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204-159
9640, 13251, 13259 By Grace Christianson at 8:55 am, Dec 19, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.12.18 15:11:44 - 09'00' Sean McLaughlin (4311) 325-770 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. Open hole window milling not to exceed 15'. DSR-12/19/25JJL 1/15/26 TS 12/22/25 10-407 01/15/26 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: December 18, 2025 Re:15-26B Sundry Request Sundry approval is requested to set a whipstock in the 15-26B wellbore as part of the drilling and completion of the proposed 15-26C CTD lateral. Proposed plan: See 15-26B Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN-nipple. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in and test BOPE. The rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in Zone 1. The lateral will continue in Zone 1 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in January 7th, 2026) 1. Coil : Dummy WS drift, Mill XN 2. Valve Shop : Pre-CTD Tree Work 3. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in January 30th,2026) Reference 15-26C Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,438 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set 4-1/2" packer whipstock TOWS=10,360' MD at 210 RHOS. 3. Mill 3.80 Single String 4-1/2" Window 4. Drill production lateral: 4.25" OH, ~2672' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2 x 3-1/4 x 2-7/8 13Cr solid liner 6. Pump primary cement job*: 46 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). 7. Only if not able to do with service coil extended perf post rig Perforate Liner with 1" or 1-1/4" CS Hydril 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Alternate plug placement variance request per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Post rig 500'-1000' EAP - see extended perf procedure attached. 3. Slickline : Set LTP* (if necessary). Set live GLVs. 4. Testing : Portable test separator flowback. Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 Well Date Quick Test Sub to Otis - Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular CL Annular Bottom Annular CL Blind/Shears CL Coiled Tubing Pipe / Slips Kill Line Choke Line CL BHA Pipe / Slip CL Coiled Tubing Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR#-AC BOP Schematic CDR Rig's Drip Pan Fill Line Normally Disconnected HP hose to Micromotion LP hose open ended to Flowline (optional) Hydril 7 1/16" Annular Blind/Shear CT Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross CT Pipe/Slips BHA Pipe / Slips nneeeeeceeeeeeeeeeeeeeeeeeeeeeeeeeeee STATE OF ALASKA I Y ED ALASKA OIL AND GAS CONSERVATION COMMISSION I� ��EE REPORT OF SUNDRY WELL OPERATIONS R 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ ryry ^ Pull Tubing ❑ Oper'/. �,' std 4.2020 ❑ Suspend ❑ Perforate 21 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory ❑ 5. Permit to Drill Number: 204-159 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22235-02-00 7 Property Designation (Lease Number): ADL 0028306 8. Well Name and Number: PBU 15-26B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 13345 feet Plugs measured 10700 feet true vertical 8819 feet Junk measured 9640,13259 feet Effective Depth: measured 10700 feet Packer measured 7869 feet true vertical 8883 feet Packer true vertical 7809 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 31 -111 31 - 111 1490 470 Surface 3473 13-3/8" 30-3503 30-3502 5020 2260 Intermediate 8524 9-5/8" 27-8551 27-8299 6870 4760 Liner 1577 7" 8282-9859 8128-8843 8160 7020 Liner 4466 4-1/2" 8878-13344 8479-8819 8430 7500 Perforation Depth: Measured depth: 8510-13220 feet True vertical depth: 8275-8821 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 25-8886 25-8483 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 7869 7809 true vertical depth) No SSSV Installed 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: 178 3845 18 0 229 Subsequent to operation: 486 29660 0 0 1191 14. Attachments (required per20 nnc 25.07026 071, s 25.283) 15. Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 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: N/A Authorized Name: Brown, Don L. Contact Name: Brown, Don L. Authorized Title: Petroleum Engineer Contact Email: bmwd2@BP.com (� Authorized Signature: I�J0-n Lf Date: 1_a,7,7048 Contact Phone: +19075644675 Form 10-404 Revised 0412017 lel �Iwo # 4z-`z4.plm+c.Q RBDMS JAN Z 3 2020 Submit Original Only Daily Report of Well Operations PBU 15-26B ACTIVITYnATF `**WELL SHUT IN ON ARRIVAL**' (SLB ELINE: PERF) INITIAL T/I/0 = 120/700/50. PERFORATE 8519'- 8549' (REFERENCE DEPTH 8510'-8540') WITH 2.88" POWERJET NOVA, 6 SPF, 60 DEG PHASED. FINAL T/I/O = 140/700/150. 1/3/2020 'WELL SHUT IN ON DEPARTURE, DSO NOTIFIED' T/I/O = 1210/1390/390. Temp = 102°. Bleed IAP to CLP (eval TxIA). No AL. IA FL @ 6469' (sta # 2 SO). Currently bleeding IAP to production. 1/12/2020 Cont on WSR 1/13/20. Cont from WSR 1/12/20. Bleed IAP to CLP (eval TxIA). IA FL @ 6469' (sta # 2 SO). Bled IAP to 15-05 production from 1390 psi to 580 psi in 2 hrs. Monitored for 30 min. IAP & IA FL unchanged. Final WHPs = 1210/580/350. 1/13/2020 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 02:00 T/I/O = 1180/570/330. Temp = 100°. WHPs (post bleed). No AL. TP decreased 30 psi, IAP decreased 10 psi, OAP decreased 20 psi overnight. 1/14/2020 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 04:45. TREE= 4-118' CAMERON WELLHEAD= FMC ACTUATOR= AXELSON OKB. ELEV = 68' REFELEV= 61.3' BF. ELEV = 3422' KOP = 6969' Max k = 93' 12135' Dafen MD = 9986' "* Dahm TVD = 8800' SS x 12.415' Minimum ID = 3.725" @ 8874' 4-1/2" HES XN NIPPLE TOP OF 7' LNR --F 8: 1-5/8' CSG, 47#, L-80 BTC, D = 8.881' 8667' 4-12' TBG, 12.61f, 13CR VAM TOP, 8886' .0152 bpf, D = 3.958' 7- LNR, D = 6.184' 12.6#, L-80 4.6#, L-80 15-26B PERFORATION SUMMARY REF LOG: GR/CCL ON 0620192 w6" / ANGLE AT TOP PERF: 53" @ 8510' //3 zozo Note: Refer m Pmdwbon DB for tisbrical perfda SIZE SPF 14TERVAL NS z SHOT SOZ 2-78' 6 8510-8540 O DOME RK 16 2.88' 6 10230 -10290 O 07/09/15 DOME RK 2.88' 6 10414 -1 D444 O 07/09/15 MMG 2.88' 6 10605 -10635 O 07/06/15 27 2-12" 4 10800-11570 S 0925104 09/17/14 2-12' 4 11630-11800 S 0925/04 09/17/14 2-7/8" 6 12208 -12238 C 0923/14 2-718' 6 12256 -12281 C 0923114 2-7/8' 6 12331 -12361 C 0922/14 2-12' 4 12400 -12640 C 0925104 2-12' 4 12750-13220 C 0925104 I SAFETY NOTES: 700@9500' "CAUTION: MULTIPLE POINTS WHERE WELL CROSSES TVD (8800' SS)** ***CHROME 4-12" TBG** -irL- HLS X NP, D= 3. ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3140 3139 1 MMG DOME RK 16 1027/16 3 5240 5239 1 MMG DOME RK 16 1027/16 2 6469 6468 4 MMG SO RK 22 10/30/17 1 7696 7658 27 MMG OMY RK 0 0926/04 8878' 1 8900' 1 SLM .0152 WE D = DATE I REV BY COMMENTS DATE REV BY COMMENTS 1992 1 IORIGINAL COMPLETION 10/31/17 LG/JMD GLVC/0(10W17) 1996 SIDETRACK 15-2 01/06/20 NXW/JMD ADPERFS 02/0320) 0927104 N2E5 SIDETRACK 15-268 012220 DD /JMD ADDED OKB, REF, & BF ELEV 0920/16 ZV/JMDPULLED PLUG &PKR -SET FISH 11/02116 JPK/JMD GLV C/O 1027116 0724/17 JDMJMD I SET CBP & RECOVERED 1 SLP FROM FISH 14-112" HES X NP. D = 3.813' 1 4-12- Ht AN NP, U = 3725' 7' X 5' BKR ZXP LNR TOP PKR w /T1BK SLV, D = 4.340' 4-112' WLEG, D = 3.958' Z5" BKR HMC LNR Rw/RNP, D=4.25" 5' X 4-12' XO, D = 3.94" FISH: PKR JUNK; 2 SLPS, 1 PARTIAL SLP, PKR ELEM, SLP CAGE ORIFICE ASSY; 0 - RINGS (09/18116) RECOVERED 1 SLP 7119/17 MILLOUT WINDOW (15-288) 9859' - 9871' VllIq-vZN:Tmm PRUDHOE BAY UNIT WELL: 15-266 PERMIT No: F1041590 API No: 50-029-22235-02 T11 N, R14E, 1030' FNL & 202 BP Expbraron (Alaska) STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMIS', • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:5c/-CJ 5,1 1E 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-159 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22235-02-00 7. Property Designation(Lease Number): ADL 0028306 8. Well Name and Number: PRUDHOE BAY UNIT 15-26B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13345 feet Plugs measured 10700 feet RECEIVED true vertical 8819 feet Junk measured 9640/13258 feet AUG 16 2017 Effective Depth: measured 10700 feet Packer measured See Attachment feet true vertical 8883 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20"91.5#H-40 30-106 30-106 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 8525 9-5/8"47#L-80 27-8552 27-8300 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10230-10290 feet 10414-10444 feet 10605-10635 feet 10800-11570 feet 11630-11800 feet 12208-12238 feet 12256-12281 feet 12331-12361 feet 12400-12640 feet 12750-13220 feet True vertical depth: 8882-8885 feet feet 8888-8888 feet 8885-8884 feet 8884-8877 feet 8877-8878 feet 8861 -8860 feet 8859-8859 feet 8858-8857 feet 8855-8844 feet 8838-8821 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-8886 25-8483 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): p NOV 7 Treatment descriptions including volumes used and final pressure: SCANNED f y O`f 0 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 512 40605 0 0 1758 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Authorized Name: Odom,Kristine Contact Name: Catron,Garry R(Wipro) Authorized Title: DS 06&13 PE Contact Email: Garry.Catron@bp.com Authorized Signature: Date: 08/15/2017 Contact Phone: +1 907 564 4424 Form 10-404 Revised 04/2017 rr` ID/6 /1 7"r/p h i RBDMS tv AUG Z 3 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) August 15, 2017 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Set Plug for Well PBU 15-26B, PTD #204-159. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 . , • • C"Z Z C/) C O COmmm%n !3Z Z :U20 :3 -11T00 gn DDCD� M m m 3 0C 7J m r oo 41. oo w co CO A C31 Cn w OD V0) 01 V NJ co ()I al OV) O O — — N W N ~ w w - C) � 4t00 � C _ 4t 00 006 0 0 o m C Dcr N OOb N 1\3 _A- NJ w 0" VoC V C D BOO z o - 0) — n aowoaow _ � V1 0° wc°Di� c0'i, CD C)) CO N N V O T� CD W N A - N - N W 01 CO 1\) V - CO O 1 1 1 1 1 1 1 v oo 0o w oo w ooCX) w -1). _so w --v .11% 000 �03 CO CA) rn CO 03 03 —% OD0 Ce) CO O) V NJ Cn CO ,72 0 0 0 0 0 0 0 CI V V V ). N —. 0 01 01 CD V N CO v Fit O O N O) O) CJS 00 O O O O O CD • • Packers and SSV's Attachment PRUDHOE BAY UNIT 15-26B SW Name Type MD TVD Depscription 15-26B TBG PACKER 7869.39 7808.82 9-5/8 X 4.5 Baker S-3 Packer 15-26B TBG PACKER 8291.01 8133.87 7" Baker H Packer 15-26B TBG PACKER 8888.93 8484.3 7" Baker HMC Packer 15-26B TBG PACKER 10732.2 8883.44 4-1/2"WFD ER Packer • \ Cl) $ m > -1 \ - a / w -I m m0C0 / § \_ & 0— o 0 ¥ o o -1 -0 o m ] �_. c -0 II E a o c 6 E / k. %/ 11 1 / co - 2CD co // / / O2 a o m A. o c, k / > -h \ CD a -< 0 a _ c / m 2 I K .13 --- J k > m 2f o J ` c @ \ 2 k 0 -u -o k 0 E -o 0 0 TREE= 4118"CAMERON • 4110FETY NOTES: 70°@ 9500' **CAUTION: WH_LHEAT0= FMC MULTIPLE POINTS WHERE WELL CROSSES ACTUATOR= AXELSON 15�� TVD(8800'SS)** OKB.ELEV= 68' ***CHROME 4-1/2"ma** BF,ELEV= ? KOP= 6969' - Max Angle= 93°@ 12135' , ' 2085' --{4-1/2"HES X NIP,D=3.813" Datum M)= 9986'"* Datum TVD= 8800'SS GAS LFT MANDRELS 13-3/8"CSG,68#,K-55,D=12.415" —I 123' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3140 3139 1 MMG DOME RK 16 10/27/16 L 3 5240 5239 1 MING DOME RK 16 10/27/16 13-3/8"CSG,68#,L-80,D=12.415" —I 3510' 2 6469 6468 4 WAG DMY RK 0 09/26/04 1 7696 7658 27 MAG DMY RIC 0 09/26/04 Minimum ID = 3.725" a@ 8874' I I 7849' —H4-1f2"HES X NIP,D=3.813" 4-1/2" HES XN NIPPLE 7$69• —j9-5J8"X 4-112"BKR S-3 ACR,D=3.875" • 7897' —14-1/2"HES X NP,D=3.813" TOP OF 7"LNR H 8289' 8874' 1-14-112"HES XN NP,ID=3.725"_....1 9-5/8"CSG,47#,L-80 BTC,D=8.681" — 8557' 8878' 1-1r X 5"BKR ZXP LNR TOP PKR w/'EBKSLV,D=4.340" 4-112"TBG,12.6#,13CR VAM TOP, H 8886' i 8886' H4-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" 8900' —7"X5"BKRI'NCLN2 I-NGRw/RNP,D=4.25" 8906' Hs"X 4-1/2"XO,D=3.94' WHIPSTOCK(09/19/04) — 9859' 9640'SLM —FISIt FKRJUNK;2 SLIPS,1 PARTIAL SLP, PKRELBN,SLP CAGE ORF10EASSY;0- RINGS(09/18/16)RECOVERED 1 SUP7/19/17 7`, 7"ESZV(09/18/04) —I 9878' ',x, MILLOUT WINDOW (15-26B)9859'-9871' 7"LNR,29#,L-80,.0371 bpf,D=6.184" —L 10330' '44"c� ��t'j ` 4-112'SLTDISOLD LNR 12.6#,L-80 --I 11549' 1,4.4.�...1.� ` 10700' H 4-11 2"YVFT OBP(07120/17) c.cc P,,,,,1' 2-3/8'SOLD/SLID LNR 4.6#,L-80 —{ 12451' * /�����' I ..