VERTICAL DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES COMPUTER- KB ELEV 7582 3682 3782 3882 3982 4082 4i82 4282 4382 4482 4582 4682 4782 4882 4982 5082 5i82 5z82 5382 5482 5582 5682 5782 5882 5982 6083 6183 6283 6385 6486 6588 6689 679i 6995 3582, 3500 3682, 3600 3'782, 7700 3882, 3800 3982, 3900 4082, 4000 4182, 4i00 4282. 4200 4382. 4300 4482, 4400 4582. 4500 4682, 4600 4782, 4700 4882, 4800 4982, 4900 5082, 5000 5t82, 5i00 5282~ 5200 5382, 5300 5482, 5400 5582, 5500 5682, 5600 5782, 5700 5882, 5800 5982, 5900 6082, 6800 6i82, 6i00 6282, 6200 6382., 6300 6482. 6480 6582, 6500 6682, 6600 6782, 6700 6882, 6800 6982, 6900 7.72 S 7.21 S 7 ~:9 "' 8 20 S 8 O0 S 7 29 S 6 26 S 5 06 S ~ 77 S 2 45 S I 14 S '17 N t 46 N 2 70 N 3 75 N 4,55 N 5,09 N 5.32 N 5,2'3 N 4.80 N 4.05 N 17.35 N i9,06 N 28,6~ N ,~1 .98 N 25.50 N ~"~' 98 N 44, "~ ,~.~ N 78.2I 9 ~, 7,3 N i10.94 N 28,02 N 147.63 N ~70~8 N SAPC !.~ELL ,, -24 MEASURED DEPTH MEASURED DEPTH ?2os 7522 7630 7¢:39 8077 8426 8802 89~9 9~86 9171 SINGLE SHOT SURVEY JOB AND OTHER DATA FOR EVERY EVEN 100 FEET OF TRUE VERTICAL StB MD TVD DEPTH SE~ DIFFERENCE VERTICAL CORRECTION 7082, 7000 7182, 7100 21 7282, 7200 26 7382, 7300 :33 7482, 7400 40 7582. 7500 48 7682, 7600 57 7782, 7700 68 7882, 7800 8t 7982, 7900 94 8082, 8000 8t82, 8~00 I26 8282. 8200 i44 8382, 8300 t64 8482, 8400 !89 8582, 8500 219 8682, 8600 257 8782, 8700 304 8838, 8756 332 5 5 7 7 8 11 17 t8 20 25 30 .38 47 28 NO A-0788-029 SUB SEA DEPTH. TOTAL COORDIHATES 196,83 226.92 260.20 296,I2 333,92 J73,47 414.75 458.25 503.84 551.86 602,86 658.97 7~8 19 78i 42 851 50 927 56 OlO 79 102 19 t56 t9 20,24 24 21 30 58 .40 55 9.3 75 97 'I00 7:3 'i26 .34. ~.48 9t t71 24 192 07 239 46 27~ 95 319 45 375 54 4 08 55 -) COHPUTER- 15 AUG 88 KB ELEV 81 .90 ~:T, E E E E E E E E E E E E E E E E E E E DEPTH 0 2000 3 O00 4000 5000 6000 ?000 8000 9000 TRUE YERTICAL DEPTH ~000, 2000. 4000, 5000 5999 6986 79J5 8724 8838 -82, 918, 'i918 3918 49t8 6905 7833 :3642 8756 TOTP. L COORDi MATES i 7 i ~ :30 N 519, i8 N 048, I 5 N I56, I9 N ,,O0 b~ 2,85 N 7,,27 E 8,92 E 4,i6 E t0 'i9 E 7 09 E 20 99 E JO9 4'i E 342 'I 6 E 408 65 E INDEXED HOUSTON A~CO STANDARD C~EVRON ALASKA PRODUCTION 08/18/88 EXXON Date: TO: TEMCO TI: 79219 MARATHON MOBIL PHILLIPS STATE OF ALASKA --. GEOSCI~NCES REF ER.ENCE: ARCHIVES SAPC OPEN HOLE FINAL LOGS The following m~terlal is being submitted hecevlth. Please acknowledge receipt by signing a copy of this letter and returning It to this office: DAL/UNIT/STATE: W-24 DIL/SFL 08/13/88 ~1 9137-9608 Sch 2"/5" W-24 BHCS 08/13/88 #1 9137-9578 Sch 2"/5" W-24 LDT/CNL poro raw 08/13/88 #1 6858-961~ Sch 5" ARCO/EXXON/SAPC ONLY: W-24 SSTVD 08/13/88 #1 9137-9616 Sch 1"/2" STATE ONLY: /-~D IREC~T~N~/~RVEYS/~ ~/~ Magnetic Single Shot Direct~ab~~UD~. ~1z~-88- Job# A-0788-029 t 7 88 72901 Cy~OScoptc Directional Su~ ~~ ~/ Da~~~7-88 3ob~ ~D ( ~(~,;~,Date: ~-22m88. Jo5~ 644 R~e I veal ~ / ~:~ : , ...... Jennifer Dietz Ooto ~ /~0%~ Lk U~o', .... ~m'~f%~ Well Rec~ds LR2-I Standard Alaska P~oducllon Company 900 Foss Be,~son Boulevard P.O. 8<). 196612 Ar~¢horocje, Alaska 99~ 19-6612 i907~ ~64 SI I I ARCO EXXON STANDARD .,\t A~-~.,',;",. :4? .! ,i ~.~ Date: 08/29/88 PHILLIPS IO: T#: 79256 STATE OF AK SYSTEMS (Transmittal & Tape) ARCH IVES REFKRSI~KiE: SAPC ~tAGNETIC LIS TAPES & LISTINGS Tne following material is being submitted herewith. Please acknowledge receipt signing a copy of this letter and returning it to this office: W-24 OH/DIL/BHC/LDT/CNL Sch#72886 1600bpi 08/13/88 #1 6858-9636 API#50-029-21833 Tape Pos.#06030 ~/PPiease Tape sent 08/16/88. The GR data in send back the OH ~ng was inadvertenly removed..._ ___, Anchorage * EXXON: An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly from the respective service company. Please confirm this. Received Date u0,,s at ,he o,.g,.~o~ 5'o,,do.d O.I Co,'~pu,,~ Jennifer Dietz INFORMATION (I~iROL Well Records ~R2-1 Please find enclosed a replacement LIS tape and verification listing for the SAPC Prudhoe Bay West End W-24 logging data. On our original distribution, the Gamma Ray data in casing was inadvertently removed. It has since been remerged, and the complete new tape and listing replace that in your file. Our apologies for any inconvenience this may have caused. Schlumberger Well Services Anchorage Computing Center RF.C[IV£D SF_P - 2 1988 (las Cons. Comrnissio~3 Anchorage Slanda~d Ala$1~a P~'o~u¢ f;on Company 900 Eo,~ An(ho~o~. klo~o 99519 661~ ~907. 564 51 I I ARCO Pit I TO: STANDARD Date: 08/16/88 T~: 79210 SYSTF. NS (Trains;al ct;i! & ARCit IVES REF~'~CE: SAPC ,%~,(;NETIC I. IS TAPES ,% LISTIN(;S /he followir~j material is t>?ing st~nitto] t~_,rt~ith. Please ackno~le~je receipt O/ signing a co?/ of .this letter and returning it to this office: W-29 OH/DIL/BHC/LDT/CNL 08/13/88 #1 6858-9636 Sch #72886 1600bpi API#50-029-21833 Tape Pos. #06030 OH/DIL/MSFL/BHC/LDT/CNL 08/10/88 #1 7694-10956 Tape Pos.#06032 Sch#72885 1600bpi API#50-029-21834 ARCHVIES ONLY: W-24 OH/field 08/14/88 #1 Tape Pos.#06031 Sch#72886 1600bpi w-29 OH/BHC/LDT/CNL #1 Tape Pos. #06033 Sch#72885 1600bpi , W-29 OH/DIL/MSFL #1 Tape Pos. #06034 Sch#72885 800bpi '~ EXXON: An Asterisk (*) next to a listing above means you shoul(l have received the Tape(s) and Listing(s) directly from the respective service company. Please confirm R~eiv~ . . ~~~ 6- r,~ Jennifer Dietz .............. . ~,..,,, . ~ Alas'knOll & Gas C0n3; Commission Anchorage I~o....,.1,,..,.1 ..- ( ~,.o,.Io-..f .,,'.. · ~ · Standard Alaska Produclion Comp, 900 East Benson Boulevard P.O. ~, 196612 Anchorage, Alaska ~519-6612 {907) 564-51 I HOUSTON ARCO CHEVRON EXXON TEXACO TO: MO B IL REFERENCE: PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION Date: 08/23/88 TI: 79236 The following material is being submitted herewith. Please acknowledge receipt by slgning a copy of this letter and returning it to this office: W-24 W-24 W-24 ,, Completion Record 08/17/88 #1 8880-9510 Sch 5" CBT 08/16/88 #1 8900-9538 Sch 5" CET 08/16/88 #1 8900-9554 Sch 5" Rece I ved Date A urn! of Ihe original Slondord O~1 Company Founded in Cleveland. O~;o. ,n 1870 Jennifer Dietz I NFORMAT 1 ON CONTROL Wel I Records LR2-1 SOHIO PETROLEUM COMPANY BOP EQUIPMENT TEST REPORT WELL __._W_.-~.4- ('44-/~..//- ,~ z._) ... TEST FLUID .... .~/~ ?~"K ACCUMULATOR VOLUME /~ TEST WPE: ~ WEEKLY ~ F~GE UP ~ cAaa~ ~T ~ST CASING;.... /3~_ "AT ~ BOP STACK-UST ALL ITEM~ TOP TO BOTTOM, ", '.. MANUFACTURER AND TYPE, SIZE OF RAMS, ETC, PREfigURE. & PERFORMANCE TESTS: ACCUMULATOR ACCUMULATOR ONLY & PUMPS TEST TEST .... UNIT PRESSURE TIME CLO~ING CLOSING RECHARGtE TIME TIME TIME ANNULAR S~o .~ ~5o0 ,,~ _. ' ............ _. BUND RAM .~ ~) - ,.~'~) ~) 0 ~ .......... ,~,~.RAM SOO-" 5.~ .q .. , P1PE RAM ,~O -- 5OO~ CHOKEMANIF- 500_- 5~&)O , ,~ TEST'~'-JIJPLUG, a_CUP. I'1PACI~ER~. KELLY COCI~ #1 ._~00 _~ t3/~ ._~'." CA~NG TESTE~. ~'~'~' F]:, TO 2~ PSI. ..... - Acc'U'I~UL~~EcH~GE __~<Z~30 P~-aEFORE TEST, KE~Y VALVE ~ ~ 00 ~ ~~ ~ ... ~ P~ AFaR CL~N~ A~ BOP'S, INSIDE ~P ' ~0~ -- 50~0 ~ .... ~MIN. REC~RGETIME ~/~ KELL~ HOSE 5~ O. ~~ ~ ~ D~ SEC -STAND PiPE ~e 0 ~ ~e ~ NITROGEN PRECHARGE: CHOKEUN~ ~0- ~0~ ~ 4 /~ KILLLINE " ~ ~ ~00 ~ -- g: ~10.~11, _~0 12. ~~,13. · -'QUIPMENT CHECKLIST '~i'EI~ NO cJRcuLA~:i"~.~ ON FLO0~ "' ,,,, " ~ ' ,,~ .. INSIDE BOP ON FLOOR & KELLY VAL~ES ON ~LOOR SPARE KELLY VAL~ '~ ~YSTEM OPEniNG "' ~ " .. , FLOW SEN~R OPE~TING , ~ . STROKE couNTER OPE~TING- ~ ..... ,, T~P TANK L~KING ~S ON ~ & A~ 'VALES OPE~TE ~LY. R~MOYE 8TA~ OPE~TI~ ~P HANOWHEE~ AVAt~E , ,,, , ii GAS SNIFFER OP~TING ,, BARITE ON HAND GEL ON HAND WATER ON HAND SURFACE MUD VOLUME HYDRAULIC OIL ON HAND NITROGEN BACKUP $Y$. EIOTTLE8 HOOKED UP, AT NITROGEN Pti E,~URE, MALFUNCTIONS & COMML"~I'I'8 (tter~ize a_tl leaka, malfunc~on& missing eqtdpment. ~,. and a~tion taken,) , TO BE COMPLETED AND PUT ON FILE FOR EACH BOP TEST. S~C l&O O/iq) June 30, !988 R H Reiley PBU Division Drilling Mgr Standard Alaska Production Company P O Box 196612 Anchorage, AK 99519-6612 Telecopy No. (907) 276-754.2 Re: Prudhoe Bay Unit W-24 Standard Alaska Production Company Permit # 88-70 Surf Loc 521'SNL, lI78'WEL, Sec 21, TllN, R12E, Btmhole Loc 4141'SNL, 962'WEL, Sec 16, TllN, R12E, UM Dear Mr Reiley: Enclosed is the approved application for peznnit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the .conductor pipe. Very tr~u!y yours, ~/ i.~ i ~ ~ l//~/ . W W Barnwell Commissioner Alaska Oil and Gas Conservation Commission BY O~ER OF THE CObRdlSSlON jo Enclosure C: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrillr311b. Type of well. Exploratoryl-] Stratigraphic Testl-] Development Oil[] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Comoanv 82 feet Prudhoe Bay Field/Prudhoe 3. Address - 6. Property Designation Bay Pool P. O. Box 1g~12. Anchoraoe. Alaska gg51g-6612 ADL 2R265 4. Location of well at sur~raCe 7. Unit or property Name 11. Type Bond(see ac ^AC as.oas) 521' SNL, 1178' WEL, SEC21, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 4281' SNL, 980' WEL, SEC 16, T11N, R12E W-24 (44-16-11-12) KOO683449-G-14 At total depth 9. Approximate spud date Amount 4141' SNL, 962' WEL, SEC 16, T11N, R12E July 2, 1988 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 28261 feet W-20 140 feet 2560 9629'MD 9153' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^AC 25.035 (e)(2)) Kickoff depth 6000 feet Maximum hole angle34.3 o Maximum surface 3330 pslg At total depth (TVD) ,'2 psl~l 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" Cond. 80' Surface 110' 110' 8 cu yds concrete 17-1/2" 13-3/8" 68# L-80 Butt 2650' Surface 2680' 2680' 3723 cu ft Permafrost 12-1/4" 9-5/8" 47# L-80 NSCC 4470' Surface 4500' 4500' 12-1/4" 9-5/8" 47# L-80 Butt 4591' 4500' 4500' 9091' 8710' 1860 cu ft Class G 8-1/2" 7" 26# IJ4S Butt 788' 8841' 8503' 9629' 9153' 252 cu fl Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVED Intermediate Production Liner JUN 2 IV,. Perforation depth: measured true vertical ~ 011 & Gas Cons. C0mmlssl~ 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilli~F~am [] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements l'-I 21. I hereby ~re~.~t~ and correct to the best of my knowledge Sig ned T i t I e PBU Drillina Enaineerin~ Supervisor Date (c, "' "-' - - ~, Commission Only - - - Use ' Permit Number IAPI number3 IApproval date ISee cover letter ~,-~'o 15O-oz9-~_1S:~_~106/30/88 Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg req0i(~:1301~'~s [] No Hydrogen sulfide measures [] Yes ~ No D~rectional su~rvey requ~recl ~ Yes [] No Other:Required workiT/~,~;~re~,~/~BOP.