��A I PERFORATION SUMMARY '114 REF LOG: GR/CCL ON 06/20/92 ` ANGLE AT TOP FERF:87°@ 10230' Nbte:Refer to Ftoduction DB for historical pert data N4441/4 -13259' FISH:MLLE?CBP SIZE SPF INTERVAL Opn/Sqz SHOT SOZ (09/24/14) 2.88" 6 10230-10290 0 07/09/15 2.88" 6 10414-10444 0 07/09/15 2.88" 6 10605-10635 0 07/06/15 2-1/2" 4 10800-11570 S 09/25/04 09/17/14 2-1/2" 4 11630- 11800 S 09/25/04 09/17/14 \\� 2-7/8" 6 12208-12238 C 09/23/14 PBTD H 13259' ;\``� 2-7/8" 6 12256-12281 C 09/23/14 ;;�. 2-7/8" 6 12331-12361 C 09/22/14 2-112" 4 12400-12640 C 09725!04 4-1/2"LNR,12.6#,L-80 BTC-M,.0152 bpf,D=3.958" --I 13344' 2-1/2" 4 12750-13220 C 09/25/04 DATE REV BY CO J U(TS DATE REV BY COMMENTS PRU DHOE BAY MT 1992 ORIGINAL COMPLETION 08/04/15 BLS/JM) SET ER FKRASSY/AE)F'ERFS WELL: 15-268 1996 SIDETRACK(15-26A) 02/04/16 CJS/TLH ER FKR ASSY CORRECTIONS PERMT No:"2041590 09/27/04 LAZES SIDETRACK(15-26B) 09/20/16 ZV/JMD PULLED PLUG&NKR-SET FISH AR No: 50-029-22235-02 09/09/14 RCT/JMD GLV CJO&WBS EDIT(09/04/14) 11/02/16 JFK/JM) GLV C70(10/27/16) SEC 22,T11N,R14E, 1030'FNL&202'FWL 09/29/14 CJS/JM) SOZ/ADPE2FS/FISH(09/17-23/14) 07/24/17 JDMJM) SET OBP&RECOVERED 1 SLP FROM FISH 10/08/14 JM) ADDED PERF SQZ DATES(9/17/14) I BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Pull Blanking Orifice 10 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-159. 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22235-02-00 7. Property Designation(Lease Number): ADL 0028306 8. Well Name and Number: PBU 15-26B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 13345 feet Plugs measured feet ry true vertical 8819 feet Junk measured 9640/13258 feet MAY 2 4 ?017 Effective Depth: measured 13259 feet Packer measured 7869 feet true vertical 8820 feet Packer true vertical 7808.82 feet 'AOG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20"91.5#H-40 30-106 30-106 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 8525 9-5/8"47#L-80 27-8552 27-8300 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10230-10290 feet 10414-10444 feet 10605-10635 feet 10800-11570 feet 11630-11800 feet 12208-12238 feet 12256-12281 feet 12331-12361 feet 12400-12640 feet 12750-13220 feet True vertical depth: 8882-8885 feet feet 8888-8888 feet 8885-8884 feet 8884-8877 feet 8877-8878 feet 8861 -8860 feet 8859-8859 feet 8858-8857 feet 8855-8844 feet 8838-8821 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-8886 25-8483 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): NES vUN I O17 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: 306 P8381 9 350 1445 Subsequent to operation: 717 33372 30 560 2404 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development ® Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 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: N/A Authorized Name: Odom,Kristine Contact Name: Odom,Kristine Authorized Title: DS 06&13 PE Contact Email: Kristine.Odom@bp.com Authorized Signature: JA, Dater 21 2017 Contact Phone: (907)564-5365 Form 10-404 Revised 04/2017 1/7-1-- 57 31 /19" �� �2 f, 'i/A7 R n ffi s Lv :!'y 2 ^� 2617 Submit Original Only • • RECEIVED baa MAY 2 4 2017 AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary May 23, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for the pulling of a Blanking Orifice Packer Assembly that resulted in the opening of Perforations to Flow for 15-26B, PTD # 204-159. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • m fa.0• 00000co R r Lo cc CO N O O C) N ti O Lc, LC') p N r- r- U y 0 0 0 0 0 o o i O) LU N CO CO CO • d' O CO r m — M Lc, CO CO CO CO O CO CS) CO 00 O V •- CO r t CO CO CO CO CO CO CO CO N OD O C3) N- N- N N- LU CO N N r- NJ' N CO CO w CO � NNO � Co CA Lc, Lc, M cc Lc, ) M co L co CO C0D CO V p M I i i i I i � I'V1 LU CD Q N o0NNccr- _ CO N N 00 CO N _ r .0• MD W O Lc, O O CO O coO U l(7 CXJ (b a) Y J J J M = 3coccc (0 *k ► 3*: LO CO CO : *k N CO .C7) N0) Diu -C _O o0 N _ U O (NJ r) Mci) � � N r r t +' 00Lc, inCOc- C CO CO CO LO Ln CO co CO .- cr co W � ~Q �O cwwa O00 U o w W E C Z Z W W W pp O DotzzD U (n (n Z J J I- • • Packers and SSV's Attachment PBU 15-26B SW Name Type MD TVD Depscription 15-26B TBG PACKER 7869.39 7808.82 9-5/8 X 4.5 Baker S-3 Packer 15-26B PACKER 8291.01 8133.87 7" Baker H Packer 15-26B PACKER 8888.93 8484.3 7" Baker HMC Packer • 0 2 % / -S/ CI o � 2 / o / $ o : c ¥ c c � _i // 0_ ® E& 2R / 27 2w 7co- :6 o 2w = = p RS _1 § < 0 �CK —= 2 / L 2 L 7 2 CD ƒ 0 "3 / < C �7k - 8' -co / ± IP < 'H co \ / co / co o ©fa. 2 >,> & - 2 A Z Z Off / °\ � / � E / oOo f CO 02 m c2 � 2 \ E6 27 / / c / E / 2 -1 ® -Ic2 » _ -I2 Wm % / G / / _ 2 wFo2 0 L / # 2 O / ƒ t q � '- C l' EL m co 5 I m » « op- 2 ƒ « re < < co 0DG m777 $ = \ 2m & a) 2 & 2 0) 220 _ 2 % ,— 0 2 / . L « / \ < c $ CI Ca zc`iNo0W / u) 0 / / k 0 F— O � F- L0uF CEt LLIQ IZ2w22I-2 U = u L m u < Z L 3 2u- 3 / 0 2 - 0 U E U o L O - m m Q # m u) 6GoG8 / G 0 b0 a) / / k / / / \ 2222 / / kz / 22 $ 2222 % ƒ / / Z < - $ | « « « < < « c _ < _, .2 « « , f a cti ± tti 3t 5 Ili H 0 /0 / C) U) H / / ƒ n 5 \ k \ < ,TREE= • 41/8"CAMERON • V413LHEAD= FMC •AFErY NOTES: 70°@ 9500' **CAUTION: ACTUTOR= AXESON 1 WH MULTIPLE POINTS ERE WELL CROSSES OKB.BEV= 68' TVD(8800'SS)** BF.BEV= '. ***CHROME 4-1/2"TBG*** KOP= 6969' Max Angle= 93"@ 12135' 20$5' 4112"HES X NIP,ID=s3.813" Datum MD= 9986'** / I I Datum TVD= 8800'SS GAS LIFT MANDFELS 13-3/8"CSG,68#,K-55,D=12.415" H 123' ST MD TVD DEV TY PE VLV LATCH'FORT DATE Li4 3140 3139 1 MAG DOW RK 16 10/27/16 3 5240 5239 1 MMG DOME R K 16 10/27/16 13-3/8"CSG,68#,L-80,D=12.415" H 3510' , 2 6469 6468 4 MAG EASY RK 0 09/26/04 1 7696 7658 27 MMG DU( RK 0 09/26/04 Minimum ID =3.725" @ 8874' I I 7849' H4-1/2"HES X NP,ID=3.813" 4-1/2" HES XN NIPPLE 7869• —19-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" 789T H4-1/2"HES X NP,ID=3.813" TOP OF 7"LIR H 8289' 8874' J—4-1/2"HES XN NP,ID=3.725"J 9-5/8"CSG,47#,L-80 BTC,ID=8.681" H 8557' F---Al 8878' —7"X 5"BKR ZXP LNR TOP PKR w/TEBK SLV,D=4.340" 4-1/2"TBG, 12.6#,13CR VAM TOP, H 8886' M. 8886' H4-1/2"WLEG,ID=3.958" .0152 bpf,D=3.958" �� I 8900' —7"X 5"BKR WC LM I-NGR w/RMP,D=4.25" 8906' He"X 4-1/2"XO,D=3.94" , VN-IPSTOCK(09/19/04) H 9859' 9640' SLM —FISH:PKR JI C;3 SLIPS, 1 PARTIAL SLIP, 66' . PKR ELEM,SLP CAGE ORIFICE ASSY;0- RIVGS(09/18/16) 7"ESZV(09/18/04) — 9878' ` MILLOt1T WINDOW (15-268)9859'-9871' ` 1 7"LNR 29#,L-80,.0371 bpf,D=6.184" H 10330' F��.�T�t•�t►.��1��� ` 1.....4-1/2"SLTD/SOLD LNR 12.6#,L-80 —{ 11549' -f��t ttt 2-3/8"SOL 'SLTD LNR,4.6#,L-80 — 12451' ►�i8.A�.���'� Di FE RFORAT1ON SUMARY ' 11 RIF LOG: GR/CCL ON 06/20/92 ` ANGLE AT TOP FERE:87"@ 10230' Note:Refer to Production DB for historical perf data ` '13259' —FISH:MILL®C8P SIZE SFP INTERVAL Opn/Sqz SRiDT SQZ ` (09/24/14) 2.88" 6 10230-10290 0 07/09/15 2.88" 6 10414-104.44 0 07/09/15 ` 2.88" 6 10605-10635 0 07/06/15 2-1/2" 4 10800-11570 S 09/25/04 09/17/14 • 2-1/2" 4 11630-11800 S 09/25/04 09/17/14 ,`` 2-718" 6 12208-12238 0 09/23/14 PBTD H 13259' ..;�!' 2-7/8" 6 12256-12281 0 09/23/14 Nt, 2-7/8" 6 12331 -12361 0 09/22/14 2-1/2" 4 12400-12640 0 09/25/04 4-1/2"LNR,12.6#,L-80 BTC-M,.0152 bpf,D=3.958" —f 13344' 1 2-1/2" 4 12750-13220 0 09/25/04 DATE REV BY CONVENTS DATE REV BY COAMHVTS FRUDHOE BAY INT r 1992 ORIGINAL COMPLETION 08/04/15 BLS/JMD SET ER FKR ASSY/ADFERFS WELL 15-26B 1996 4 SIDETRACK(15-26A) 02/04/16 CJS/TLH ERPKR ASSY CORRECTIONS PERMIT No:'L041590 09127/04 N2ES SIDETRACK(15-26B) 09/20/16 ZV/JMD PULLED PLUG&PKR-SET FISH AR No: 50-029-22235-02 09/09/14 RCT/JMD GLV CIO&WBS EDIT(09/04/14) 11/02/16 JPK/JND GLV GO(10/27/16) SIC 22,T11 N,R14E, 1030'FTS.&202'FWL 09/29/14 CJS/JMD SQZIADPERFS/FISH(09/17-23/14) II 10/08/14 MID ADDED FBF SOZ DATES(9/17/14) i BP Exploration(Alaska) STATE OF ALASKA 0,LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-159 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22235-02-00 7. Property Designation(Lease Number): ADL 0028306 8. Well Name and Number: PBU 15-26B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: 1.^r r Total Depth: measured 13345 feet Plugs measured 10738 feet t1,I11;1 El ?r ,, true vertical 8819 feet Junk measured 13258 feet e, 1t#', Effective Depth: measured 10738 feet Packer measured See Attachment feet true vertical 8883 feet Packer true vertical See Attachment feet e Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 76 20"91.5#H-40 31-107 31 -107 1490 470 Surface 88 13-3/8"68#K-55 30-118 30-118 3450 1950 Surface 3376 13-3/8"68#L-80 118-3493 118-3493 5020 2260 Intermediate 8525 9-5/8"47#L-80 27-8552 27-8300 6870 4760 Liner 1575 7"29#L-80 8284-9859 8129-8843 8160 7020 Liner 4466 4-1/2"12.6#L-80 8879-13345 8479-8819 8430 7500 Perforation Depth: Measured depth: 10230-10290 feet 10414-10444 feet 10605-10635 feet 10800-11570 feet 11630-11800 feet 12208-12238 12256-12281 feet 12331-12361 feet 12400-12640 feet 12750-13220 feet True vertical depth: 8882-8885 feet 8888-8888 feet 8885-8884 feet 8884-8877 feet 8877-8878 feet 8861-8860 8859-8859 feet 8858-8857 feet 8855-8844 feet 8838-8821 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 26-8888 26-8484 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCAM NOV 1 62015 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 608 52554 3 0 1164 Subsequent to operation: 586 29184 8 0 1457 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Contact Summerhays,Nita M(WIPRO Technologies) Email Nita.Summerhays@bp.com Printed Name Summ-rhays, v: , (WIPRO Technologic/ Title Petrotechnical Data Manager Signat / / Phone +1 907 564-4035 Date 08/05/2015 L. L .�_ Form 10-404 Revised 5/2015 V Tl- q/2,/j5 (7�) Sub i riginal Only /// RBDMS AUG 1 4 .2015 • • Daily Report of Well Operations PBU 15-26B ACTIVITYDATE SUMMARY CTU 8 w/ 1.5" CT(CTV=24.7) Objective-GSO by setting ER packer above existing perfs and adding 120'of perfs. N2 lift MIRU from maintenance. Function test BOPs upon initial rig up. BOP test w/no failures. Liquid pack wellbore w/ 1% KCI w/SL. RIH w/ PDS MGR/CCI carrier and 3.70" drift to 10830' CTM. Log OOH to 9900'and paint flag at 10700'. POH 7/5/2015 ""*Job in Progress*** CTU 8 w/ 1.5" CT(CTV=24.7) Objective-GSO by seting ER packer above existing perfs and adding 120' of perfs. N2 lift Finiish POH w/logging tool/drift. RIH w/WFT ER packer assy and set at 10740' ME. POOH. L/D setting tool and recover 5/8" ball, all looks good. M/U and RIH w/snap-latch and blanked off orifice assembly BHA, OAL: 17.83'. Pump additional 5bbl 50/50 cap on well. 7/6/2015 ***Jobi n progress""" CTU 8 w/ 1.5" CT(CTV=24.5) Objective-GSO by setting ER packer above existing perfs and adding 120'of perfs. N2 lift Finish POH w/logging tool/drift. RIH w/WFT ER packer assy and set at 10740' ME. POOH. L/D setting tool and recover 5/8" ball, all looks good. M/U and RIH w/snap-latch and blanked off orifice assembly BHA, OAL: 17.83'. Pump additional 5bbl 50/50 cap on well. Latch orifice assembly in ER packer. Pump off and PU. Left orfice top at 10732' ELMD. Perform mini MIT-T to 500psi, held. POOH. LD BHA and cut 104' of coil. MU and RIH w/Perf Gun#1: 30' of 2.88" guns-6spf-60 deg- 2906 PJ HMX charges, OAL=38.47' and perforate 10605-10635' using top of orfice sub as depth control. POH. MU 30' perf gun#2 7/6/2015 In progress CTU 8 w/ 1.5" CT(CTV=24.5) Objective-GSO by setting ER packer above existing perfs and adding 120'of perfs. N2 lift RIH w/perf gun#2 and tag orfice sub in ER packer at 10745' CTM which is—25'deeper than previous run. POH to run log. LD live perf gun. Change packoff, MU/RIH with logging tools, OAL=12.47', max OD=2.875". Tag packer at 10752'CTMD. Log out of hole from compression. Paint flag at 10615'E/10594M. POOH. LD logging tools, download data. +10'correction. Tagged blank plug in orifice sub at 10761.71' corrected depth. Packer has moved down hole 29'. APE agrees to fish and re-set packer. MU and RIH with fishing BHA, OAL=22.33', max OD=3.6". Latched orfice sub found at 10752' CTM and pulled it and the ER packer to the XN nipple at 8865' CTM. Pulled fish thru nipple after getting jars to fire. POH 7/7/2015 In progress CTU 8 w/ 1.5" CT (CTV=24.4) Objective-GSO by setting ER packer above existing perfs and adding 120'of perfs. N2 lift LD WFT ER packer assy and orfice sub complete. RIH w/PDS carrier w/3.70"drift. Log up from 