~E _[]2M; 1~3M~~I~l; F'll0M; I-I15M; by order of Approved by ~,//////////r ~ ~ ~ .._. Commissioner me comm,ssion Date6/~'d'/~']r Form 10-401 Rev. 12-1-85 Submit in triplicate PROPOSED DRILLING AND COMPLETION PROGRAM WELL W-24 [ 44-16-11-12 ] PBU Install and cement 80' of 20" conductor to surface. The drilling fluid program will consist of an 8.5-9.5 ppg spud mud in the 17-1/2" hole, a 9.0-9.7 ppg water base mud in the 12-1/4" hole and a 9.4 ppg water base mud in the 8-1/2" hole. Drill 17 1/2" hole to 2700' and cement 13 3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original resevoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9 5/8" 47# L-80 Butt/NSCC casing to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe. The second stage to be downsqueezed in the 13 3/8" x 9 5/8" annulus followed by nonfreezing fluid. Directionally drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to 9.6 ppg. NaC1 completion fluid. Test casing and lap to 3000 psi. Run 9 5/8" production packer on internal plastic coated tubing with a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 50' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Shut down rig operations for perforating subsequent to rig release. The well will be perforated in accordance with normal practices. Tubing Size: 3 1/2", 9.3#, L-80, A/B Mod, EUE 8RD, IPC with 8 GLM's Tailpipe Size: 3 1/2", 9.3#, L-80, EUE 8RD JLW:20-JUN-88 PROPOSED DOWNHOLE DIAGRAM WELL W-24 [44-16-11-12] PBU/EWE PROPOS ED DEPTH BKB 20" Conductor Ball Valve 110' 13-3/8" Casing Shoe 17-1/2" Open Hole 2680' 2700' 3-1/2" 9.3/t L-80 A/B Mod. EUE tubing with 8 GLM's 9-5/8" Packer 8791' 7" Tieback Assembly 8841' 9-5/8" Shoe 12-1/4" Open Hole 9091' 9096' 7" 26# L-80 IJ4S Liner 7" PBTD 7" Liner Shoe 8-1/2" Open Hole 95O9' 9629' 9629' G.O.P. STACK CONFIGURATION 13-5/6 IN. TRIPLE RAM STACK SO00 PSI WP DRILLING ANNULAR PREVENTER I PIPE RAMS ! BLIND RArlS :2 IN. KILL LINE CHECK GATE GATE DRILLING SPOOL ! ! PIPE RAPIS 4 IN. CHOKE LINE GATE GATE ,1 A WELL N* W' 24' · ~U R FACE LOCATION LAT. · ?0° 17' 56. 195" LONG. · 149° 05' ~,~. 172" ¥ · 5, 959, 7S5.94 A.S.P. X · 612 , 049.02~ ZONE 4 521' FROM N. LINE SECT. 1178' FROM E. LINE SECT. 2, 'A; "; 'J '" (MILES j L CERTIFICATE OF SURVEYOR: SURVEYOR DATE: WELL PAD'W' , i. '~'ELL N° W- 24 AS- IUILT LOCATED IN PROTRACTED IECT. ~1 , T. II N. , R. 12 E. , U.M. IURVEYED FOR : ~ ALASIGt~, I:~:~DLKETION ,".0 PREPARED. I¥ : KUUKPIK ' TECH'NICAL IERV. INC. PRUDHOE lAY OFFICE DATE , NOV, 15, 86 I~RAWN BY: I.T. CH KD. IY; R.H. W-$2 · W-~3t · · W-~ · w -&& 5'"4 · SUMP LiNE ~~ NE COR~.OF SECT. 21 I i w-24 · W.Z2 · W-21 · W-20 · W-t9 · W-18 · W-'t7 · W-t6 · W-t5 · W-14 · W-iS · W-I · W-2 · · W-.4 · · · W-7 · W-8 · · W-lO · W-II · W-12 1178' o SHEET 2 OF 2 1 MORT 14, WELL PAD'W' DATE , ~K)¥,Ie,,BE D~ILAW# DY: -- P'IIEPAREC~ BY : KUUKPIK - TECHNICAL ~ER¥. I1~. I~ UD~ OE DAY OFF ICE IU g V'[YED FOR : ~ ALASr, A P~~'hOr, CO WELL N° W-24 AS-BUILT LOCATED IN PROTRACTED ~CT. ti , T. II III. , R. I~ E. Search Radius= 3000 COURSE LINE For proposed well: W-24 [44-16-I1-12] Location ~ W-E S-N TVD(SBS) Top 612049.00 5929736.00 -82.00 Bottom 612230.57 5961315.17 8948.00 Note: Closest Approach Analysis --- Date: ~I-JUN-88 ,Time: 16:45:00 Al1 depths in Feet Belo~ ½ell~ Bushing (BKB) Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART CLOSEST DISTANCE A029-2052400 MP1511 9030.0 1589.6 9070.0 6729.5 628.3 A029-2103300 W-T 3107.3 0.0 3109.7 858.0 2819.9 A029-2177600 W-40 0.0 0.0 10.0 0.0 945. A029-~178400 W-39 0.0 0.0 8.8 0.0 911.9 W-35 .1291.2 0.0 1300.0 4. 5 776. ,AOa?-~lS0700 W-38 0.0 0.0 3.5 O. 0 878.4 A0~9-~180800 W-~O 0.0 0.0 0.0 0.0 140.0 Vertical Intersection /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART VERTICAL DISTANCE SUMMARY The well which comes closest to the proposed mell is: A029-2180800 W-20 Closest approach distance = KICR OFF For this run = 140.0 ~eet 5000.0 Feet ----Closest hppr~oach Analysis --- . Date: 21-,JUN-88 Ti'me: 16: 47: Sea~ch Radius= 3000 7 DEOREE LEAD 'LINE Fo~ p~oposed well' W-~4 [44-16-11-1~] Location = W-E S'N TVD(SBS) Top 61~047.00 5?5?736.00 -85.00 Bottom 613036.77 59613~5. 53 8948.00 Note: All depths in feet Below Kelly Bushing (BKB) Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART CLOSEST DISTANCE A0~9-~05~400 MP1511 9030.0 1589.6 9054.8 6711. 5 817.9 A0~9-2103300 W-T 3107.3 0.0 3107.7 858.0 2819.9 A0~9-2177600 W-40 0.0 0.0 10.0 O. 0 945. 5 A0~9-~!78400 W-3~ 0.0 0.0 8.8 O. 0 911. 9 A0~9-~177900 W-35 - 1291.2 0.0 1300.0 4.5 776.~ AOag-~180700 W-38 0.0 0.0 3.6 O. 0 878.4 A0~9-~180800 W-aO 0.'0 0.0 0o0 O. 0 140.0 Vertical Inte'~sectio. n /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART VERTICAL DISTANCE SUMMARY The well which comes closest to the p~oposed well is: A0~?-~180800 W-~O Closest approach distance KICK OFF fo~ this 140.0 feet 6000.0 feet NABORS RIG NO. 22E MUD/SOLIDS CONTROL EQUIPMENT 1 - Brandt Dual Tandem Shale Shaker 2 - Triflow 16" Cone Mud Cleaners 1 - Demco 416H w/16 cones & (1) Demco 48H w/16 cones (Desilter) 1 - Gasaway Vacuum Mud Degasser 2 - Pioneer 100 gpm Capacity Centrifuges 1 - Brandt CF-2 200 gpm Capacity Centrifuge 1 9- Brandt MA5 Mud Mix Agitators 1- Trip Tank 1- Recording drilling 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 1- Caviem Dewatering screen assembly C6NTRIFUG~ _PIONEER MK I MIX HOPPERS SUCTION TANK MtJD PUMPS 2- Emsco FB 1600 Triplex Pumps STANO P1PE GASAWAY DEGASSER MUD CLEANER ~2 TRIFLOW .... MUD CLEANER ~ 1 TRIFLOW TO PiT --~ KIJ. LINE WATER-VOLUMETANK FILL LINE VOLUME TANK SHAKER TANK FLOW IJNE TO FLARE NABORS DRILLING RTD RIG No. 22E MUD SYSTEM SURFACE FACILITIES TOTAL ACTIVE SYSTEM: 948 BBL TOTAL SURFACE CAPACITY : 1200 BBL CHECK LIST FOR NEW WELL PERMITS comPany~z~.~_~ , Lease & Well No. ITEM APPROVE DATE YES NO Fee ~,,~u~_ ~/~ 1. Is the permit fee attached .......................................... ~- -- (2 thru 8) (8) (3) Admit ~ 6/~3[~ 9. (9 thru 13) ' - 10. (10 and 13) 12. 13. (4) Casg ~~ ~-~-~ (14 thru 22) (5) BoPE (23 thru 28) 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is.a conservation order needed ...................................... _~ Is administrative approval needed ................................... _~_ Is the lease number appropriate ..................................... ~_ . Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. 21. Is old wellbore abandonment procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ............................ 23. Is a diverter system required ....................................... 24. Is the drilling fluid program schematic and list of equipment adequate/~ 25. Are necessary diagrams and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to ~~ psig .. 27. Does the choke manifold comply w/API RP-53 (May 84) .................. 28. Is the presence of H2S gas probable ............ ~ .................... o ~z (6) OTHER ~ d~/Z8/~ (29 thru 31)' (6) Add: For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .... 31 If an offshore loc., are survey results of seabed conditions 32. Additional requirements ............................................. Geology: Engineering WWB ~ LCS -/~BEW rev: 02/17/88 6.011 / : INITIAL GEO. UNIT iON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. VERIFI~IS TAPE VP OlO,H~2 VERIFICATION !~ISTING PAGE * R~EL HEADER ERViC:F NAME :EDIT A .~.'~., ~8/08/15 i'' :R~G~N ~FLYC EEL N'.~ NE ~728~6 REVIDI)8 )EDIT LiS,STANDARD PRUOHOE ~AY W * TAPE HEADER ** ATE :~/08/~.5 O~TINUATION # 'J O~ MKN~S {EDIT bIS,STANDARD PR[iDHOE BAY W ~4,API * FILF HEADER ** !bE NAME )EDIT .O01 E, RVIC ..... NAME :FLIC ER, SION # :O0]A02 ATE {~8/08/15 A×I~U~ LE~GT[{ {~024 ILE TYPE :bO REVIOUS FILE { , CO~£NTS ** *********************************************************************************** SCHLUMBERGER ALASKA COMPUTING CENTER *********************************************************************************** 'O~P~NY = STANDARD ALASKA PRODUCTION CO, ELL = W = 24 P! ~ = 50-029-21833 'IE[~D : PRUDHOE BAY iOUNTY : NORTH SLOPE BOROtIGH ~TATK = ALASKA VP OlO,H*02 VERIFICATION LISTING PAGE 2 YPE FLUID H LUID LOSS = 9 ~5" ~9148' ' BIT SIZE = 8,5" TO 9625'(DRILLERS DEPTH} = S RMF = , = ~C3 R~ AT B~T = , DF ATRIX SANDSTOM£ 1,}8£VEN RUBBE~ FINNED STANDOFFS AND 2' HObS FINDER 'CML MATRIX = SA~{D. HOLE CORRECTION = CALIPER. O/CC. F~UI~ DENSITY l.O ~/CC. BO~MPR~NO USED ON CN~. OR HIGHER THAN REPEAT PASS, ON BOTTOM DUE TO INDUCED RADiaTION EUTRON. THI~ IS CAUSED FROM TOOL STRING BEING S~OWED DOWN BEFORE ERCHiN~ TD TO LOG, I[,YC COMENTS: l,)~II,~ EDIT.O01 CONTAINS DATA OF DUmbSINDUCTION (.,Dfb) BOREHOI~E COMPENSATED SONIC (.BHC). LITHO'DEN~ IYY bOG (.bDT)'.~O~PENSATED NEUTRONiN CISINGbOG(.cSG)('CNb~PhEDiND GANM~ .5'RAY AND CO~PENSiTED NEUYRON bOGGED ,Y VP 010,~0~ VE~IFICATIO9 LISTING SCMLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: * , CASING TYPE :CONS MNEN TUNI VAbU DEFI CN STANDARD AbASK* Company Name ~P OIO,HO~ VERIFICATION LISTING PAGE 4 FN PRUDHOE BAY W~ W - 24  ATI 'USA TAT ALASKA COUN NORTH SLOPE SECT 21 TOWN lin RRNG lie LONG  P£R D, WARNER ON 548378 APIN FI,, 5)0"029"2I'8~3 i' FNL & 117. TYPE ~CURV Field Name well Name Nation State or Provl* Township Lon O. per Serv~ ie Num* ion, MNEM DEFI DEPT DEPTH CHANNEL * SFbU SFL unaveraged* ILD /b:-Deep Res[st* ILM lb-Medium Rest* SP Spontaneous Po* GR Gamma Ray T~NS Tensio~ DT Delta-T G:~ Gamma Ray T~NS Tension DRHO Delta tho RHOB BuI~ Density DPHI Pe.sity Poro~l* PEF Photo-Electric* LL LOng Lower Win* bt) Long Upper !'2, LS bon~ Spacin~ C* LITH I.,ltholog Windo, SSi ~hort Spacing , 882 snort Spacing , CAbI Calt~er 08S OUALITY CONTRO* OLS OUAL/TY CONTRO* bSHV Long Spacing H* SSHv Short Spactnq. 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T~ !T~ ~EDT ;p 'PHI '.NTC ~TF~. !TN R ~NTC ~EPT ~$ 'ALI ~t~TC ~TE~ 'T N R ~rJTC ~EPl ;p ~pN I '.ALI ~TF~ 2~ 21 352 172~ 20~ 2 3699 -999 -999 -999 5000 LIT~ 11.8 3438 OaS 0 0000 GE 23 !250 aT~N 957 5846 RCFT !46I 8169 ~R 23 1250 ~TEN 957 ~500 ~CFT ~999 ~500 TENS -999 ~500 0000 707C) 1875 01~6 0156 5000 073 ! 5000 2500 25OO 930 2 i ~0 172~ 199 2 4012 1,99 -999 -999 -999 0000 9375 7969 5992 0000 4766 o0oo 25oo ~904 0083 2500 2500 2500 2500 SFl, tl 26 GR 26 TENS 4548 PEF 2 LITH 97 OSS 0 G~ 28 HTEN 997 RCFT 1746 G~ 28 HTE~ 997 RCF! -999 TENS -999 ,0841 7969 0000 45!2 5625 0215 421.9 50O0 6467 4219 5000 ,2500 .