10800 to 9900'CTMD.Paint yellow flag at 10650.0E/10622M/10650.0PDS. POOH. LD Logging tools. Download Data. +7' correction. MU and RIH with Hydraulic Setting Tool and ER Packer, OAL= 16.41' Max OD=3.7". Correct depth at the flag for the middle element to 10660.7'ELMD. RIH and set packer at 10710'ELMD. POOH. LD setting tools. Cut 100' of pipe. MU/RIH with Hyd Spear and snap latch orifice assembly with a blank and text book set in ER packer. POH 7/8/2015 In progress CTU 8 w/ 1.5" CT(CTV=24.2) Objective-GSO by setting ER packer above existing perfs and adding 120'of perfs. N2 lift RIH w/2-7/8"x 30' perf gun#2 and perforate 10414-444' using orfice blank as depth control. POH. LD perf gun, ASF, ball recovered. MU and RIH with 2-7/8"x30' pelf gun #3 and perforate10260- 10290' using orifice blank as depth control. POOH. LD Gun#3. ASP, Ball recovered. Cut 100'of pipe. MU and RIH with 2-7/8"x30' pert gun#4 and perforate from 10230-10260' using orifice blank as depth control. POOH. LD Perf gun. Standby for DSO for N2 lift. 7/9/2015 In progress • • Daily Report of Well Operations PBU 15-26B CTU 8 w/ 1.5" CT(CTV=24.2) Objective-GSO by setting ER packer above existing perfs and adding 120' of perfs. N2 lift Standby for DSO for N2 lift. MIRU N2 Pump- RIH w/ 1.9" JSN pumping 500 scf/min N2 to 7000' and kicked off well. POH. Left well flowing and in control of DSO. RDMO to H-27 7/10/2015 Job complete Fluids Summary BBLS Type 53 50/50 METH 505 1% SLICK KCL W/SAFELUBE 558 Total • Packers and SSV's Attachment PBU 15-26B SW Name Type MD TVD Depscription 15-26B PACKER 7870.74 7809.96 9-5/8 X 4.5 Baker S-3 Packer 15-26B PACKER 8291.01 8133.87 7" Baker H Packer 15-26B PACKER 8890.28 8484.96 7" Baker HMC Packer 15-26B PACKER 10738.1 8883.48 4-1/2"WFD ER Packer TREE 41/8'CAMERON • *EN NOTES: 70°@ 9500' "CAUTION: WELLJ-EADD=AAXt3SON 15-26B MULTIPLE POINTS WHERE WELL CROSSES ACTUATOR ND(8800'SS)" OKB EDI= 68' "'CHROME 4-1/2"TBG KOP= 6969' Max Angler 93 12135' I I 2085' -j41/2'HES X NP,D=3.813' Datum MD= 9986'" Datum TVD= 8800'SS GAS LFT MANDRELS 13-3/B'CSG,681S,K-55,D=12.415' 123' ST MD TVD DEV TY FE VLV LATCH PORT DATE ' 4 3140 3139 1 MAG DAY RK 0 09/04/14 3 5240 5239 1 MAG OW RK 0 09/04/14 --Al 2 6469 6468 4 LMAC DI1AY RK 0 0926/04 13-318°CSG,68#,L-80,D=12.415' — 3510' 1 7696 7658 27 WAG DMY FE 0 09/26/04 Minimum ID = 3.725" @ 8874' I 78.49' --I4-12'HEs x NP,D=3.813" 4-112" HES XN NIPPLE 7869' ' 9-5/8'X 412"BKR S-3 Fa(R,D=3.875" ' 7897' —4-1/2'FES XMP,C=3.813' aril TOP OF 7"Lt•Ei H 8289' 9-5/8-CSG,47#,L-80 BTC,D=8.681' — 8667' 4s>.74' I—4-12"HES XN NP,ID=3.725' ' _ { 8878' -7'X 5-BKR ZXP LAIR TOP PKR 41/2'TBG, 12,6#,13CR VAM TOP, — 8886' .,11=61(SLV,D=4.340' .0152 bpi,0=3.958' ► 8886' —41/2'V&EG,D=3.958' 8900' —r X 5"BKR HMC LNR I-NGR w 1 R NP,D=4.25' IWt-PSTOCK(09/19/04) — 9859' 8906' -5"X 4-12'XO,D=3.94' MILLOUT WINDOW (15-268)9869'-9871' 7"ESZV(09/18/04) H 9878' ` • r LNR 29#,L-80, 0371 bpf,D=8.184" — 10330' _ �1�1�1�1�1�:�1�1; ` 10710' —4-12'ER PACKER 412'SLTD/SOLD LIR 12.6#,L-80 J— 11549' 1.1.1.1.1.1.1 " �.<<_. w!CX'2FICE A SSY,D= 1 tt♦tt :....***0.• .� , (07/08/15) 2-38"SOLD/SLTD LNR 4.6#,L-80 -1 12451' .111 /�:.�1111l I `/ —BLANK PLUG(07!08/15) PERFORATION SUIMAARY 01111` 11' REF LOG: GR/CXi.ON 06/20/92 ` ANGLE AT TOP F .87"CO 10230' Mite:Refer to Production 0B for historical pert data ` -13259' IL F1S1-t MLLE!CSP SIZE SPF INTERVAL Opn/Sqz SHOT SQZ Sk (09124/14) 2.88' 6 10230- 10290 0 07/09/15 ' 2.= 6 10414- 10444 0 07/09/15 2.88' 6 10605-10635 0 07/06/15 2-1/2 4 10800-11570 S 09/25/04 09/17/14 2-12' 4 11630-11800 S 09/25/04 09/17/14 ;\;` 2-7/8" 6 12208- 12238 C 09/23/14 PBTD — 13258' AA��• 2-7/8' 6 12256- 12281 C 09/23/14 \;�. 2-7/8' 6 12331 - 12361 C 0922/14 2-12' 4 12400- 12640 C 0925/04 412'LIR,12.6#,L-80 BTC-M,.0152 bpf,D=3.958' -1 13344' i 2-12' 4 12750-13220 C 09/25/04 DATE REV BY COMMENTS DATE REV BY CX)MWNTS PRUDH0E BAY UNIT r 1992 ORIGINAL COMPLETION 09/09/14 RCT/JMD GLV GO&WBS EDIT(09/04/14) WELL 15-26B 1996 SIDETRACK(15-26A) 09/29/14 CJS/JM) SQZJADPERFSJFRSH(09/17-23/14) PERMIT No:`2041590 09/27/04 NRES SIDETRACK(15-266) 10/08/14 JMD ADDED PERF SOZ DA11±,(9/17/14) API No: 50-029-22235-02 09/05/08 REM/PJC SET VWRP(08118/08) 08/04/15 BLS/JAV SET ETR RCRASSY/ADPERFS SEC 22,T11N,R14E, 1030'FM.&202 FAL 12/04/13 RCT/JM) FISH LEFT N HOLE(11/30/13) 12/11/13 TTR/JMD FULLED FISNIVVRP(12/05-07/13) BP Exploration(Alaska) · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may bescanned during a special rescan activity or are viewable by direct inspection of the file. c:2..o It-- 1 ~ ~ Well History File Identifier Organizing (done) o Two-sided 1/1111/11111/1/1111 o Rescan Needed 1111111111111111111 RES CAN ~Ior Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. ~ o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date: II /1 Lf IOh I / /s/ iliP Project Proofing 11I111111111111111/ BY: ~ Date: II IJ if/Db I I d- x 30 = D + Date: I I /s/ rY\f Scanning Preparation BY: / = TOTAL PAGES {p I (Count does not include cover sheet) /s/ Production Scanning 11I111111111111111I Stage 1 Page Count from Scanned File: (¿; ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ¿ YES ~ Datal//llt/Ob If NO in stage 1, page(s) discrepancies were found: YES BY: /s/ ~p Stage 1 NO BY: Maria Date: /s/ 11111111111I111111/ Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 "II/ BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111/1111111111 10/6/2005 Well History File Cover Page.doc 02/23/11 Schkakerger NO. 5698 Alaska Data & Consulting Services Company: State of Alaska 2525 GambeII Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD P2 -31A BCRD -00081 TEMP &X/Y CALIPER SURVEYa ®t}' /C //) 02/06/11 1 ,.S`6/Si-. 1 E -03A BL85 -00015 SCMT .D6 f - ;)- 01/27/11 j•SNJ)(p 1 1 04-21 BG4H -00031 PRODUCTIOFrPROFILE 1 J. 02/02/11 1 04-17 BG4H -00029 INJECTION PROFILE / - 01/31/11 1 1 P2 -52 BCRD -00082 PRODUCTION PROFILE c i - t ` 1 02/09/11 i 1 11 -04A BG4H -00032 X -FLOW CHECK/IBP / " f - /7 ji 02/06 /11 1 kiA 1 W -202 BMSA -00005 ISOLATION SCANNER 16 01/30/11 _ ,a , # 1 1 15 -26B BD88 -00088 MCNL _ • J - prze 1 15 -11C BD88 -00081 MCNL _VL j1Ljg 01/06/11 1 F Ira- . 1 07.09A BD88 -00078 MCNL — / _ 12/08/10 1 'j 1 I SO K -12B BCUE -00094 MCNL :. 0 al • - / 11/23/10 1 . /1 � �}� 1 E -35B BD88 -00077 MCNL 12/05/10 1 _ • +. 1 B -04A BAUJ -00055 MCNL .. V 11/21/10 1 NJY!e 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 Gambell Street, Suite 400 I 900 E. Benson Blvd. Anchorage, AK 99503-2838 • A MA 1 2011 MAR 1 4 2( M.# AMA t z ' 12/30/10 Schhunberger NO: 5672 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambefl Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -28311 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Y 6 Anchorage, AK 99501 Job # Log Description Date BL Color CD E -05 BL65 -00011 MEM DDL 12/18/10 1 1 - 38 AY1M-00056 PROD PROFILE ,- _ -/ 11/27/10 1 • •,i 1 11-12 BCZ2 -00033 PROD PROFILE ", — • 12/06/10 1 .Vn'N:no 1 01 -25 BG4H -00022 • • - • 4 1111111V & r �`�Min 1 04 -24 AY1M -00058 19:•]•1• a•]ylsa MIITZ ♦ r + Z, 1 P2 -16 BSJN -00077 kiriM _ • V} - .. 1 A-41 BCZ2 -00030 LDL (• . - • 11/26/10 1 'LZ, 1 04 -08 BCRJ -000566 INJECTION PR• FILE • "i' • —r 12/06/10 1 O •�• - SirYi 1 01 -24A BBSK -00043 11011X•il[•■IJ:1•]d144 ,AWMTAIIMEY _. r VThM•I'M_ 1 04-10 AVIH -00051 • , • - • IL L1 � ' • •••• � Z ` • _ 12/07/10 1 �i 1 15-268 6088 -00080 EM PROD PROFILE ; & e ', 1 2- 288/0 -19 BCRJ -00055 • - ROD PROFILE _ • • - ��, 11/30/10 1 - 411=A 'T 1 07.23B , AY1M -00056 SCMT - D 11128/10 a( 1 02 -21A BBSK -00042 SCMT 0 4" - • - ,ra , 11123110 - • 12/12/10 1 1 1 1 02 -22B BL65 -00006 SCMT l (" — y , 12/11/10 • ' 1 1 18 -12B BBUO -00029 SCMT ' (S • - 08/30110 • 1 1 P2-16 B5JN -00077 USIT ( 1 -103 11/28/10 • , 1 1 05 -276 BAUJ -00049 MCNL • -• - • 09/18/10 1 4 • , 1 16-066 BBSK -00037 i Ti 11/15/10 1 r+ ---, 1 G-09B B-00050 _ (1 n � 09/28/10 1 ,, � 1 E-34L1 •34L1 BD88-00050 MCNL _ (} --- / / 7 L 09/28/10 1 , 1 W-219 BGZ7.00012 CH EDIT PDC -GR USIT --- - • 11/22/10 M• f.. � ° ] 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Explora0on (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 S' MAR 1 4 2011 • i 1 ~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~`~F~;;~!~ ~l~E~' ~ ~ 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~ d ~ .~ ~,,~ 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 ^ate~ 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01B 2042570 50029206960200- NA Sealed NA 15-02B 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-04B 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Seated NA 15-O6A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-O8C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-12B 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11 /7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-25B 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-31B 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A .2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11!10/2009 15-37B 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-41B 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-49B 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 • • ~K.t ~~ r~~. ryt'Y "`y ... ~_ MICROFILMED 03/01 !2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc 11 /21107 ~chlumber~er Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh it 1 nn rlncrrin4inn ~~~ N0.4509 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 1 l ,~j ~ 333 West 7th Ave, Suite 100 /~ ~ ~ 1 Anchorage, AK 99501 O'1~ Field: P.Bay, Milne Pt., Endicott ns., o~ Z-10 11676974 GLS -" ' -- f J 11/11/07 06-16 11686797 PPROF &RST _ P "'=~"'~', 11115/07 1 MPL-33 11661179 MEM INJECTION PROFILE ~ 1';"~-~~ ? "~°. 11/13!07 1 MPF-25 11846827 USIT ! `~ "°- r _' t;, x 11/10/07 1 GNI-04 11846828 USIT `?• `;:~-,._ "1' P. ~ 11/11/07. 1 OWDW-SW 11626128 RST r) ' ~~ , r„ ..r it-- ~ - 3" ~°`~t- 10/10/07 1 1 3-35/L-36 11630502 RST ~ "t't ' ~°~ ~ ~ ; ;, 3 '~'- s, - i, f rt 09/09/07 1 1 15-266 11661165 MCNL ,'J r)'__l - ~ ~'_<~ '~t ,r °-~~., ~ ~ ~ " 08/24/07 1 1 05-36A 10928638 MCNL ,;,,~ y~ ~-. 4y•°7_~ "~ ~ ;" /) ~= - 06/11/05 1 1 07-16A 11216211 MCNL ~ : a i ~-~" ~ ~~~ d °~ '• ; ~°~~•~ 08/27/06 1 1 2-28B/0-19 11638650 RST ~ ~, j - ~~ ,w„ ~ '"' r ~~:~~ '~ ~ 07/05/07 1 1 07-02A 11649983 MCNL il'1 ". ,'~ ~~ `,~' sg ~---r. r~t 08/07/07 1 1 N-27 40015763 OH MWD/LWD EDIT }ry ? .\.;,'r~ }' - ".~ ~ 09/11/07 2 1 . .. ~.-...~ ... v~ .~wur ~ o~ J~V~~nYV fi1~IV RGIURIYIIYV VIVC l~-JY 4^~Al.l"1 I V: BP Exploration (Alaska) tnc. t~ ~~ ,, Petrotechnical Data Center LR2-1 ' 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~,(~g ~ ,~~ ~fiq~ tl Date Delivered: f J d 3'ii ,r ~ , Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth ,~I ~ ' Received b ~ ~~ ~,, Y f '. os/za/o7 1~1 $C~IUp1d~1'I~P~' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jeh !t Lea Descriofien NO.4414 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Date RI Cnlnr CD 09-25 11695072 LDL ,y, ~ _p 08!17/07 1 L-04 11661166 SCMT 08/25/07 1 15-266 11661165 MEM PROD PROFILE 08!23107 1 02-126 11628789 MEM PROD PROFILE Q 08120/07 1 02-11A 11428266 MCNL G} / [ 10/03/06 1 1 18-24AL2 11209591 MCNL _ ~ / j' (a 03/23106 1 1 14-07 11637334 RST ( - / ~ 05!08107 1 1 B-14 11637349 RST - '~- / ~/ 07/04/07 1 1 Z-08A 11630483 RST - ( 06/21/07 1 1 Z-46 40012671 OH EDIT MWD/LWD ~ - - ~ 1 < 12112105 2 1 Z-46A 40012671 OH EDIT MWDlLWD # / - 01/03/06 2 1 E-37A 10928640 MCNL a p5 -OC`~ '1 06/14/05 1 1 B-34 11594510 RST u q- ~ ~ 06/14107 1 1 MPH-17 11813063 CBUUSIT (PDC) CH EDIT c7U3 -U(a t 5 ~ 07/21/07 1 YLtASt AGRNVWLtUC9t KtGt1Y 1 f!Y i~ItaNINl9 ANU Kt 1 UKNINta UNt GVYY tAGFt 1 V: BP Exploration (Alaska) Inc. _ Petrotechnical Data Center LR2-1 ~ ~- - ~ ~ " k~ ~ ~~; 900 E. Benson 81vd. - C~ "~=~'' Anchorage, Alaska 99508 ., c' Date Delivered: ,-b~." ~' ~,, U ~L~I ~a., . _`. '~: A`; ~ ~,C~orui9i~i~li.~'s'1 ;p~;. Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth Received by: ~-- • Permit to Drill 2041590 MD 13345...