~500 920 -7 3 1 27 172 19 384 t9 -~9 -~9 -99 0 CO00 4 1875 ~ 8281 3 !902 7 7500 8,4766 2.0000 5'3750 ~ 2626 ,6260 5,3750 0.2500 9,2500 q,~500 8~ LJ 1.8 6~ 31. TENS 4752 LITH 86 O~$ 0 GR 34 ~']~t~,) 1024 f~CFT 1780 CR 34 HI'Fh 1024 ~CFI: 3837 '8281 . .0000 .6855 0625 020O 0625 0 000 .9753 .0625 ,0000 ,2500 .2500 ]'36. 84. 23. !.02. 8 1723~ 18q, ?. 2193. !89, 0000 0313 75O0 !,676 4375 7734 nooo 1250 98q6 !982 1250 SFI.I.) PEF I~ I Th 2000.0000 184 7500 4584~000() 55 5313 -0,!279 197.5000 !015 0000 743~8635 197.500o 1015.0060 LL MOJI UPHI ~CNT D R H 0 Lb TEN6 TEN6 NFHI ~CNT HTE~ IbD OLS NPNI kCNT RCN~ 0,0069 1.88,2500 ~23.8750 -0,0054 485o;0ooo 23'~194 3653~9595 4880,0000 2999'2500 999,2500 -999'2500 17,4228 454~ ,~000 , 089 161,3750 219,2500 0,0278 4880,0000 22,2034 4240,4873 880,O000 ~999,2500 '999,2500 'g99,~500 13,5395 4752'00O0 0,0044 !.43,5000 713,7500 -0,0308 4912,0000 21,2115 3976.4492 4912.0000 -999.2500 -999,2500 -99g,2500 5,2479 4584,0000 -0.8440 45.~875 56.375 -0,0669 4924.0000 3!.3037 21.51,2632 4~24.0000~ 27.5(i;70 LS~V TNRA CFTC ~RE5 TNRA CFTC MRES DT LU 862 LSHV NRES TNRA CFTC TNRA CFTC MRES DT RHOB LU TNRA CFTC TNRA CFTC MRES f) T RHOB LU SS2 LSH } ~RES TNRA CFTC ~RES 'rNP ~ 2 2977 ]28 7500 ]34 7500 1762 0000 0 7622 2 t143 1.61~ 5837 7622 -999 2500 -999 2500 -999 2500 13 4131 813125 3926 277 2500 320 5000 1764 0000 0 ?646 2 2!81 1859 6228 0 7646 -999 2500 -999 ~500 -999 500 1~ 4614 8 3750 2 4324 268 2500 310 5000 1763 0000 0'7842 2,151.9 1858,~637 842 :99~:2500 .999,2500 999.2500 200o.0000 b7,12~0 2.~67 114 5000 9] 1250 1764 0000 0 8301 2 8484 789 2214 0 8301 2,91!5 VP 010,H02 VERIFICATI©H LTSTING PAGE 10 NTC T~ P AL I TNR N?C ~PHI 'ALI T~h :NTC 'PHI :AL I ;SHV ~TNR '.NTC .NTC ~T~N 3,1294 RCFT 2105'4585 TEN& 18:6 * 1250 9000 0000 SFLU 5938 GR TENS 99 250 .EF ~ '0 ~5 0 51TH ,5O OSS -9 '0 '9' GR "999: HTKN 2 RCFT 1860 1467 TE~$ 185 7500 :999 9991 -999 '999 "999 -999 "999 -999 -999 -999 4 1524 8800 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 4 1548 0000 SFLU :2500 G~ ,2500 T~NS .2500 PgF ,2500 LiT~ ~500 ~500 ~500 ~500 RCFX ~500 ~R ~500 H~EN 0638 RCFT 7i19 TENS 2500 0000 SFLU 2500 GR 2500 TENS 2500 PEF 2500 LITH 2500 OSS 2500 GR 2500 HT~N 2500 RCFT 2500 GR 2500 HTEN 27~7 RCFT 5920 TENS ~500 668. 1589 RCNT 4652,0000 HTEN 2000.0000 3~.7813 TENS 4580,0000 :99g- 5oo i999'250i0 -999.2500 T:EN~ NPHI -999;~§00 RCNT '999,2500 -999"~500 62~,6553 RCNT 4632,0000 -ggg 2500 ',,999 ~500 '999 2500 DRHO '"9 2500 '999 2500 '999 .~500 TENS '999~2500 NPHt '99912500 RCNT '999~2500 TENS '999.2~500 NPHI 390'6938 RCNT 464410000 ~TEN '999 '999 '999 '999 '999 '999 '999 '999 '999 '999 '999 4564 250O I~D 2500 TENS 2500 DR{tO 2500 O0 SS1 25OO 2500 u~UI 2500 RCNT 2500 TENS 2500 NPHI !082 RCNT 0000 HTEN )EPT ;P ;R )PHI 8.700,0000 ~999.2500 999.~500 -999'2500 -999,2500 SFLU GR TENS PEF LITH -999 2500 ILO -999 2500 TENS -999 2500 DRHO -999 2500 LL -999 2500 SSi 92 . MRE$ 4,8169 4580,0000 DT -9:9:9,2500 -999,~500 LU -999,2500 -999,2500 -999,2500 -999,2500 TNRA :999,2500 CFTC · 999,2500 MRES 23,7643 TNRA 1906,~656 CFTC 916i0000 MRES -999 -999 -999 -999 -999 -999 -999 -999 46 2500 500 OB 500 bU 500 ,2500 bSHV 2500 ~RE$ 2500 TNRA msoo C~TC 2500 ~RE8 3897 TNPA c ,c MRE8 999,2500 IbM 999,2500 DT -999,2500 RMOB '999,2500 LU '999,2500 -99 2500 TNRA c ,c -99 2500 4i!7837 TNRA ~56 558~ CFTC 94 5000 -ggg 2500 IbM -999 2500 DT -999 2500 RHOB -999 2500 bO -999 2500 72~,0:237 .8320 20¸ -999 2500 -999 1500 -997 !500 99 -999 O0 ~999 2500 .999 2500 -999 !500 ~473 '999,2500 '999.2500 '999,2500 '99~,2500 '99~,2500 '999.2500 2999;2500 999. o -999 0 -999 2500 4 0~86 38O 3740 0 8687 -999 2500 -999 2500 -999 2500 .999 2500 -999 2500 VP OlO,~Y)2 VE[~IF!CATIt~N LIST!r~G P~GE -999, -999. so -999' ~ . RCF -999,2500 ~ T N.C ~999,2500 .... C~T N!C ]516,!~63 TENS TEM ~76~7500 -999 2500 OhS -999 2500 TEN5 -999 2500 ~P~! -999 2500 RCNT -999 2500 TENS -999 2500 ~PHI 339 948~ RCNT 4520 000 ~TEN 8600 0000 -999 ~999 -999 ~999 -999 ~999 -999 -999 -~99 -999 5 SFLU 2500 2500 TENS ~500 PEF 2500 2500 2500 Ga 2500 HTEN 2500 RCFT 2500 2500 5227 RCFI 9041 TENS 0000 -999 2500 IbO -999 2500 TENS -999 -999 ~999 -999 -999 -999 -999 -999 -999 2500 2500 250O 2500 2500 TENS 2500 gPHI 2500 RCNT 2500 TEN& 2500 NPHI 426 4491 RCNT 4480 0000 HTEN EFT !P"I 'ALI :T N R 7N'rC 00 00 S F L U 8500, . '"9~9 2500 Ga -g.9:2500 TENS -999 2500 PEF -999 -999 -999 -999 -999 -999 -999 4 1736 ~74 2500 LITH 2500 O$S 2500 ca 2500 HTEN 2500 PCFT 2500 GR 2500 H/F~ 1600 RCFT 42~5 TENS 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -999 2500 -gE9 ~500 -999 2500 -999 5~ ~4~4 DRHO LL Og$ TEN8 ~PHI RCNT TENS 2500 ~PHI 9501, RCNT 0000 HT'E~ )EPT ~p ;R ,$ iTFg ~TNR 'NTC ~NTC 8400 0000 SFI,U '999.2500 GR 'q9g. .2500 2500 -~99 :999 ~500 999:2500 -999.2500 -999,~500 -999 2500 -999i2500 -999 ~500 3.2917 1~71,5657 !73,3750 PEF t, GR R C F 1> RCF? -999.2500 It, D  999,~500 TENS 999 2500 DRHO 999~2500 LL 999 2500 SSI. 299 1 soo -999.2500 -999 2500 -999 500 Ts. 608 O840 4408.0000 -999.2500 [,SHV :999,250.0 -99~.2500 ~RE$ 999~2500 -999,2500 TNRA 999,~500 -999,~500 CFTC 1999;2500 -999,2500 NRES -999'~500 50,~981 TNRA 4,16!7 1562,t338 CFTC 373'I$83 954,0000 MRE:S 0~8784 -999,~500 -999,2500 DT 882 [,,SHV' -999,2'500 -999. 500 CFTC -999, 500 46.4749 TNRA 1668,223t CFTC 953'5000 :999,2500 999,2500 -999.2500 ~HOB - 9 . 5oo 2soo .,99:25oo -999.2500 TNRA -g99,2500 CFTC -999,2500 37,8775 TNRA 1770.35~1 CFTC 954.6250 -999.2500 -099.2500 DT '999.2500 '999.2500 hO '999.2500 S$2 '999.2500 '999.2500 MRE~ -99q.2500 TNRA -999,2500 CFTC -999,2500 28,6089 TNRA 1939.1438 CFTC ~60.5000 ~RE8 -999,2500 -999,2500 ,;9 2500 -9992500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 ~ 9520 433 7504 0,8887 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 -999 2500 -999 2500 -999 2500 ] 4804 508 7603 0 8916 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -999 2500 -999 2500 2 9720 624 7665 0,8965 .VP 010,HI)2 VERIFICATION LISTI~IG PAGE 12 'PHI ,S~'V N~ C NTC ~EPT iSHV :NTC ~NTC tEPT ;P ;R )PHI ~ALI ;SHV tTNR ~TN~ ~TC )EPT ;p ;R )PHI ;5HV ~Tg~ .8300,0000 SFLU GR. "999; 2500 '999.2500 TENS "999 PEF '-999 GITH =500 GR " HTE~ "9' 0 RCFT I~CFT 0000 SF~U 2500 GR 2500 TENS 2500 PEF  ITH HTEN -999,~500 ReFT '999,"2500 GR -999;2500 MTEN 130610024 TENS i69,!250 8100 0000 SFLU -999 -999 -999. -999 999 999 -999, ~999 ~999 -999 1601 167 2500 OR 2500 TENS 2500 OSS 2500 GR ]{00 HTEN O0 RCFT 2500 GR 2500 HTEN 9107 RCFT 5757 TENS 2500 8000,0000 SFLU -999.2500 GR -999,~500 TEN5 -999.2500 PEF -999,2500 LITH -999.2500 OS$ 999 2500 ~R q99:2500 HTEN '999,2500 ILO -99g,2500 TENS -999,2500 DRHO '999'2500 I,L -999.2500 '999;2500 ODS -999-2500 TENS '999~2500 NPHI '99922500 RCNT :999;2500 '~N 999,2500 314~9993 RCNT 4364~0000 HTEN :999.2500 ILD ,999,~500 TENS :999.2500 DRHO 999,~500 LL :999~2500 999'2500 -999.2500 TENS '999,2500 NPHl , o.ooAg HTEN -999 ~500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 455 4268 ILD ]500 TENS 500 DRHO 2500 L~ 2500 SSi 2500 OLS 2500 TENS ~00 NPHI O0 RCNT 2500 TENS 2500 NPHI 5922 R~NT 0000 HTEN -999 2500 -999:2500 TENS -999 2500 DEMO -999 2500 -999 2500 -999 2500 OLS -999 2500 TENS -999 2500 NPHI -999.2500 XL~ -999.2500 ~lO:B -999.[2500 '999,~500 LU -999,2500 8S2 "999,2500 '999.2500 TNRA -9 CFTC ~99 4 · 0000 -999 -999 -999~ -999 -999 -999 966 5000 DT 2500 RHOB 2500 LU ~500 SS2 2500 LSHV 2500 N. RES 2500 TNRA 2500 CFTC 2500 MRES 1!39 TNRA 86i6 CFTC MRES -999 -999 -999 -999 ~999 -999 -999 2500 IbM 2500 DT 2500 RHOB 500 LSHV 500 MRES }500 TNRA 2500 CFTC ,5527 TNRA 9.~839 CFTC 1~4. 000 MRES -999.2500 lb~ -999.2500 DT -999+2500 RHOB :999. 500 LU 00 SS2 -999'~00 LSHV 999.2 -999.~500 MRES -999. 500 TNRA -999 -g99 -99~ -9:99 -999 }0 ,00 ,00 O0 -99~ 4259 28 8401 0~9233 -999 2500 -999 2500 -999 2500 -999 -999 -999 2500 -999 2500 -99~ 2500 51~4 468 6049 0 9~41 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 TI~R '999 NTC -999 T F, ~ 165 ~5o0 RCFT 2500 GR 1528 RCFT 0444 TENS 8750 EPT 7900 P ~999 R -999 P~l -999 $ -999 -999 -999 'NR -999~ TC -999: TEN -999 TNB 3 :~TC 1597 TEN 1.64 0000 SFLU 2500 Ga 2500 TENS 2500 PEF ~500 LITH 2500 OSS 2500 G~ ~500 HTEN 2500 ~CFT ~500 GR ~500 HTEN 6038 RCFT 9480 TEN~ !250 'EPT 7800 P -999 ;a -999 'P~l -999 :$ -999 'ALI -999 ~SRV -999 TEN -999 TNR -999 NTC -999 T~N -999 T~'~{~ 4 161 ~0000 SFLU 2500 2500 TENS 2500 ~500 2500 2500 HTEN 2500 RCFT 2500 GR 2500 HT~N 7059 ~CFT 2217 TENS 8750 'EPT 7700 .P -999 'R -999 :PHI -999 S -999 'ALI -999 S~V -999 'rEM -999 T~ -099 ~NTC -999 'rK~ -999 T~R 4 'NTC 1370 oO00 SFI,J 2500 PEF 2500 OSS ~500 GR .2500 .2500 ~C~i' 2500 .0244 RCFT .7649 TENS ,2500 ~EPT :600,0000 SFLU .P 999,25n0 dR -999 250o -Egg 2500 -999 2500 613 9061 4t 60 0000 -999.2500 -999.2500 '999.2500 -999'2500 -999.2500 '999,~500 -99912500 '999'~500 -999.2500 -999'2500 -999,~500 480i5573 41.12'0000 -999 2500 -999 2500 -999 2500 -990 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -999 2500 -999 262 70]2 4080,0000 -999 P500 -Egg 2500 -099 2500 -999 2500 -999 ~500 -999 ~500 -090 2500 -999 2500 -9991250(1t -999 2500 -999 2500 3~0.9450 4014.0000 -o99 2500 -999~P500 TENS NPHI ~CNT ~TEN TENS Lb TENS NPHI RCNT TEN6 NPHI ~CNT ~{TEN OhS NPHI RCNT TEN~ NPHi ~CNT ILD TENS LL $61 TENS NPHI TEN6 NPHI RCNT :999.2500 CFTC 999,2500 27,79! 2005,1241 CFTC 979.8750 '999.2500 ILM -999,~500 DT -999'2500 RHOB -999,2500 LU '999,~500 bSHV '999°~500 MRE$ '999'~500 TNRA -999'2500 CFTC 6~3672 TNRA 1~12'3230 CFTC .oooo -999,2500 IbM -999,2500 DT -999,2500 RHOB '999'2500 LU -999,~500 852 '999.2500 LSHV "999,~500 MRES -999,~500 TNRA '999,2500 CFTC '999.~500 ~R~S 55,7534 TNRA 1326.~974 CFTC 974'0000 MRES '999.2500 Ib~ '999 2500 DT '999:2500 RHOB '999,~500 bU '99g,~500 S62 '999.~500 LSHV -999.~500 RRES -999,~500 TNRA -999.~500 CFTC -999.2500 ~RES 48.6947 TNRA 140~.30~8 CFTC g79.5000 ~R~5 -999.2500 IL~ -990.2500 DT -999,2500 .999~2500 655 ' I 5:67 049424 -999 2500 -999 '500 -999 }0 -9! !500 -9 2500 '999 2500 -999 ~500 '9992500 '999 2500 "999.:~500 3.3975 .3:790 ,9526 -999 2500 ,Egg 2500 .199 ~500 -999 2500 -999 2500 -9~9 50O -999 {500 -999 2500 -999 2500 4 4610 303 9543 0 9658 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 0735 349,7976 0,9785 :~90,2500 .99,2500 R $ ALI NTC T~R -99q,2500 -999,2500 -999,2500 -999,2500 -999 t. 50t PEF L I T H 5714 RCFT 8750 -999 2500 '999 '999 -999 '999 '999 '999 '999 38O 250O 2500 2500 ObS 2500 25O0 500 RCNT 500 TENS 2500 7682 RCNT 3964 0000 MTEN EPT R $ A t:,. I SHY ~TC TNR 7500 o0o0 SFLU -.9919 ~999 -999 -999 -999 -999 -999 -999 4 1.424 2500 TENS 2500 PEF 25o0 OSS 250o GR 2500 ~TEN 2500 RCFT 2500 Ga 2500 HTFN 6~50 -999.2bn0 -999'2500 -999.2500 -999 -999 -999 -999 -999 -999 -999 -999 DR~O ~500 Lb 2500 881 2500 OhS 2500 TENS 2500 NPHI 2500 RCNT 2500 TENS 2500 9109 RCNT 0000 HTEN P P~I :$ SHV TMR '~*tC 7400 0000 -Egg 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -~99 2500 -999 2500 -999,2500 -99~,~500 .7273 1318,5762 156.0000 S F b tJ TENS PEF I, ITH H T ~:~ N RCFT TE~.