--- À-b ~~ ,lð~ ~ DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 5'pl¿d.. ,z~~~ <f API No. 50-029-22235-02-00 Well Name/No. PRUDHOE BAY UNIT 15-26B Operator BP EXPLORATION (ALASKA) INC TVD 2085"'--' Completion Date 9/26/2004 Current Status 1-01L Completion Status 1-01L UIC N -'- ----- REQUIRED INFORMATION Mud Log No Directional Survey ~... ---.L'--._._~- Samples No -- --_._--~ DATA INFORMATION Types Electric or Other Logs Run: DJR / GR / RES / ASI Well Log Information: Log/ Data Digital Type Med/Frmt ~.. D Asc '17 D Asc ~ ~:: (data taken from Logs Portion of Master Well Data Maint Electr Dataset Number Log Log Interval . Run OH/ Scale Media No Start Stop CH Received Comments 9782 13345 Open 11/9/2004 IIFR 00' i 9782 13345 Open 11/9/2004 IIFR I 9782 13345 Open 11/9/2004 MWD I 9782 13345 Open 11/9/2004 MWD I 9808 13304 Open 11/9/2004 GR/ERW4/ASI/ROP/PWD/ I MWD 9859 13345 Open 2/22/2006 ROP DGR EWR plus I Graphics 12822 Name Directional Survey Directional Survey Directional Survey Directional Survey Gamma Ray 13572 Induction/Resistivity ~~~.~.._..__.._--------' Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received . ADDITIONAL INFORMATION Well Cored? ø --- Chips Received? Y / N Analysis Received? Daily History Received? '(DN &N Formation Tops ~ Comments: ----,~--~-- Compliance Reviewed By: ..#U )ctð~~C(J Date: " RECEIVED . STATE OF ALASKA . SEP 2 9 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT~tSwt~ Cons. Commission c orane 1. Operations Performed: RepairWellŒ Pluç PerforationsD Stimulate 0 OtherD Abandon 0 Alter CasingD Pull TubingD Perforate New PoolD WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryD 20A-1590 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-22235-02-00 7. KS Elevation (ft): 9. Well Name and Number: 61.30 15-268 8. Property Designation: 10. Field/Pool(s): ADL-028306 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 13345 feet true vertical 8819.0 feet Plugs (measured) None Effective Depth measured 13259 feet Junk (measured) None true vertical 8820.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 68 20" 91.5# H-40 47 - 115 47.0 - 115.0 1490 470 SURFACE 77 13-3/8" 68# K-55 46 - 123 46.0 - 123.0 3450 1950 SURFACE 3387 13-3/8" 68# L-80 123 . 3510 123.0 - 3509.0 4930 2270 PRODUCTION 8512 9-5/8" 47# L-80 45 - 8557 45.0 - 8303.0 6870 4760 LINER 1571 7" 29# L-80 8288 - 9859 8132.0 - 8843.0 8160 7020 LINER 28 5-1/2" 17# L-80 8878 - 8906 8479.0 - 8493.0 7740 6280 LINER 4438 4-1/2" 12.6# L-80 8906 - 13344 8493.0 - 8819.0 8430 7500 Perforation depth: Measured depth: 10800-11570,11630-11800,12400-12640,12750-13220 True vertical depth: 8884-8877,8877-8878,8855-8844,8838-8821 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 43 - 8886 Packers & SSSV (type & measured depth): 7" Baker S-3 Packer @ 7869 7" Baker ZXP Liner Top PKR @ 8878 4-1/2" HES X Nipple @ 2085 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft 0 C1 1!31UUô Treatment descriptions including volumes used and final pressure: 13 Representative Dailv AveraQe Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casinç Pressure Tubing Pressure Prior to well operation: 755 33189 0 - 1667 Subsequent to operation: SI 0 0 --- 286 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr " Title Petroleum Engineer Signature A Xo.. Æ_~/J -../ Phone 564-5174 Date 9/28/06 n Form 10-404 Revised 4/2004 ORIGINAL . . 15-26B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/28/2006 ***WELL SHUT-IN UPON ARRIVAL*** (post tree c/o) PULLED P-PRONG . PULLED PX PLUG BODY. RDMO . ***WELL LEFT SII ON DEPARTURE*** 08/15/2006 Set & pulled a 4" ciw twc. tree swap completed & tested. 08/07/2006 { SET PLUG TO CHANGE TREE} TESTED PLUG TO 560 PSI, BLED TUBING DOWN TO 0, RIG DOWN TURN WELL BACK TO DSO. 08/06/2006 TWO UNSUCCESSFUL ATTEMPTS TO SET PX PLUG BODY IN X NIPPLE @ 7897'MD, BRUSHED NIPPLES W/4.5" BLB AND 3.805" GAUGE RING ATTEMPT TO SET PXN PLUG BODY IN XN NIPPLE, DID NOT SET, LOST PLUG, PULL W/ 4.5 GS SET 4.5" PX PLUG BODY (FOUR 1/4" EQU. PORTS) IN X NIPPLE @ 7880' SLM RIH W/4.5" CHECK SET, PIN SHEARED SET 96" 1-7/8" PRONG WI 1.75" F.N. BLEED TUBING OFF TO 0 PSI, 60 PSI AFTER 15 MIN. 08/05/2006 *** WELL SHUT IN ON ARRIVAL*** BRUSH NIPPLES W/4.5" BLB AND 3.805" GAUGE RING UNABLE TO SET 4.5" PX PLUG BODY, TROUBLESHOOT. 08/04/2006 T/I/O= 2000/1500/0, Well kill for Slickline. Pump 5 bbls neat, 275 bbls 1 %KCL, Freeze protect w. 45 bbls Crude, 5 bbls neat.FWHP=0/138010 07/29/2006 TestEvent --- BOPD: 723 BWPD: MCFPD: 30,271 AL Rate: FLUIDS PUMPED BBLS 1 PT Surface Equipment 10 Neat 18 Diesel 48 Crude 275 1 % KCL 352 TOTAL Page 1 TREE = 4-1/8" CAMERON WELLHEAD = FMC ACTUA TOR = AXELSON KB. ELEV = 68' BF. ELEV = ? KOP = 6969' Max Angle = 93 @ 12135' Datum MD = 9986' *" Datum TVO = 8800' SS NOTES: 70° @ 9500' **CAUTlON: MULTIPLE POINTS WHERE WELL CROSSES rvD (8800' SS)** ***CHROME 4-112" TBG*** 15-26B I WHIPSTOCK (09/19/04) I 9859' 2085' "4-1/2" HES X NIP, 10 = 3.813" I 113-3/8" CSG, 68#, L-80, JO = 12.415" I ST MD 4 3140 3 5240 2 6469 1 7696 TVO 3139 5239 6468 7658 GAS LIFT MANDRELS OEV TYÆ VLV LATCH 1 MMG DOI'v1E RK 1 MMG SO RK 4 MMG OMY RK 27 MMG OMY RK PORT DATE 16 09/30/04 20 09/30/04 o 09/26/04 o 09/26/04 113-3/8" CSG, 68#, K-55, 10 = 12.415" I I TOP OF 7" LNR I 8288' 7849' "4-1/2" HES X NIP, ID = 3.813" I 7869' "7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" I 7897' "4-1/2" HES X NIP, 10 = 3.813" Minimum ID = 3.725" @ 8874' 4-1/2" HES XN NIPPLE 19-5/8" CSG, 47#, L-80, ID = 8.681" I 4-1/2"TBG,12.6#, 13CRVAM TOP, .0152 bpf, ID = 3.958" 8886' "4-1/2" HES XN NIP, ID = 3.725" I 7" X 5" BKR ZXP LNR TOP PKR w ITIEBK SL V, 10 = 4.340" -14-1/2" WLEG, ID = 3.958" I 7" X 5" BKR HMC LNR HNGR w / R NIP, 10 = 4.25" MILLOUT WINDOW (15-26B) 9859' - 9871' I 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 14-112" SL TO/SOLID LNR, 12.6#, L-80 H I 2-3/8" SOLID/SL TO LNR, 4.6#, L-80 I I I ~ ÆRFORA TION SUMMARY REF LOG: GR/CCL ON 06/20/92 ANGLE AT TOP ÆRF: 90 @ 10800' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 10800 - 11570 0 09/25/04 2-1/2" 4 11630 - 11800 0 09/25/04 2-1/2" 4 12400 - 12640 0 09/25/04 2-1/2" 4 12750 - 13220 0 09/25/04 IPBTO I 14-1/2" LNR, 12.6#, L-80 BTG-M, .0152 bpf, 10= 3.958" I DATE 1992 05/07/97 09/27/04 09/30/04 02/28/06 08/07/06 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK (15-26A) N2ES SIDETRACK (15-26B) RWUPJC GLV C/O ORF/TLH ORLG DRAFT CORRECTIONS KSB/PJC SET PX PLUG @ 7897' OA TE REV BY COMMENTS 08/28/06 GJF/PAG PULL PX PLUG @ 7897' PRUDHOE BA Y UNrr WELL: 15-26B ÆRMrr No: '2041590 API No: 50-029-22235-02 SEC 22, T11 N, R14E. 4078.66 FEL & 4836.85 FNL BP Exploration (Alaska) . . WELL LOG TRANSMITTAL :;¿ 04 - I ~Scf J 3~7 ;;)- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 RE: MWD Formation Evaluation Logs 15-26B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 15-26B: LAS Data & Digital Log Images: 50-029-22235-02 1 CD Rom ~'~Zo y\~0' . . c:<.o 'f- (S c¡ /2- fr2. 2. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I November 02, 2004 RE: MWD Fonnation Evaluation Logs: 15-26B, AK-MW-3281391 I LDWG fonnatted Disc with verification listing. llPI#: 50-029-22235-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 I BP Exploration (AlaSka) Inc. Petro- T echnicaI Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: /1,/;, !of f ' Si J. . STATE OF ALASKA I ALASKA~L AND GAS CONSERVATION COM bSION WELL COMPLETION OR RECOMPLETION REPORT AND .,LOG Revised: 11/~e1'(Jp~n Production 2D04 1a. Well Status: i8I Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: 20MC 25.105 20MC 25.110 i8I Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/26/2004 2()4..159 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/20/2004 50- 029-22235-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/22/2004 P8U 15-268 1030' SNL, 202' EWL, SEC. 22, T11 N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 426' SNL, 1743' WEL, SEC. 21, T11N, R14E, UM 61.3' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2449' NSL, 1821'WEL, SEC. 16, T11N, R14E, UM 13259 + 8820 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 676130 y- 5960456 Zone- ASP4 13345 + 8819 Ft ADL 028306 TPI: x- 674170 y- 5961014 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 674018 y- 5963886 Zone- ASP4 (Nipple) 2085' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey i8I Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: DIR / GR / RES 1 ABI 22. CASING, LINER AND CEMENTING RECORD ...////~ CASING WT.P~~ tT' .GRÁDE SETTlNê;DEÞTHMD . ßm'N<õPEp'fI:Íi'\ìØ HOL~ 0' SIZE Top BOTTOM TöP BOTTOM SIZE 20" Conductor Surface 115' Surface 115' 13-3/8" 68# K-55/ L-80 Surface 3510' Surface 8509' 16" 1425 $X CS III, 400 $X 'G', Top Job: 200 $X CS II 9-5/8" 47# L-80 Surface 8557' Surface 8305' 12-1/4" 1070 sx Class 'G', 546 sx 'G' 7" 29# L-80 8289' 9859' 8134' 8848' 8-1/2" ~50 sx Class 'G' 4-1/2" 12.6# L-80 8878' 13344' 8479' 8819' 6" 1-489 sx Class 'G' 23. Perforations op'en to Production (MD + TVD of Top and 24. T JBING .... t t/ Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 8886' 7869' MD TVD MD TVD 10800' - 11570' 8884' - 8877' 25. ~Cfì;),âb~";;""'''''''~'''''''';;'~ , .....ËTc::... 11630' - 11800' 8877' - 8878' / 12400' - 12640' 8855' - 8844' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12750' - 13220' 8838' - 8821' 2200' Freeze Protected with 155 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 19, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-MCF W A TER-Bsl CHOKE SIZE I GAS-Oil RATIO 10/28/2004 3.1 TeST PeRIoD .. 335 2965 -0- 45.43 8858 Flow Tubing Casing Pressure CALCULATED .. Oil -Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 1397 1552 24-HoUR RATE 2591 22952 -0- 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS BFL NOV -12004 OR\G\f'JAL GF Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. J ,,: GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were Gonducted, state "None". TDF I Zone 1A 9953' 8858' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram,! Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date 1\- 03-0 PBU 15-26B Well Number Pr'fJpared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Phil Smith, 564-4897 204-159 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternaijng-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is acompJetion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as ieference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00.;00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any mul~iple stage cementing and the location of the cementing tool. . ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval)~ ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ,A' .. STATE OF ALASKA . ocr 1 (~7004 ALAS~ AND GAS CONSERVA TrON COMI ION v t; L WELL COMPLETION OR RECOMPLETION REPORT A.'t1W!:¡ti-OP; 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20MC 25.105 20MC25.110 181 Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/26/2004 204-159 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/20/2004 50- 029-22235-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/22/2004 PBU 15-26B 1030' SNL, 202' EWL, SEC. 22, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 426' SNL, 1743' WEL, SEC. 21, T11N, R14E, UM 61.3' Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 2449' NSL, 1821' WEL, SEC. 16, T11N, R14E, UM 13259 + 8820 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 676130 y- 5960456 Zone- ASP4 13345 + 8819 Ft ADL 028306 TPI: x- 674170 y- 5961014 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 674018 y- 5963886 Zone- ASP4 (Nipple) 2085' MD 18. Directional Survey 19. Water depth. if offshore 20. Thickness of Permafrost 181 Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: DIR I GR I RES I ABI 22. CASING, liNER AND CEMENTING RECORD CASING GRAPe .$mll\l§ I· SETTINßDEPTH rvo ~71~ \ 'PlllhPn SIZE Wn<PERFT. 'Top;" BOTTOM Top BOTToM ;\; ..... .; ;< 20" Conductor Surface 115' Surface 115' 13-3/8" 68# K-55/ L-80 Surface 3510' Surface 8509' 16" 1425 sx CS III, 400 sx 'G', Top Job: 200 sx CS II 9-5/8" 47# L-80 Surface 8557' Surface 8305' 12-1/4" 1070 sx Class 'G', 546 sx 'G' 7" 29# L-80 8289' 9859' 8134' 8848' 8-1/2" 450 sx Class 'G' 4-1/2" 12.6# L-80 8878' 13344' 8479' 8819' 6" 1489 sx Class 'G' 23. Perforations open to Production (MD + TVD of To"e and 24. .T ICI'~¡r.> \ \ Bottom Interval, Size and Number; if none, state none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 8886' 7869' MD TVD MD TVD 10800' - 11570' 8884' - 8877' 25. ""biD,;';';: .._:;. 11630' - 11800' 8877' - 8878' ;"ÿt:;MI;N I, ;\. 12400' - 12640' 8855' - 8844' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12750' -13220' 8838' - 8821' 2200' Freeze Protected with 155 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF W A TER-BBl CHOKE SIZE ì GAS-Oil RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA a'iet des~~~. of I""ology, porosüy, tmetu,"", appa,.nt dips and ","senee of 011, gas 0' wat., <attach sepamle sheet, . necessa",) Submit re:<;:hlp5i,1{flone, state "none". .z&,TE ì None ~~ f.~f DRtGiNAL ú)R0Af; GP ~·""'_-"'-,...".~.,_,.,l ..... '-. -..... -~ A. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE "7 2'8. GEOLOGIC MARKERS 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TDF / Zone 1A 9953' 8858' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date ) Prepared By Name/Number: Terrie Hubble, 564-4628 Drilling Engineer: Phil Smith, 564-4897 PBU 15-26B Well Number 204-159 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 0:01 :48 AM Printed: 9/27/2004 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 9/10/2004 00:00 - 02:00 2.00 MOB P PRE Moved pit module. Prepared rig module for moving. 02:00 - 04:00 2.00 MOB P PRE Moved and spotted rig module over DS 15-26B 04:00 - 05:00 1.00 RIGU P PRE Set in pit module. Raised and pinned derrick. Raised cattle chute. 05:00 - 06:30 1.50 RIGU P PRE Unbridlled and pinned blocks. Hung off blocks and tied off lines. Rigged up floor. 06:30 - 10:30 4.00 RIGU P PRE Spotted cuttings tank. Spotted and connected shops and out buildings. Strung geronimo line. Completed pre-spud check list. 10:30 - 11 :00 0.50 RIGU P PRE Held pre-spud safety meeting. Rig accepted at 10:00. 11 :00 - 11 :30 0.50 WHSUR P DECOMP Rigged up DSM lubricator and pulled BPV. 11 :30 - 12:00 0.50 WHSUR P DECOMP Installed secondary annulus valve and rigged up circulating lines 12:00 - 18:00 6.00 KILL P DECOMP Circulated diesel from well with sea water at 3 BPM with 180 psi. Pumped soap pill and circulated seawater at 13 BPM and 2200 psi. Lost 376 BBLS while circulating. 18:00 - 18:30 0.50 WHSUR P DECOMP Ran BPV and tested from below with 1000 psi. 18:30 - 19:00 0.50 WHSUR P DECOMP Bled off control lines and chemical injection lines. 19:00 - 20:00 1.00 WHSUR P DECOMP Nippled down tree and adaptor flange. Installed blanking plug. 20:00 - 22:00 2.00 BOPSU P DECOMP Installed double stud adaptor and BOPS. 22:00 - 00:00 2.00 BOPSU P DECOMP Pressure testing upper rams and choke manifold to 3500 psi high and 250 psi low. BOP test witness waived by Chuck Shevie - AOGCC. 9/11/2004 00:00 - 02:30 2.50 BOPSU P DECOMP Completed testing upper pipe rams, blind rams, manifold & valves, TIW valve, inside BOP & top drive to 250 psi low and 3500 psi high. Tested annular to 250 psi low and 2500 psi high. Pulled blanking plug and rigged down test joint. 02:30 - 03:30 1.00 BOPSU P DECOMP Rigged up DSM lubricator and pulled BPV. 03:30 - 05:00 1.50 PULL P DECOMP Picked up hanger running tool on 1 joint of 5" DP and engaged hanger. Backed out lock down screws. Picked up and pulled hanger up to rig floor with 77,000 Ibs pick up weight. Had no overpull. Pick up weight correlated to estimated depth of parted tubing at +/- 5178'. Held PJSM to discuss potential corrosion inhibitor inside chemical injection line. Rigged up for spooling injection line and SSSV line. Laid down tubing hanger. 05:00 - 06:00 1.00 PULL P DECOMP Rigged up tubing running equipment and spooling equipment for control lines. Filled hole with 125 BBLS. 06:00 - 15:30 9.50 PULL P DECOMP Held PSJM to discuss laying down tubing. Laid down 31/2" tubing and spooled control line and injection line to SSSV. Laid down SSSV and continued to lay down tubing and injection line to 3485'. Injection line started to slide on tubing. Spooled up remaining injection line, unable to determine quantity of injection line recovered. Rigged down line spooler. Continued laying down 3 1.2" tubing. Recovered 163 joints of tubing, 1 SSSV, 1 GLM and one pup joint parted at the pin end. 167 clamps and pins and 3 steel bands were also recovered. Overall length recovered was 5172'. Top of fish estimated at 5197' (5203' orig RKB). Some corrosion was seen on the tubing joints. The pup joint was extremely corroded with multiple holes. 15:30 - 16:00 0.50 PULL P DECOMP Laid down running tools for tubing. Cleared floor. 16:00 - 16:30 0.50 BOPSU P DECOMP Ran and set test plug in wellhead on 5". 16:30 - 17:00 0.50 BOPSU P DECOMP Tested top and bottom pipe rams and annular with 5" and Printed: 9/27/2004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 tested 5" TIW valve and inside BOP valve to 250 psi and 3500 psi (annular - 2500 psi). 17:00 - 17:30 0.50 BOPSU DECOMP Pulled test plug and installed wear bushing. 17:30 - 18:00 0.50 FISH DECOMP Made up overshot with overshot extension. 18:00 - 22:30 4.50 FISH DECOMP Tripped in hole with overshot picking up 5" DP. Hit obstruction in casing at 4076'. Unable to work through with 25,000 Ibs down. Attempted to wash with 2 to 3000 Ibs and 25 RPM w/o sucess. Had no overpull picking back up. 22:30 - 20:00 21.50 FISH P DECOMP Tripped out of hole with offshot to 1329' at report time. 9/12/2004 00:00 - 01 :30 1.50 FISH P DECOMP Completed pulling out of hole with overshot. Recovered ball of injection line jammed inside overshot bowl. 01 :30 - 02:00 0.50 FISH P DECOMP Leveled rig while wating on wireline spear. 02:00 - 04:00 2.00 FISH P DECOMP Made up wire line spear assembly. Having trouble with tilt arm while picking up 61/2" DCS. 04:00 - 13:00 9.00 FISH N RREP DECOMP Repair tilt arm on top sub. 13:00 - 13:30 0.50 FISH P DECOMP Completed picking up DCS and BHA. 13:30 - 14:30 1.00 FISH P DECOMP Picked up 5" singles to 1372'. 14:30 - 15:30 1.00 P DECOMP Ran in hole to 4076'. Pushed spear to 4090'. Had 10,000 Ibs drag. 15:30 - 17:00 1.50 FISH P DECOMP Pulled out of hole to BHA. 17:00 - 17:30 0.50 FISH P DECOMP Laid down jars and stood back DCS. 17:30 - 18:00 0.50 FISH P DECOMP Broke out wireline spear. Spear was full of tightly balled injection line. 18:00 - 18:30 0.50 FISH P DECOMP Made up new wireline spear. 18:30 - 19:00 0.50 FISH P DECOMP Ran in hole with DCS and picked up jars. 19:00 - 20:00 1.00 FISH P DECOMP Slipped and cut drilling line 20:00 - 21 :30 1.50 FISH P DECOMP Tripped in hole to 4090'. Continued in hole slowly to 4883', drag increased to 10,000 Ibs. 21 :30 - 23:00 1.50 FISH P DECOMP Pulled out of hole to BHA. 23:00 - 23:30 0.50 FISH P DECOMP Laid down jars and stood back DCS. 23:30 - 00:00 0.50 FISH P DECOMP Broke out wireline spear. Spear was 100% full of balled injection line. 9/13/2004 00:00 - 02:00 2.00 FISH P DECOMP Made up new wireline spear. Tripped in hole to 4883'. 02:00 - 02:30 0.50 FISH P DECOMP Engaged chemical injection line and pushed to 5197'- estimated top of fish. Had 10,000 Ibs drag up. 02:30 - 04:30 2.00 FISH P DECOMP Pulled out of hole. Broke out wireline spear. Spear was 100% full of balled injection line. 04:30 - 06:30 2.00 FISH P DECOMP Made up new spear. Tripped in hole to top of fish at 5197'. 06:30 - 07:00 0.50 FISH P DECOMP Worked spear 07:00 - 09:00 2.00 FISH P DECOMP Pooh out of hole. Broke out wireline spear. Recovered +/- 50' of injection line. 09:00 - 10:30 1.50 FISH P DECOMP Made up new spear. Tripped in hole to 4598'. 10:30 - 11 :00 0.50 FISH P DECOMP Serviced rig. 11 :00 - 11 :30 0.50 FISH P DECOMP Tripped in hole to top of fish at 5197'. Worked spear. 11 :30 - 13:30 2.00 FISH P DECOMP Pulled out of hole to BHA. 13:30 - 14:30 1.00 FISH P DECOMP Laid down BHA. No recovery on spear. 14:30 - 15:00 0.50 FISH P DECOMP Cleared floor. 15:00 - 16:30 1.50 FISH P DECOMP Made up short catch overshot. Tripped in hole to 5197'. 16:30 - 17:00 0.50 FISH P DECOMP Engaged fish with overshot. Verified with 15000 Ibs overpull. 17:00 - 20:00 3.00 FISH P DECOMP Rigged up slickline unit. Tested lubricator to 1000 psi. 20:00 - 22:30 2.50 FISH P DECOMP Ran 2.75 impression block. Unable to work thru safety valve. Started running 2.5" impression block. Schlumberger became concerned about getting wireline fish past smaller block. Pulled Printed: 9/27/2004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 9/13/2004 20:00 - 22:30 2.50 FISH P DECOMP LIB. Broke out TIW valve. Installed swab valve and tested with 1000 psi top and 500 psi below. 22:30 - 23:30 1.00 FISH P DECOMP Ran 2.75 impression block with brush sub. Tagged top of fish at 5206' WLM. Worked into top of fish. Tools stopped at 5226' WLM. Pulled impression block. Had small marks on bottom possibly indicating junk from injection line or parted wireline. Had no indication of top of bait sub left in hole. 23:30 - 00:00 0.50 FISH P DECOMP Ran in hole with wireline grab, brush sub and bait sub. 9/14/2004 00:00 - 02:00 2.00 FISH P DECOMP Ran in hole with wireline grab, brush sub and bait sub. Tagged obstruction at 5026'. Worked down and pushed down 6' with slight drag up. Obstruction worked free with no drag. Ran in hole to 8276' WLM (possible top of XN plug), checking pick up weight every 100'. Pulled back up and worked thru spot at 5026' several times w/o drag. Pulled out of hole. No recovery on spear. 02:00 - 03:30 1.50 FISH P DECOMP Made up 2.75" impression block with brush sub. Ran in hole to 8276' to check for junk on top of plug. Pulled impression block. Had good impression of clean XN plug top. 03:30 - 05:00 1.50 PULL P DECOMP Made up equalizing assembly. Ran in hole to equalize pressure accross plug. Attempted to hold pressure on tubing w/o success. Circulated down Dp with 200 psi. Unable to get a pressure or rate change to indicate that plug was equalizing. Pulled tool. Marks on tool showed that equalizer prong had gone down inside XN plug. 05:00 - 07:00 2.00 PULL P DECOMP Run in hole with GR retrieving tool for XN plug. Latch onto XN plug. Attempt to pull free. POH with GR tool - no plug. 07:00 - 10:30 3.50 PULL P DECOMP Run in hole with GR retrieving tool for XN plug. Latch onto XN plug. Jar plug free. POH with GR tool and XN plug 10:30 - 13:00 2.50 PULL P DECOMP PJSM. RU Schlumberger E-line. 13:00 - 15:00 2.00 KILL P DECOMP Rig up to reverse circulate. Reverse circulate - 5 bpm, 350 psi for 3000 strokes (135 bbls). Shut In and flow check the well - stable. 15:00 - 18:00 3.00 PULL P DECOMP RIH with SLB chemical cutter and cut the 3-1/2" 9.2# 13Cr tubing below GLM # 7 @ 8,200' ELM. POH. RD SLB wireline. 18:00 - 18:30 0.50 PULL P DECOMP Pull on the 3-1/2" string in an attempt to pull from the cut. Applied 20K overpull to the string and PU weight went to hanging string weight of 135K. 18:30 - 19:30 1.00 PULL P DECOMP Circulate botoms up. Flow check - stable. 19:30 - 21 :30 2.00 PULL P DECOMP POH from 5,211' to the overshot. 21 :30 - 22:00 0.50 PULL P DECOMP Break and LD short catch overshot, cut joint, GLM #2, 6.05' of parted pup joint - total length 14.69'. 22:00 - 22:30 0.50 FISH P DECOMP MU 3.77' 8-3/8" OD overshot, 1.6' extension, 3.26' extension and XO. 22:30 - 00:00 1.50 FISH P DECOMP RIH with overshot assembly to top of parted tubing stub @ 5,211'. 9/15/2004 00:00 - 03:00 3.00 FISH P DECOMP Attempt to engage fish. Slowly rotated the overshot over the top of the stub. Tubing stub took an intermittent weight of - 5K while attempting to engage. Stopped rotation and downward movement of the overshot - believe the tubing was collapsing while trying to engage. POH and check the overshot. Pulled out -8' of balled up chemical injection line in the bottom of the overshot. LD Overshot and extensions. Clear floor. 03:00 - 04:30 1.50 FISH P DECOMP Service the top drive and slip and cut drilling line. Printed: 9/27/2004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 9/15/2004 04:30 - 06:30 2.00 FISH P DECOMP MU Washover Fishing BHA w/Guide Shoe, Rolling Dog Sub, 2 x joints washpipe, pup joint, boot basket, bumper sub, jars, 9 x drill collars to 376'. 06:30 - 08:30 2.00 FISH P DECOMP RIH with fishing BHA on 5" DP to 5,213'. PU - 150K 08:30 - 09:30 1.00 FISH P DECOMP Engage fish @ 5,213'. Swallow 42' of fish to 5,255'. Latch fish. PU - 175K. 09:30 - 10:30 1.00 FISH P DECOMP Circulate bottoms up at the chemical cut depth - 8,200' ELM. 12 bpm, 600 psi. Monitor well - stable. Blowdown the top drive. 