~$ -999 2500 -999 2500 TENS -999 2500 -999 2500 Lb -999 2500 -999 2500 OLS -999 2500 TENS -~99 2500 -99~ 2500 RCNT -999~2500 TENS -999.9500 NPHI 781,169A RCNT ~t844.00~0 ? :R 'P~I 'TNb~ 7300,0000 .-.999.25oo 999.25oo ;999 2500 ,~99:25oo 999 -qgg:~bO0 -999.~500 :999,2500 99~,2500 -999.2500 ILD -999.2500 TEN6 :~99!~500 99 2500 LL -999 2500 -999.2500 -999.2500 -qgg 2500 -099:2500 -999 2500 -999125~0 -999.2500 -999'2500 bU '999,2500 852 '999,2500 t~SHV .~9~.25oo :999'2500 T~RA .999.~5oo CS'TC 999.2500 MRES 40,4200 T~RA 1596'891! CFTC 979'5000 ~RES -999,2500 Ib~. ~999 ~ 2500 DT -999 ~. 2500 25 00 t,U -999~2500 LS~V -999.~ 2500 ~RES ! 999,~500 TaRA .FTC 999'2500 C 999'2500 47 ~ 7185 NRA 145~9814 CFTC 960,0000 MRE8 -999,2500 -099 2500 , DT '999'~500 RHOB '999,2500 LU '999,2500 852 -~99,~500 LSHV -999,2500 -999.~500 55,7865 TaRA 133~.9570 CFTC 9~1.0000 ~RES -g99,2500 Ib~ -999,2500 DT -999,2500 RHOb -999.2500 LU '999,2500 S52 '999,2500 '999,2500 "RES '999,2500 TaRA 'g9~,2500 CFTC 'q99.2500 ~RES 52.1466 TNPA -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4t~ 6199 ~342 09863 '999,2500 -999;2500 1999'2500 ~999'2500 '999~500 2999;2500 1999~500 1999'2500 .999;~500 .999~2500 4'0202 366~5644 0;9941 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 462~ 298 0905 t O049 -egg 2500 -999 2500 -999 2500 -999 2500 .999 2500 -999 2500 -999 2500 -999 ~500 -999 ~500 -999,2500 4.2631 VP O!0,HO2 VERIFICATION LISTING T~!R 4,5429 RCFT !NTC !354,4558 T~;NS ~EPT ~PHI ~N?C -NYC 7!00 0000 "999 2:500 -999 2500 "999 ~500 -999 2500 -999 2500 -999 2500 ~9992500 -999 2500 -999 ~500 -999 2500 5 2069 ~304 6799 151 2500 TENS PEF bITS GR HT~N Reft ~R HTEM RCFT TENS )EPT ;p :R )PHi ;SI-IV ~TF, M ~NTC ~TEM TC ~TEM 700O 0000 -999'2500 999,2500 999,2500 999,~500 -999,~500 -999 2500 -999 ~500 -999 ~500 -999 2500 -999 ~500 4 6061 1~55 9434 ~49 8750 SFLU ~R TENS PEF GR HTEN RCFT GR HTEN RCFT TENS )EPT ,R 6900 0000 =999 2500 -999 2500 -999 2500 -999 ~5o0 SFl,U TENS PEF LIT~  98.9924 3 I0.0000 -999,~500 -999,2500 -999~2500 -999 2500 -999 ~500 -999 2500 ~999,2500 999,2500 -999'~500 -999,2500 -999,2500 286,5001 3760.0000 -99~ 2500 '99~ 2500 -99~ 2500 ~999 -999 ~500 5OO -999 2500 -999 2500 -999 ~00 oo -999 -999 2'500 -999 2500 306 ~0 3710 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -999 2500 -999 2500 -999 2500 -999 2500 332 3198 3650,0000 TENS D~HO TENS RCNT NPHI .CNT HTEN TENS DRHO TEN~ NPHI ~CNT TgN8 NPHI RCNT HTEN TENS DRHO 881 TENS NPHI RCNT TENS NPNI RCNT NTEN 99i500ILD i 99 2500 TENS -999 25t%0 DR}{O -99 2500 -qg : soo 139! .4539 960.5000 C OT RHOB $$2 bSHV TNRA CFTC MREM TNRA CFTC -999,2500 Ib~ ~999,2500 DT ~999~2500 RHOB ,999;2500 LU 999'~500 SS~ '999,2500 [,$HV -99q'2500 MRES -999,2500 TNRA -999,2500 CFTC -999,2500 MRES 54,4759 TNRA 1297,9724 CFTC 948,0000 ~RES -999 2500 IL~ -99912500 D~ -999.2500 RHOB ~99i2500 [,0 99 2500 862 999 2500 L$~V '999,~500 ~RE$ '999, 500 TNRA -999,~500 CFTC -999,2500 MRE$ 48,6467 TNRA 1393,8293 CFTC 965,5000 PRES '999.2500 IbM '999,2500 DT '999,2500 RHOB '999,2500 LU 'qgg.~500 S52 016.6 '99 "'~ 0 '997 -999 0 ~ O0 -999 "999 -~ 0 3 66 -999.2500 -999'2500 ~999~2500 ~999~2500 999~2500 '999~2500 "999'2500 -999'2500 :999'2500 999,2500 4'3909 312.2!36 i~0381 -999, 2500 :999, 2500 999:500 -999 500 =999 2500 =999 2500 "999 .,,, o0 -999 2~00 -999 2500 4 4gO! 0 ! 336 0 1 0498 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 .,¥P OlO,H02 VERiFiCATION L! .... rING }S~4V -999 TEM -999 ~:T~I R -999 T ' "'999 NTC 13O6 ~TKM ! 47 >EPT 6,58 ;P -999 ;R ,.999 )PF;I -999 .[~I ,-999 ;S~V -999 ITEM -999 ~T~ ~NTC ggg ~T~M -999 ~TK~ 147 -999 2500 2500 2500 2500 RCFT ~500 2500 gTFM 5429 9045 TENS 8750 :0000 :FLU 25OO 2500 TENS ~500 PEK O0 LITH ~oo oss ~500 GR 2500 500 RCFT 500 ~500 6000 RCFT 9578 TEN~ 7500 -999 ~500 ODS -999 2500 T~N6 -999 2500 NPH! -999 2500 RCNT -999 2500 TENS -999 2500 NPH! 240 7206 RCNT 3594 0000 HTEN -999 2500 ILD -999 2500 TENS -999 2500 DRHO -999 2500 LL -999 2500 SS! -999 2500 TENS -999 ~500 NPH! -999 ~500 ~CNT -999 ~500 TENS -999 ~500 NPHI 294 818!~ ~CNT 3570 0000 HTEN '., N~,ME :EDIT ,001 ~E~VICF ~A~E ,'FLIC ~E~SIO~} { :O01A02 )ATE ~AXI"{..}~ LENGTH :1024 'ILE TYPE 'EXT FILE NAME '999.2500 'L$~V -099,2500 ~RE$ -999~2500 TNRA -999~500 CFTC -999*~500 MRES 54;7052 TNR~ 1339'7039 CFTC 948.5938 MRES DT RHOB LU '999,2500 882 -999,2500 LSHV -999~2500 -999;~500 TNRA -999'~500 CFTC -999;~500 MRES 13~.6501 T~RA ;524~ CFTC -999~2500 PAGE lb -999,2500 -999.2500 .-9'99,~500 :99'9,2500 999,~500 4'.4015 294~838~ 1'0605 - g 99; 25 0 o .999'2500 4; ~ 9:o 7 ]06~7665 1~0664 ~* T~PF TR~ILE~ ** ;E~VTCF NAME :EDIT >ATE :~8/08/15 CAPE N~ME :72886 ~ONTTN{!ATION # :1 ~EXT ~PE NAME : ~(:]~KN~S :EDIT L.IS,STAUDARD PRtJOHOK !