10:30 - 12:30 2.00 FISH P DECOMP POH standing back 5" DP and 9 drill collars from 8,200' (ELM) to 3,045'. 12:30 - 13:00 0.50 FISH P DECOMP LD jars, bumper sub and boot basket to 3,025'. 13:00 - 14:00 1.00 FISH P DECOMP RU 3-1/2" tubing handling equipment. Cut chemical injection line and rig up Camco spooling unit 14:00 - 15:00 1.00 FISH P DECOMP Back out 3-1/2" tubing from washpipe & rolling dog sub. LD remaining fishing tools to 2,945'. 15:00 - 19:00 4.00 FISH P DECOMP LD 3-1/2" completion string from chemical cut from 2,945' to surface. Recovered parted 4.75' corroded L-80 pup, 86 joints of 3-1/2" L-80, 3 joints of 3-1/2" 13Cr, 5 GLM's, 10 SS bands, 91 clamps w/pins and 23.3' cut 13Cr joint. Also recovered slickline fishing tools (bait sub, wire brush, 2 prong wire grab) left in the hole during pre-rig work. 19:00 - 20:00 1.00 FISH P DECOMP Clear and clean the floor. Remove Camco spooling unit. 20:00 - 20:30 0.50 FISH P DECOMP MU Spear BHA #3. Rope Spear, drain sub, bumper sub, oil jar, 9 x drill collars, xo to 313' 20:30 - 22:30 2.00 FISH P DECOMP PU 4" HT40 DP from 313' to 3,397'. 22:30 - 00:00 1.50 FISH P DECOMP RIH with 5" DP from 3,397' to 6,700' 9/16/2004 00:00 - 00:45 0.75 FISH P DECOMP RIH with Spear BHA #3 on 5" DP from 6,700' to 8,198'. PU- 195K, SO - 175K. Tag up on 3-1/2" tubing stub @ 8,198'. 00:45 - 02:00 1.25 FISH P DECOMP Circulate bottoms up @ 12 bpm - 1,000 psi. Blow down top drive. 02:00 - 05:30 3.50 FISH P DECOMP POH with 5" DP from 8,198' to 3,397'. Change out handling equipment. POH w/4" DP from 3,397' to 311 '. Stand back 9 drill collars. POH with jars, bumper sub, drain sub and spear. Upper half of the spear had slickline wrapped around it with the lower half clean. 05:30 - 06:00 0.50 FISH P DECOMP LD Spear and section of balled up slickline. Clear the floor. 06:00 - 06:30 0.50 FISH P DECOMP MU Spear BHA #4 - rope spear, 2 x xo, drain sub, bumper sub, jars, 9 x drill collars, xo - to 307'. 06:30 - 07:30 1.00 FISH P DECOMP RIH with Spear BHA #4 on 4" DP from 307' to 3,492' 07:30 - 08:30 1.00 FISH P DECOMP Lubricate the rig and service the top drive. 08:30 - 10:30 2.00 FISH P DECOMP RIH with 5" DP from 3,492 to 8,184'. PU - 195K, SO - 185K. 10:30 - 11 :00 0.50 FISH P DECOMP RIH from 8,184' to tag the top of the 3-1/2" tubing stub @ 8,200'. Looked to be pushing something ahead. Worked the spear and saw no drag. Monitor the well - stable. Slug pipe and blow down the top drive. 11 :00 - 14:45 3.75 FISH P DECOMP POH with 5" DP from 8,200' to 3,492'. POH with 4" DP from 3,492' to 307'. Stand back BHA. Break and LD Spear assembly - no wire recovered. 14:45 - 15:30 0.75 FISH P DECOMP MU Double Bowl Overshot BHA - double bowl overshot, xo, bumper sub, jars, 9 x drill collars, accelerator jars, xo - to 322'. 15:30 - 18:30 3.00 FISH P DECOMP RIH with Spear BHA #4 on 4" DP from 322' to 3,405'. RIH with 5" DP from 3,405 to 8,200'. PU - 195K, SO - 190K. Printed: 9/27/2004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING f NABORS 2ES Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 9/16/2004 18:30 - 19:00 0.50 FISH P DECOMP Slowly rotated ahead with pumps on - 4.5 bpm, 200 psi. Observed a pressure increase of 150 psi when going over the top of the 3-1/2" tubing stub. Swallowed 5' of the fish. PU on the fish - free - 10K additional weight. 19:00 - 20:00 1.00 FISH P DECOMP Circulate bottoms up. Monitor the well - stable. 20:00 - 23:00 3.00 FISH P DECOMP POH standing back 5" DP from 8,200' to 3,405' (at 18 stands of 5" out, rotated 10 turns to the right in an attempt to hook remaining wireline fish - no additional drag seen). POH standing back the 4" DP from 3,405' to 322'. 23:00 - 00:00 1.00 FISH P DECOMP LD Fishing BHA to the top of the overshot - 322' to 11' 9/17/2004 00:00 - 01 :00 1.00 FISH P DECOMP LD overshot and 20' cut joint. 01 :00 - 02:30 1.50 FISH P DECOMP Clean and clear the floor. Change out the handling equipment for 3-1/2" 13CR 9.2# tubing. 02:30 - 05:00 2.50 FISH P DECOMP Hold PJSM. LD remaining 3-1/2", 9.2#. 13Cr, Fox from 1,705' to surface. Recovered 41 joints 3-1/2", 9.2#, 13Cr tubing + 20' cut joint and overshot. 05:00 - 06:00 1.00 FISH P DECOMP Rig down the tubing handling equipment and clear the floor. 06:00 - 07:30 1.50 FISH P DECOMP MU Spear BHA #5 to 327' - rope spear, drain sub, string magnet, xo, 2 x boot basket, xo, bumper sub, jar, 9 x drill collars, xo. 07:30 - 08:30 1.00 FISH P DECOMP RIH with Spear #5 BHA on 4" DP from 327' to 3,410'. 08:30 - 09:30 1.00 FISH P DECOMP Slip and cut drilling line. 09:30 - 10:30 1.00 FISH P DECOMP RIH with 5" DP from 3,410' to 8,278'. 10:30 - 11 :00 0.50 FISH P DECOMP Circulate at the 7" liner top @ 8,278'. Set down 5K and rotate. PU with no over pull. Repeat 4 times without additional overpull. 11 :00 - 11 :30 0.50 FISH P DECOMP Circulate bottoms up. 11 :30 - 14:30 3.00 FISH P DECOMP POH with 5" DP from 8,278' to 3,410'. POH with 4" DP from 3,410' to 327'. 14:30 - 16:30 2.00 FISH P DECOMP LD Spear BHA #5 from 327'. No recovery of any fish. Clear the floor. 16:30 - 18:30 2.00 FISH P DECOMP MU Mill and Scraper BHA to 1,050' - mill, 2 x boot baskets, scraper, xo, bumper sub, jar, 3 x drill collars, string magnet, 9 x drill collars, 21 x hWdp, xo. 18:30 - 19:30 1.00 FISH P DECOMP Lubricate rig and service the top drive. 19:30 - 23:00 3.50 FISH P DECOMP RIH with 4" DP from 1,050' to 4,132'. PU 4" DP from 4,132' to 5,069'. Change out elevators. RIH with 5" DP from 5,069' to 9,886'. Observed intermittent drag from 9,150' to 9,839'. Set down @ 9,839'. Worked pipe and got obstruction to move down to 9,886' and then had no further progress. 23:00 - 00:00 1.00 FISH P DECOMP Circulate bottoms up - 13 bpm, 3,300 psi. 9/18/2004 00:00 - 04:00 4.00 FISH P DECOMP Pump dry job. POH with 5" DP from 9,886' to 5,069'. Change out the handling equipment. POH with 4" DP from 5,069' to 1,050'. No additional drag seen on trip out of the hole. 04:00 - 06:00 2.00 FISH P DECOMP LD Mill and Scraper BHA from 1,050' - standing back drill collars and HWDP. Clear the floor. Small section of wire recovered in boot basket. 06:00 - 10:30 4.50 PXA P DECOMP MU EZSV BHA. RIH on 4" DP to 4,687'. Change out handling equipment. RIH on 5" from 4,687' to 9,875'. PU - 197K, SO- 185K. 10:30 - 11 :30 1.00 PXA P DECOMP MU cement head pin and break circulation @ 3 bpm, 280 psi. Printed: 9/27/2004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 9/18/2004 10:30 - 11 :30 1.00 PXA P DECOMP Set EZSV @ 9,878'. Shear off EZSV with 48K Overpull. Establish injection rates: 1 bpm - 40 psi 2 bpm - 130 psi 3 bpm - 340 psi 4 bpm - 560 psi 5 bpm - 920 psi 11 :30 - 12:00 0.50 PXA P DECOMP Test the 9-5/8" x 7" casing to 3,500 psi and hold for 30 minutes - good test. 12:00 - 13:15 1.25 PXA P DECOMP Sting into the top of the EZSV @ 9,875'. Set down 25K. Pumped 5 bbls fresh water ahead. Pumped 31.5 bbls of 15.8 ppg + adds cement plug slurry. Pumped 5 bbls fresh water behind. Displace with the rig pumps with 130 bbls of seawater - under displaced. CIP - 1315 hours. 13:15 - 14:00 0.75 PXA P DECOMP Unsting from the EZSV and reverse circulate @ 8.5 bpm - 2,230 psi. 14:00 - 17:30 3.50 PXA P DECOMP POH with 5" DP from 9,875' to 4,672'. Change out handling equipment. POH with 4" DP from 4,672'. LD EZSV setting tool. Clean and clear the floor. 17:30 - 22:30 5.00 BOPSU P DECOMP MU test joint. Pull wear ring. Set test plug. Test BOPE and related equipment to 250 psi/3,500 psi and the annular to 250 psi/2,500 psi. Pull the test plug. Set the wear ring. RD the test joint. Witness of the BOP test was waived by John Crisp of the AOGCC. 22:30 - 00:00 1.50 STWHIP P WEXIT MU Whipstock BHA to 108' - anchor, whipstock, window mill, lower watermelon mill, upper watermelon mill, 1 x HWDP, float sub, mwd. Download MWD tools and shallow test - good test. 9/19/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT MU remaining Whipstock BHA to 1,128' - bumper sub, 12 x drill collars, 21 x HWDP, xo. 01 :30 - 05:30 4.00 STWHIP P WEXIT RIH with whipstock on 4" DP from 1,128' to 5,147'. Change out handling equipment and RIH with 5" DP from 5,147 to 9,805'. Fill pipe every 3,000'. 05:30 - 06:00 0.50 STWHIP P WEXIT Service the top drive and crown. 06:00 - 06:30 0.50 STWHIP P WEXIT Orient 60 degrees RHS. PU - 200K, SO - 180K. Set anchor and shear lug @ 9,877' 06:30 - 07:30 1.00 STWHIP P WEXIT Displace the well over to 8.4 ppg FloPro drilling fluid from seawater. 320 gpm - 1,250 psi. 07:30 - 14:00 6.50 STWHIP P WEXIT Mill 6-1/16" window from 9,859' to 9,871'. Drill new formation to 9,885'. PU - 195K, SO - 175K. TO off - 4K, TO on - 7K. 318 gpm - 1,350 psi. TOW - 9,859' BOW - 9,871' 14:00 - 15:30 1.50 STWHIP P WEXIT Circulate hi-visc sweep and bottoms up while cleaning up the window. 325 gpm - 1,375 psi. Pull into the casing and monitor the well - stable. 15:30 - 16:00 0.50 STWHIP P WEXIT Perform FIT to 10.0 ppg EMW with 8.4 ppg fluid and 735 psi surface pressure at 8,843' TVD. Good test. Pump a dry job and blow down the surface equipment. Remove the blower hose. Printed: 9/27/2004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 9/19/2004 16:00 - 20:00 4.00 STWHIP P WEXIT POH with 5" DP from 9,885' to 5,129'. Change out the handling equipment. POH with 4" DP from 5,129' to 1,110'. 20:00 - 22:00 2.00 STWHIP P WEXIT LD Whipstock BHA from 1,110'. Mills in gauge. Clear the floor. 22:00 - 23:00 1.00 STWHIP P WEXIT Flush the stack, rams, flowline and shakers. Service the wear ring 23:00 - 00:00 1.00 STWHIP P WEXIT MU 6" Drilling BHA to 175' - 6" Security FM2631 RR w/6 x 10's, 5" motor (1.5) 6/7 stage w/ABI,non-mag float sub, GRlRes, DM HOC, TM HOC, 3 x non-nag flex collars, circ sub. 9/20/2004 00:00 - 00:30 0.50 STWHIP P WEXIT Continue MU remaining 6" Drilling BHA to 363' - 3 x HWDP, jar, 2 x HWDP, xo. Shallow test MWD - good test. 00:30 - 02:30 2.00 STWHIP P WEXIT RIH with 6" BHA on 4" DP from the derrick from 363' to 4,380'. Fill pipe every 3,000'. 02:30 - 05:15 2.75 STWHIP P WEXIT PU 4" DP from 4,380' to 8,211'. Fill Pipe every 3,000'. 05: 15 - 06:00 0.75 STWHIP P WEXIT Change out handling equipment. RIH with 5" DP from the derrick from 8,211' to 9,734'. 06:00 - 07:00 1.00 STWHIP P WEXIT Cut and slip 110' of drilling line. Adjust brakes. 07:00 - 08:00 1.00 STWHIP P WEXIT Service the top drive and change out the lube pump. 08:00 - 08:30 0.50 STWHIP P WEXIT Orient BHA to 60 RHS. Slide through window and ream undergauge hole from 9,883' to 9,885'. 08:30 - 00:00 15.50 DRILL P PROD1 Drill 6" hole directionally from 9,885' to 10,630'. PU - 185K, SO - 160K, ROT -175K. TQ off - 5K. AST - 9.28, ART - 0.22. 9/21/2004 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6" hole directionally from 10,630' to 11,632'. PU - 185K, SO - 160K, ROT - 175K. 12:00 - 15:00 3.00 DRILL P PROD1 Circulated bottoms up at 325 GPM with 1850 psi. Monitored well - static. 15:00 - 16:00 1.00 DRILL P PROD1 Short tripped out from 11,632' to 9,859'. Had no excess drag. 16:00 - 16:30 0.50 DRILL P PROD1 Serviced rig and top drive. 16:30 - 17:00 0.50 DRILL P PROD1 Tripped in from 9,859' to 11,632'. No problems. 17:00 - 20:00 3.00 DRILL P PROD1 Directionally drilled 6" hole from 11,632' to 11,917'. PU - 190K, SO - 160 K, RT - 178K. 9/22/2004 00:00 - 12:00 12.00 DRILL P PROD1 Directionally drilled 6" hole from 11917' to 12700'. Sliding for right hand turn. PU - 190K, SO - 160K, RT - 180K 12:00 - 19:30 7.50 DRILL P PROD1 Directionally drilled 6" hole from 12700' to 13345' TMD. Sliding for right hand turn and angle drop. PU - 190K, SO - 160K, RT - 180K 19:30 - 21:00 1.50 DRILL P PROD1 Pumped 50 BBL high viscosity sweep and circulated bottoms up. 21 :30 - 23:00 1.50 DRILL P PROD1 Short tripped 20 stands from 13345 to 11537'. Had 20,000 Ibs overpull at 12545' and 12790'. Tripped back in to 13345' TMD. Had 15000 Ibs drag at 13025'. 23:00 - 00:00 1.00 DRILL P PROD1 Pumped 50 BBL high viscosity sweep. Circulate bottoms up. 9/23/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Circulated high viscosity sweep. Spotted 130 BBLS of clean liner running pill. 01 :30 - 04:30 3.00 DRILL P PROD1 Laid down 5" DP from 13345' to 9829'. (111 stands) 04:30 - 05:30 1.00 DRILL P PROD1 Dropped wiperlrabbit dart and displaced to circulating sub. Sub did not shear. Pulled one stand. Unable to shear sub. 05:30 - 06:00 0.50 DRILL P PROD1 Pump dry job. Pulled wet pipe to 9450'. Opened circulating sub. 06:00 - 09:30 3.50 DRILL P PROD1 Tripped out of hole to BHA to 363'. 09:30 - 11 :00 1.50 DRILL P PROD1 Laid down BHA. Flushed out MWD. Cleared floor. 11 :00 - 12:00 1.00 CASE P RUNPRD Rigged up liner running equipment. 12:00 - 13:00 1.00 CASE P RUNPRD Held PJSM. Picked up float equipment. Checked floats - okay. 13:00 - 16:30 3.50 CASE P RUNPRD Picked up 106 joints of 41/2" 12.6# L-80 BTC-MOD casing to Printed: 9/27/2004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 9/23/2004 13:00 - 16:30 3.50 CASE P RUNPRD 4432' w/ one centralizer every joint. 16:30·17:00 0.50 CASE P RUNPRD Made up 7" X 4.5" HMC Linger Hanger and ZXP Liner Packer. Filled running tool w/ gel. 17:00 - 17:30 0.50 CASE P RUNPRD Picked up 1 stand of DP. Circulated the liner volume to clear floats at 6 BPM w/160 psi. Liner weight = 80K Ibs. 17:30 - 20:00 2.50 CASE P RUNPRD Tripped in hole w/liner to 9859', filling every 10 stands. 20:00 . 20:30 0.50 CASE P RUNPRD Circulated DP and liner volume at 6 BPM w/1300 psi. 20:30 - 22:00 1.50 CASE P RUNPRD Tripped in hole to 13320'. 22:00 - 22:30 0.50 CASE P RUNPRD Rigged up cementing head. Tagged bottom at 13345' TMD. 22:30 - 23:30 1.00 CASE P RUNPRD Staged pump up to 6 BPM with 1300 psi while reciprocating 15'. Had 25,000 Ibs drag with slight increase in pump pressure. Stopped reciprocating and set liner at 13344'. 23:30 - 00:00 0.50 CASE P RUNPRD Continued circulating. Held PJSM with cementers and daylight crew which came on at midnight. 9/24/2004 00:00 - 01 :00 1.00 CEMT P RUNPRD Circulated bottoms up at 6 BPM & 1200 psi while batch mixing cement. 01 :00 - 03:00 2.00 CEMT P RUNPRD Pumped 2 BBLS of water. Pressure tested lines to 4500 psi. Pumped 15 BBLS of 8.34 ppg CW100 flush and 25 BBLS of 9.6 ppg mud push spacer. Pumped 459 sx (98 BBLS) of class G cement w/ additives mixed at 15.8 ppg. Displaced cement with 90 BBLS of perforating pill and 74.5 BBLS of mud. Cement overdisplaced by 0.7 BBLS. Did not bump plug. Attempted to set liner hanger with left hand rotation. Unable to shear pins. Pumped on casing, pressure increased to 4000 psi w/o circulating (plug was on top of landing collar). Sheared pins and set liner hanger and packer. Verified hanger was set. CIP at2:15. 03:00 - 04:00 1.00 CEMT P RUNPRD Pressured DP to 1000 psi and unstung setting tool. Circulated bottoms up at 12 BPM wI 1900 psi. Recovered 40 BBLS of spacer marked wI dye. 04:00 . 05:00 1.00 CEMT P RUNPRD Pumped 50 BBLS high viscosity pill. Displaced wellbore with clean seawater at 12 BPM and 2400 psi. Recovered some cement strung out in mud while displacing. Total sea water used for clean displacement was 860 BBLS. 05:00 - 06:00 1.00 CEMT RUNPRD Laid down cementing head. Pulled 5 stands. 06:00 - 07:00 1.00 CEMT RUNPRD Slipped and cut 100' of drilling line. Inspected brakes. 07:00 - 08:00 1.00 CEMT RUNPRD Serviced rig and top drive. 08:00 - 12:00 4.00 CEMT RUNPRD Tripped out of hole. Laid down liner running tool. Cleared floor. 12:00 - 13:30 1.50 PERFO LOWER1 Held PJSM. Rigged up handling equipment for perforating guns. 13:30 - 14:30 1.00 PERFO LOWER1 Tested liner, liner top and casing to 3500 psi - okay. 14:30·18:00 3.50 PERFO LOWER1 Held PSJM. Maded up 2.5" HSD perforating guns and firing heads with 2 7/8" DP for spacing. 18:00 - 20:30 LOWER1 Tripped in hole picking up 2 7/8" DP to 4427'. Rigged down 2 7/8" handling equipment. 20:30 - 00:00 LOWER1 Tripped in hole with perforating assembly to 12275'. 9/25/2004 00:00 - 01 :00 LOWER1 Tripped in hole with perforating assembly. Tagged landing collar at 13260'. Picked up and position bottom shot at 13220' DPM. 01 :00 - 01 :30 LOWER1 Broke circulation to fill DP and annulus. Closed Hydrill, Pressured annulus to 3000 psi and bled off pressure. Guns fired after 7 minutes and at 8 minutes. Perforated from 10800' - 11570', 11630' - 11800', 12400' - 12640' and 12750' - 13220' Printed: 9/27/2004 10:02:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-26 15-26B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 8/17/2004 Rig Release: 9/26/2004 Rig Number: Spud Date: 12/25/1991 End: 9/26/2004 with 21/2 HSD Power Jet guns with 4 SPF at 60/120 phasing. Had good indication at surface of guns firing. Lost 14 BBLS of fluid. 01 :30 - 03:00 1.50 LOWER1 Pulled out of hole to 10680'. Monitored well. Losing 2 BPH fluid. 03:00 - 07:00 LOWER1 Laid down 4" D to 4427'. 07:00 - 09:00 LOWER1 Changed out running equipment to 2 7/8". Laid down 2 718" DP to 2443' 09:00 - 16:30 LOWER1 Held PSJM. Changed out running equipment for 2 1/2" guns. Laid down guns. Changed equipment. Laid down DP. Changed equipment. Completed laying down guns. 16:30 - 17:30 LOWER1 Ran in hole with 4" and 5" DP in derrick. 17:30 - 20:00 LOWER1 Laid down 4" and 5" DP. 20:00 - 21 :30 RUNCMP Rigged up power tongs, computer and compensator for 4 1/2" chrome completion 21 :30 - 00:00 2.50 RUNCMP Held PSJM. Made up 4 1/2" tail pipe assembly, XN nipple, 23 joints of 41/2" 12.6# 13CR Vam Top, X Nipples & Baker 9 5/8" x 41/2" S-3 permanent packer. Run 41/2" 12.6# 13CR Vam Top tubing and gas lift mandrels to 1534'. Make up torque 4440 ftIlbs. 9/26/2004 00:00 " 09:00 9.00 RUNCMP Continued running 41/2" 12.6 # 13 Chrome tubing completion and tagged tie back sleeve. PU - 125000 Ibs. SO - 120000 Ibs. 09:00 - 10:30 1.50 TUBHGR Spaced out tubing. Rigged down compensator. Made up tubing hanger and landing joint. Landed tubing with WLEG at 8884'. 10:30 - 14:00 RUNCMP Rigged up circulating lines. Reverse circulated 135 BBLS of clean seawater followed by 286 BBLS of inhibited seawater with 25 gal/1 00 BBLS of inhibitor. Circulated at 3 BPM with 150 psi. 14:00 - 15:30 TUBHGR Dropped 1 7/8" ball on rod & let fall to RHC seat in 'XN' nipple. Pressured tubing to 3500 psi and set packer at 7869'. Tested tubing to 3500 psi for 30 minutes - okay. Bled tubing pressure to 0 psi and sheared DCR valve, 15:30 - 16:00 0.50 WHSUR P WHDTRE Set two way check valve in hanger. Tested from below to 1000 psi -okay. 16:00 - 19:30 3.50 WHSUR P WHDTRE Removed BOPS. Installed adapter flange and tree. Test tubing hanger pack-off/ void area to 5000 psi - okay. 19:30 - 20:00 0.50 WHSUR P WHDTRE Tested tree to 5000 psi - okay. 20:00 - 20:30 0.50 WHSUR WHDTRE Rigged up locator. Pulled two way check valve. 20:30 - 22:00 1.50 WHSUR P POST Held PJSM. Rigged up lines and hot oil truck. Tested lines to 3000 psi. Freeze protected by pumping 155 bbls diesel down annulus taking returns up tubing at 3 BPM and 500 psi. 22:00 - 23:00 1.00 WHSUR P POST Let diesel U-tube until balanced for freeze protection to 2200.' 23:00 - 00:00 1.00 DEMOB P POST Rigged down circulating hoses. Set back pressure valve and tested to 1000 psi. Rigged down hot oiler. Removed annular companion valve. Secured well. Released rig at 24:00 hours Printed: 9/27/2004 10:02:26 AM . . 15-0ct-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 15-268 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,782.30' MD 9,859.00' MD 13,345.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date C¡!J/ Ií~~ Signed 1l~ O/JJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 20vf-jJ-Q . Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 15-26B 15 Surveyed: 22 September, 2004 Job No. AKZZ3281391 Survey Report 2004 6 October, . Your Ref: API 500292223502 Surface Coordinates: 5960455.70 N, 676129.67 E (70017' 51.1880" N, 148034' 24.9830 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: svy4402 W) Surface Coordinates relative to Project H Reference: 960455.70 N, 176129.67 E (Grid) Surface Coordinates relative to Structure Reference: 1621.72 N, 130.32 W (True) Kelly Bushing Elevation: 61.30ft above Mean Sea Level Kelly Bushing Elevation: 61.30ft above Project V Reference Kelly Bushing Elevation: 61.30ft above Structure Reference spa""''''''Y-SUi! DAIL.L.I:NG seAVlces A Halliburton Company Halliburton Sperry-Sun Survey Report for P8U_EOA OS 15 - 15-268 Your Ref: API 500292223502 Job No. AKZZ3281391, Surveyed: 22 September, 2004 8PXA 8PXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9782.30 76.400 287.300 8764.60 8825.90 551.55 N 1787.99 W 5960965.20 N 674329.24 E 551.55 Tie On Point MWD+IIFR+MS 9859.00 78.160 287.300 8781.49 8842.79 573.80 N 1859.42 W 5960985.76 N 674257.31 E 2.295 573.80 Window Point 9890.37 79.450 288.370 8787.58 8848.88 583.23 N 1888.72 W 5960994.50 N 674227.80 E 5.301 583.23 9922.16 81.330 289.450 8792.88 8854.18 593.38 N 1918.37 W 5961003.96 N 674197.92 E 6.796 593.38 . 9950.93 83.880 290.420 8796.59 8857.89 603.11 N 1945.19 W 5961013.06 N 674170.88 E 9.473 603.11 9985.57 84.810 291.580 8800.00 8861.30 615.46 N 1977.37 W 5961024.65 N 674138.42 E 4.279 615.46 10016.40 85.240 292.610 8802.67 8863.97 627.02 N 2005.82 W 5961035.54 N 674109.70 E 3.609 627.02 10045.35 85.050 293.580 8805.12 8866.42 638.33 N 2032.36 W 5961046.23 N 674082.91 E 3.402 638.33 10080.05 84.310 295.720 8808.34 8869.64 652.74 N 2063.76 W 5961059.89 N 674051.18 E 6.500 652.74 10110.12 84.620 297.200 8811.24 8872.54 666.08 N 2090.55 W 5961072.60 N 674024.08 E 5.006 666.08 10140.75 84.810 299.040 8814.06 8875.36 680.45 N 2117.45 W 5961086.34 N 673996.85 E 6.014 680.45 10174.14 85.370 300.380 8816.92 8878.22 696.94 N 2146.34 W 5961102.14N 673967.58 E 4.336 696.94 10205.24 86.050 304.210 8819.25 8880.55 713.50 N 2172.55 W 5961118.09N 673940.99 E 12.474 713.50 10234.74 86.790 306.530 8821.09 8882.39 730.55 N 2196.56 W 5961134.57 N 673916.59 E 8.240 730.55 10268.24 87.160 308.160 8822.86 8884.16 750.84 N 2223.15 W 5961154.23 N 673889.53 E 4.983 750.84 10300.35 87.840 310.880 8824.26 8885.56 771.25 N 2247.90 W 5961174.06N 673864.31 E 8.724 771.25 10329.69 88.460 313.480 8825.21 8886.51 790.94 N 2269.63 W 5961193.23 N 673842.13 E 9.106 790.94 10363.86 88.640 314.410 8826.07 8887.37 814.64 N 2294.22 W 5961216.35 N 673816.99 E 2.771 814.64 10395.76 89.630 318.090 8826.55 8887.85 837.68 N 2316.27 W 5961238.87 N 673794.40 E 11.945 837.68 10424.74 89.810 319.140 8826.70 8888.00 859.42 N 2335.43 W 5961260.15 N 673774.74 E 3.676 859.42 10459.10 89.940 323.850 8826.77 8888.07 886.30 N 2356.82 W 5961286.53 N 673752.73 E 13.713 886.30 . 10519.01 90.860 328.070 8826.35 8887.65 935.94 N 2390.35 W 5961335.36 N 673718.05 E 7.209 935.94 10551.58 92.220 330.380 8825.48 8886.78 963.91 N 2407.00 W 5961362.93 N 673700.74 E 8.228 963.91 10583.86 92.220 330.970 8824.23 8885.53 992.03 N 2422.80 W 5961390.68 N 673684.29 E 1.826 992.03 10612.97 92.040 331.600 8823.14 8884.44 1017.54 N 2436.78 W 5961415.85 N 673669.72 E 2.249 1017.54 10648.05 91.540 333.440 8822.05 8883.35 1048.65 N 2452.96 W 5961446.57 N 673652.81 E 5.433 1048.65 10679.73 89.320 334.920 8821.81 8883.11 1077. 16 N 2466.75 W 5961474.75 N 673638.35 E 8.422 1077.16 10708.24 89.810 336.490 8822.03 8883.33 1103.14 N 2478.48 W 5961500.46 N 673626.02 E 5.769 1103.14 10742.54 89.570 337.740 8822.21 8883.51 1134.74N 2491.82 W 5961531.73 N 673611.94 E 3.711 1134.74 10774.52 90.060 340.360 8822.32 8883.62 1164.61 N 2503.25 W 5961561.32 N 673599.81 E 8.335 1164.61 6 October, 2004 . 15:30 Page 2 of 5 OrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-26B Your Ref: API 500292223502 Job No. AKZZ3281391, Surveyed: 22 September, 2004 BPXA BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10803.55 89.630 343.530 8822.39 8883.69 1192.20 N 2512.25 W 5961588.70 N 673590.17 E 11 .020 1192.20 10838.08 90.000 346.080 8822.51 8883.81 1225.52 N 2521.30 W 5961621.80 N 673580.34 E 7.462 1225.52 10869.89 91.300 349.920 8822.14 8883.44 1256.63 N 2527.91 W 5961652.74 N 673573.00 E 12.744 1256.63 10898.88 91.230 349.310 8821.50 8882.80 1285.14 N 2533.13 W 5961681.12N 673567.11 E 2.117 1285.14 10994.23 90.490 346.390 8820.07 8881.37 1378.33 N 2553.20 W 5961773.81 N 673544.87 E 3.159 1378.33 . 