%AY W - 24,API 50-029-21833 ~, RK£I~ TRtlLE~ :E~VICE NAME :ATE :88/08/15 ]RIGTN :FL!C ~EFL N~E :72886 ]ONTIN!~ATIqN ~ : ,~EXT RFE!, NA~E VP OlO,HO2 VERIFICA?IO~ I.~ISTING PAG~ 17 RECEIVED $5P ~ ~ 1988 Alaska Oil & ~as Cons. Commission Anchorage Ci;~tPANY NA~E .'. STA~!Dt~R~) ALASKA WELb ~AMK : w - 24 F:[EI,.~D NA~'; : P.RUDH(/E BAY R{.)RUUGH APl REFERE~CE K~U : 72886 PRODUCTION CO, a~,e Yerificatien L[Stin~ ~a,s. Ka Computinq Center 25-t~uG-19B~ 05:02 PAGE~ ~ 88/08125 ~ ~blC CONTINU~TIO~ ~ P~EvIOUS TAPE COMMENT : EDIT LIS,STAnDARD PRUDHUE BAY ~ -- ~4,API 50-029--~18]3 FILE NA~E : ~QIT .001 8EMvtcE V~RSION : 00iA02 M~× ~EC SIZ~ I 1024 FILF TYPE L~ST FIbE ** DATA FOi~MAT SPEC!I;'TCATIuM P, ECORD ** SET TYPE - 64EB ** TYPE R CUDE lIE 2 66 0 3 73 ~16 4 66 ~ 6~ 0~5 9 65 11 66 4 13 66 0 14 65 PT 15 6~ 6~ I6 6~ 1 0 66 0 ma,~e Verification !,istJno t~mberger AlasKa Computino Center 25-~iJC-19~ 05:{,)2 w~E $~¥ U~,~iT SEPVTCE APl ~pI ~Pl APl FIL~ NU~ N~ ~IZ~ REPR PROCESS DFPT "~T ~'., i I 1 4 6 0000000:0:00 SPbU Dll., [:~'{~ ~ 1 I i 4 68 0000000000 uS/F ~H~ LDT G!C3 DPHI LOT P ~: F L D T LL' LD~ CPS LU LD~ CPS LI T~'~ I~T CPS SS1 bDT CPS 8S2 I~DT CPS OSS eLS bDT LSHV LDT V ~HV I.~D~ V  I,,[~m GAPT ENS LDT LB ~TE~ LDT DEGF HTE',a, LDT LR NPH] CNL TN~, CNL R~N~ CNI, ~CFT CNI, CPS RCNT CNb CPS C~TC CNb C CNTC CNh CPS G~ CN[, TENS CNI, LB ~TE~ CNI, DEGF NPNT C$~ pTI TNR~ CS~ RCF~' CSG CPS ~'F ~S CSG I i 4 1 I 4 68 ! i 4 69 '.! 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TNRA O0 OIL -999 ~50 -999 50 -999 250 -999 250 -999 0 -999 ~50 -999 50 -999 ~0 -999 ~ 0 55,786 1331,957 961,000 Ih) iL RHOB ~DT Ltl DT 882 LDT LSHV BDT MRES bDT TMRA CNL CFTC CN MRE$ CN~ TNRA,CSG CFTC,CSG MRE$,CSG -999 -999 -999 -999 -999 -999 -999 -999 -999 250 250 250 250 250 250 250 250 250 IBM.OIL DT'B~C RHOB,LDT bU BDT S$2 LOT BSMV bDT MRES bDT TN~A CNL CFTC CNL '999 -999 -9' '991 '999 -999 '999 -999 ~98 -999 -999 -999 '999 '999 ~$O 2'30 ,2 S0 :250 0 250 ,LS Tane Verification Y,jstino ;c~lOmb~r~er AlasKa....o ptitin~ Center CNTC CNTC CNL -999,250 1. 354 , 456 1.54. ~75 DIL B HC bDT LOT bDT cNL 7200,. -999,25<. -999 250 -9.99 250 -999 250 -999 -999 250 -999 250 4 129~,364 I52,750 D I L BHC LDT LOT L [) T LDT bDT CNL, 7100 -999 -999 -999 -999 -999 -999 -999 -999 -9o9 -9 9 5 1.104 151 000 250 25O 25O 25O 25O 25U ~ 2 5 o ,25~ ,250 ,207 .680 .250 SFLU.DIb '~P OIL DEF. {~DT LITH. bDT QSS. LtJ'r HTEN bDT RCFT ] CF, L GR. Cn L HTEN. TENS. CSt ~HC bDT LOT L b T ,.LOT .bDT CML CNL CNI. CSG ,CSG 7000 -999 -9q9 -999 -999 -999 -99~ ~9 -999 -999 4 1355 1,49 .UO0 ,250 25O ·'250 .250 .250 .250 .250 ,250 ,25U ,606 ,943 DFPT GR t) P H I , . O 1 L .BHC , L D T 6900 -999 -999 · 0 O 0 · 25o · 25u .250 5FhU. DIb GR. OIt, 25-AU(;-19S8 05:02 PAGE; -99 -9 29 3~10 52 -999 -999 -999 -999 286, 3760, 49 -99~ -999 '999 '999 37i0 52 -999 -909 -999 -999 -999 -999 -909 -999 -999 -999 -999 332 3u50 44 -999, -999, -999, -999, 250 TEN$,C~L 000 HT:.:N.Co,~ 594 -999.250 ~RES 4 CFTC 500 ~:R ES CNb -999 CSG 1,: 250 ILO,OiL 250 OR. HO ' . b O'r 250 b L, b O T -999 250 SSlLOT -909 25,~ , LOT '99:9: 250 IENS,LOT -999 250 [:~CNT, CN !,~ 250 NPMI,CSG 000 HTEB2 75{~ -999 250 250 5 CFTC 5 MRES -999 bDT -9 -9 1 SSI,bDT OLS,LOT 250 TENS,bDT '999, 250 ~PHI,C~L -9991 '5' CSG 54 2~0 NPHI, 685 RCNT.CSG ~297 000 M~EN CSG 948 969 ~o 25o 25o  76 TN:RA 72 CFTC 000 MRES LDT LDT IDT LDT CNL CNL CNL '9 -9 1, 25U lbD,DII, 250 TENS.OiL 250 DDHO.LDT 250 bL,LDT 250 SSl.bOT 50 ODS,bDT ~50 TENS.LOT 250 NPNI,CNb 250 RC{'~T.CNL 250 TENS,CNL 250 NPHI,CSG 320 RCNT.CSG 00~ HTEN.CSG ~999 250 999 50 -999 ~50 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 48 647 139~ 829 965 500 ILN DID PT BHC RHOF LOT LU bDT SS2 [,DT LSHV bDT MRES bDT TNRA CNL CFTC CNL MRES,CNL CFTC,CSG ~RES.CSG -999 250 "99:11 -999 336 480 ! O5O 250 ILD.DIb 250 T~NS,DiL 25U DRI40, I,DT 250 I.,I,, LDT -999,250 -999,250 -909 50 IL~,D1L DT'BHC HNOB,LDT I,U,PDT '999,250 '999'250 "999,250 -999,250 10 ,IS, Tame YerlflcatJon ;~hl~mbe,mfler AlasKa ComPutln~i Center C~L! LDT SSNV LDT PTEP RTN~ CSC CNTC -999.25C -999.250 -90 25O 250 -90 250 -Egg 250 -999 2.. 0 ~ 5~.3 1306. 147. D SP DPH~ RTNP C DIb -909 BH:C -gE9 [.,i)T -999 LDT -999 LDT -9~9,250 LDT -99~ ', 250 ,L'DT -9~9,250 CNb '9q9,25( C6C 4,600 C S G 1 345,958 CSG 147,750 ** END OF DATA 25-~tiG-I 988 05:o2 -909,2~6 -999 -999 -999 250 SS2, LDT 5 0 T:NRA 50 CFTC 9 9,: s0 s ,7o5 13:39~704 ~48~594 ~RES -999 -999 Z99~ 99 -999 -999 ~:50 250 250 Lb; bDT 2~0 OhS,bDT TEN$,LDT NPHI~CNL ~:CNT,CN~ NP~I'CSG ~C~T,CSG 00~ UTEN,CSG 938 2~,0 I~ TENS'DiL 999 250 DT -999 5:0 -999 ~50 -99:9: 25:0 -999 250 PAGEI 11 -999 250 066 **** FILE TRA !~,ER **** FTLF NAME : EDIT .00] SERVICE : F6IC VFRSIOb} ! O0 ].A02 D~TF : ~8108/25 FILF T~PE : LO LaST FILE : **** TAPE TRAIbER **** SERVICE NAiF : EDIT DATF : 88/08/25 ORICIN : FL!C TAPE NAME ~ 72886 CONT~NU~'.CT[]fJ ~ % t. PREVIOUS T4~E : COMMENT { EDIT LI~,ST4~O~R9 PR[}D~OE B~Y ~ - 24,API 50-029-21833 t],S. ~aee Yerl~icatfon [~istlnq ~CblUmber~er AlasKa Com[:t)ttnt! Center 25-AUG-1988 05:0'2 PAG~ 12 D.aTF : B8/08/25 ORIGIN : FLI'C R~E[. NAN~ : 72~86 CONTINUATION ~ : C~[]NT : ~DIT L!S,STAN[~)ARD PRUDNOE FAY W' 24,API 50-029~2183~3