11089.58 89.940 345.110 8819.72 8881.02 1470.74 N 2576.67 W 5961865.65 N 673519.24 E 1 .461 1470.74 11183.19 89.820 344.340 8819.91 8881.21 1561.05 N 2601.33 W 5961955.35 N 673492.47 E 0.832 1561.05 11278.85 90.560 344.560 8819.59 8880.89 1653.20 N 2626.97 W 5962046.88 N 673464.67 E 0.807 1653.20 11374.59 90.800 344.690 8818.46 8879.76 1745.51 N 2652.36 W 5962138.57 N 673437.13 E 0.285 1745.51 11468.93 90.930 344.890 8817.03 8878.33 1836.53 N 2677.10 W 5962228.99 N 673410.26 E 0.253 1836.53 11563.23 91.050 345.040 8815.40 8876.70 1927.59 N 2701.56 W 5962319.45 N 673383.67 E 0.204 1927.59 11597.58 89.880 345.710 8815.13 8876.43 1960.83 N 2710.24 W 5962352.47 N 673374.22 E 3.925 1960.83 11629.37 89.440 345.250 8815.31 8876.61 1991.60N 2718.21 W 5962383.05 N 673365.53 E 2.002 1991.60 11658.09 89.440 345.660 8815.60 8876.90 2019.40 N 2725.42 W 5962410.67 N 673357.67 E 1 .428 2019.40 11693.74 89.320 346.480 8815.98 8877.28 2054.00 N 2734.00 W 5962445.06 N 673348.28 E 2.325 2054.00 11724.69 89.440 348.520 8816.32 8877.62 2084.21 N 2740.70 W 5962475.11 N 673340.88 E 6.602 2084.21 11753.84 89.510 348.580 8816.58 8877.88 2112.78 N 2746.48 W 5962503.53 N 673334.42 E 0.316 2112.78 11788.25 90.560 349.520 8816.56 8877.86 2146.56 N 2753.02 W 5962537.15 N 673327.10 E 4.096 2146.56 11820.19 90.990 350.830 8816.13 8877 .43 2178.03 N 2758.47 W 5962568.49 N 673320.91 E 4.316 2178.03 11849.13 91.910 353.010 8815.40 8876.70 2206.67 N 2762.54 W 5962597.02 N 673316.18 E 8.174 2206.67 11884.26 91.360 356.500 8814.40 8875.70 2241.64N 2765.75 W 5962631.90 N 673312.15 E 10.053 2241.64 . 11915.77 91.420 359.700 8813.63 8874.93 2273.12 N 2766.79 W 5962663.35 N 673310.37 E 10.154 2273.12 11944.43 92.530 3.130 8812.64 8873.94 2301.75 N 2766.08 W 5962691.99 N 673310.40 E 12.572 2301.75 11979.02 92.590 8.210 8811.10 8872.40 2336.12 N 2762.67 W 5962726.43 N 673313.01 E 14.673 2336.12 12011.08 92.160 11.920 8809.77 8871.07 2367.65 N 2757.07 W 5962758.09 N 673317.87 E 11.640 2367.65 12040.02 92.900 14.780 8808.49 8869.79 2395.78 N 2750.40 W 5962786.36 N 673323.88 E 10.199 2395.78 12074.23 93.270 18.420 8806.65 8867.95 2428.51 N 2740.64 W 5962819.32 N 673332.87 E 10.680 2428.51 12105.44 93.400 21.500 8804.83 8866.13 2457.79 N 2730.01 W 5962848.84 N 673342.81 E 9.861 2457.79 12134.96 93.460 24.720 8803.07 8864.37 2484.89 N 2718.44 W 5962876.20 N 673353.74 E 10.890 2484.89 12169.49 92.720 25.990 8801.20 8862.50 2516.05 N 2703.68 W 5962907.70 N 673367.77 E 4.252 2516.05 12201.15 92.840 28.230 8799.67 8860.97 2544.20 N 2689.27 W 5962936.17 N 673381.51 E 7.077 2544.20 12230.34 91.600 30.980 8798.54 8859.84 2569.56 N 2674.86 W 5962961.86 N 673395.32 E 10.328 2569.56 12264.95 90.560 33.940 8797.88 8859.18 2598.75 N 2656.29 W 5962991.48 N 673413.21 E 9.063 2598.75 12296.65 91.850 34.250 8797.22 8858.52 2624.99 N 2638.52 W 5963018.14 N 673430.35 E 4.185 2624.99 12325.71 91.300 34.880 8796.42 8857.72 2648.91 N 2622.04 W 5963042.44 N 673446.27 E 2.877 2648.91 6 October, 2004 - 15:30 Page 3 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-26B Your Ref: API 500292223502 Job No. AKZZ3281391, Surveyed: 22 September, 2004 BPXA BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12373.15 92.280 36.500 8794.94 8856.24 2687.42 N 2594.38 W 5963081.58 N 673473.02 E 3.990 2687.42 12419.92 92.470 35.090 8793.00 8854.30 2725.33 N 2567.05 W 5963120.12 N 673499.45 E 3.039 2725.33 12516.16 92.780 34.490 8788.59 8849.89 2804.28 N 2512.20 W 5963200.33 N 673552.44 E 0.701 2804.28 12610.85 92.780 34.830 8784.00 8845.30 2882.07 N 2458.41 W 5963279.37 N 673604.39 E 0.359 2882.07 12706.92 93.390 37.780 8778.83 8840.13 2959.37 N 2401.62 W 5963357.98 N 673659.36 E 3.131 2959.37 . 12801.30 93.090 38.750 8773.49 8834.79 3033.36 N 2343.26 W 5963433.31 N 673715.96 E 1.074 3033.36 12895.18 93.090 36.850 8768.43 8829.73 3107.43 N 2285.81 W 5963508.70 N 673771.66 E 2.021 3107.43 12991.29 91.850 35.010 8764.29 8825.59 3185.17 N 2229.47 W 5963587.75 N 673826.17 E 2.307 3185.17 13086.87 91.170 33.920 8761.77 8823.07 3263.95 N 2175.40 W 5963667.77 N 673878.37 E 1.344 3263.95 13182.41 90.740 33.750 8760.18 8821.48 3343.30 N 2122.21 W 5963748.34 N 673929.69 E 0.484 3343.30 13277.64 90.800 33.880 8758.90 8820.20 3422.41 N 2069.22 W 5963828.68 N 673980.81 E 0.150 3422.41 13345.00 90.800 33.880 8757.96 8819.26 3478.33 N 2031.67 W 5963885.46 N 674017.04 E 0.000 3478.33 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13345.00ft., The Bottom Hole Displacement is 4028.21ft., in the Direction of 329.711 ° (True). . 6 October, 2004 - 15:30 Page 4 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15· 15·26B Your Ref: API 500292223502 Job No. AKZZ3281391, Surveyed: 22 September, 2004 BPXA North Slope Alaska BPXA Comments Measured Depth (It) Station Coordinates TVD Northings Eastings (It) (It) (It) Comment 9782.30 9859.00 13345.00 8825.90 8842.79 8819.26 551.55 N 573.80 N 3478.33 N 1787.99 W 1859.42 W 2031.67 W Tie On Point Window Point Projected Survey . Survey tool program for 15-268 From Measured Vertical Depth Depth (It) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (It) 0.00 9782.30 0.00 9782.30 8825.90 13345.00 8825.90 MWD Magnetic (15-26) 8819.26 MWD+IIFR+MS (15-268) . 6 October, 2004·15:30 Page 5 of 5 DrillQuest 3.03.06.006 . AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . 15-0ct -04 Re: Distribution of Survey Data for Well 15-268 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,782.30' MD 9,859.00 I MD 13,345.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date 9 ~ 6\{' ~'1. Signed .2Lr-¿t ()£4) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ;¿~ Ul-l \4 Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 15 15-26B (mwd) . Job No. AKMW3281391, Surveyed: 22 September, 2004 Survey Report 6 October, 2004 Your Ref: API 500292223502 Surface Coordinates: 5960455.70 N, 676129.67 E (70017' 51.1880" N, 148034' 24.9830" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 960455.70 N, 176129.67 E (Grid) Surface Coordinates relative to Structure Reference: 1621.72 N, 130.32 W (True) Kelly Bushing Elevation: 61.30ft above Mean Sea Level Kelly Bushing Elevation: 61.30ft above Project V Reference Kelly Bushing Elevation: 61.30ft above Structure Reference spal'""1l'""1V-SUil'1 DRIL.L.ING seRVices A Halliburton Company Survey Ref: svy4403 Halliburton Sperry-Sun Survey Report for PBU_EOA OS 15 - 15-26B (mwd) Your Ref: API 500292223502 Job No. AKMW3281391, Surveyed: 22 September, 2004 BPXA BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9782.30 76.400 287.300 8764.60 8825.90 551.55 N 1787.99 W 5960965.20 N 674329.24 E 551.55 Tie On Point 9859.00 78.160 287.300 8781.49 8842.79 573.80 N 1859.42 W 5960985.76 N 674257.31 E 2.295 573.80 Window Point 9890.37 79.450 288.370 8787.58 8848.88 583.23 N 1888.72 W 5960994.50 N 674227.80 E 5.301 583.23 9922.16 81.330 289.450 8792.88 8854.18 593.38 N 1918.37 W 5961003.96 N 674197.92 E 6.796 593.38 9950.93 83.880 297.110 8796.59 8857.89 604.65 N 1944.55 W 5961014.62 N 674171.48 E 27.849 604.65 . 9985.57 84.810 281.920 8800.03 8861.33 616.13 N 1976.95 W 5961025.33 N 674138.83 E 43.718 616.13 10016.40 85.240 305.590 8802.74 8864.04 628.42 N 2004.85 W 5961036.96 N 674110.64 E 76.495 628.42 10045.35 85.050 303.150 8805.19 8866.49 644.70 N 2028.66 W 5961052.68 N 674086.46 E 8.424 644.70 10080.05 84.310 297.190 8808.41 8869.71 662.06 N 2058.52 W 5961069.33 N 674056.20 E 17.234 662.06 10110.12 84.620 295.650 8811.31 8872.61 675.37 N 2085.32 W 5961082.02 N 674029.09 E 5.201 675.37 10140.75 84.810 305.440 8814.14 8875.44 690.86 N 2111.56 W 5961096.88 N 674002.50 E 31.832 690.86 10174.14 85.370 304.720 8816.99 8878.29 709.98 N 2138.78 W 5961115.36 N 673974.84 E 2.726 709.98 10205.24 86.050 305.370 8819.32 8880.62 727.78 N 2164.17 W 5961132.56 N 673949.04 E 3.021 727.78 10234.74 86.790 307.230 8821.16 8882.46 745.21 N 2187.90 W 5961149.43 N 673924.91 E 6.774 745.21 10268.24 87.160 309.270 8822.93 8884.23 765.92 N 2214.17W 5961169.52N 673898.16 E 6.181 765.92 10300.35 87.840 313.890 8824.33 8885.63 787.21 N 2238.16 W 5961190.24N 673873.68 E 14.529 787.21 10329.69 88.460 312.470 8825.28 8886.58 807.27 N 2259.54 W 5961209.80 N 673851.83 E 5.279 807.27 10363.86 88.640 313.630 8826.14 8887.44 830.59 N 2284.50 W 5961232.52 N 673826.33 E 3.434 830.59 10395.76 89.630 317.800 8826.63 8887.93 853.42 N 2306.77 W 5961254.82 N 673803.54 E 13.434 853.42 10424.74 89.810 319.570 8826.77 8888.07 875.18 N 2325.90 W 5961276.13 N 673783.90 E 6.139 875.18 10459.10 89.940 325.320 8826.84 8888.14 902.41 N 2346.83 W 5961302.86 N 673762.33 E 16.739 902.41 . 10519.01 90.860 330.240 8826.42 8887.72 953.08 N 2378.76 W 5961352.77 N 673729.22 E 8.354 953.08 10551.58 92.220 334.980 8825.55 8886.85 981.98 N 2393.74 W 5961381.31 N 673713.58 E 15.135 981.98 10583.86 92.220 331.140 8824.30 8885.60 1010.73 N 2408.35 W 5961409.71 N 673698.30 E 11.887 1010.73 10612.97 92.040 331.050 8823.22 8884.52 1036.19 N 2422.41 W 5961434.84 N 673683.64 E 0.691 1036.19 10648.05 91.540 333.300 8822.12 8883.42 1067.20 N 2438.77 W 5961465.45 N 673666.55 E 6.567 1067.20 10679.73 89.320 335.210 8821.88 8883.18 1095.73 N 2452.53 W 5961493.65 N 673652.13 E 9.244 1095.73 10708.24 89.810 337.160 8822.10 8883.40 1121.81 N 2464.04 W 5961519.46 N 673640.01 E 7.052 1121.81 10742.54 89.570 338.280 8822.28 8883.58 1153.55 N 2477.05 W 5961550.88 N 673626.27 E 3.339 1153.55 10774.52 90.060 341 .040 8822.39 8883.69 1183.53 N 2488.16 W 5961580.60 N 673614.45 E 8.765 1183.53 10803.55 89.630 344.270 8822.47 8883.77 1211.24 N 2496.82 W 5961608.09 N 673605.15 E 11.225 1211.24 10838.08 90.000 347.090 8822.58 8883.88 1244.69 N 2505.36 W 5961641.34N 673595.83 E 8.237 1244.69 10869.89 91.300 350.970 8822.22 8883.52 1275.91 N 2511.41 W 5961672.41 N 673589.05 E 12.863 1275.91 10898.88 91.230 349.790 8821.58 8882.88 1304.49 N 2516.25 W 5961700.86 N 673583.54 E 4.077 1304.49 10994.23 90.490 346.870 8820.14 8881 .44 1397.85 N 2535.53 W 5961793.74 N 673562.07 E 3.159 1397.85 6 October, 2004 - 15:31 Page 2 of 5 OrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-26B (mwd) Your Ref: API 500292223502 Job No. AKMW3281391, Surveyed: 22 September, 2004 BPXA BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11089.58 89.940 346.110 8819.79 8881.09 1490.56 N 2557.81 W 5961885.90 N 673537.63 E 0.984 1490.56 11183.19 89.820 345.170 8819.98 8881.28 1581.24N 2581.02 W 5961976.02 N 673512.30 E 1.012 1581.24 11278.85 90.560 344.740 8819.67 8880.97 1673.62 N 2605.86 W 5962067.79 N 673485.31 E 0.895 1673.62 11374.59 90.800 345.330 8818.53 8879.83 1766.11 N 2630.58 W 5962159.67 N 673458.43 E 0.665 1766.11 11468.93 90.930 345.300 8817.11 8878.41 1857.35 N 2654.49 W 5962250.33 N 673432.38 E 0.141 1857.35 . 11563.23 91.050 345.580 8815.48 8876.78 1948.61 N 2678.19 W 5962341.01 N 673406.55 E 0.323 1948.61 11597.58 89.880 345.940 8815.20 8876.50 1981.90 N 2686.64 W 5962374.10 N 673397.32 E 3.564 1981.90 11629.37 89.440 345.670 8815.39 8876.69 2012.72 N 2694.44 W 5962404.72 N 673388.80 E 1.624 2012.72 11658.09 89.440 345.870 8815.67 8876.97 2040.56 N 2701.50 W 5962432.39 N 673381.09 E 0.696 2040.56 11693.74 89.320 347.160 8816.05 8877.35 2075.23 N 2709.81 W 5962466.85 N 673371.97 E 3.634 2075.23 11724.69 89.440 349.020 8816.39 8877.69 2105.51 N 2716.20 W 5962496.97 N 673364.88 E 6.022 2105.51 11753.84 89.510 349.100 8816.65 8877.95 2134.12 N 2721.73 W 5962525.45 N 673358.67 E 0.365 2134.12 11788.25 90.560 350.260 8816.63 8877.93 2167.98 N 2727.89 W 5962559.15 N 673351.72 E 4.547 2167.98 11820.19 90.990 351.630 8816.20 8877.50 2199.52 N 2732.92 W 5962590.56 N 673345.95 E 4.495 2199.52 11849.13 91.910 353.720 8815.47 8876.77 2228.21 N 2736.61 W 5962619.16 N 673341.59 E 7.888 2228.21 11884.26 91.360 356.750 8814.47 8875.77 2263.20 N 2739.52 W 5962654.07 N 673337.86 E 8.763 2263.20 11915.77 91.420 0.360 8813.70 8875.00 2294.68 N 2740.32 W 5962685.53 N 673336.33 E 11 .455 2294.68 11944.43 92.530 3.550 8812.71 8874.01 2323.31 N 2739.34 W 5962714.17 N 673336.63 E 11.779 2323.31 11979.02 92.590 8.200 8811.17 8872.47 2357.67 N 2735.80 W 5962748.61 N 673339.36 E 13.431 2357.67 12011.08 92.160 12.090 8809.84 8871.14 2389.20 N 2730.16 W 5962780.25 N 673344.26 E 12.197 2389.20 12040.02 92.900 14.930 8808.56 8869.86 2417.30 N 2723.41 W 5962808.51 N 673350.36 E 10.132 2417.30 . 12074.23 93.270 17.690 8806.72 8868.02 2450.09 N 2713.82 W 5962841.51 N 673359.18 E 8.128 2450.09 12105.44 93.400 20.740 8804.90 8866.20 2479.50 N 2703.56 W 5962871.16 N 673368.74 E 9.765 2479.50 12134.96 93.460 23.530 8803.14 8864.44 2506.80 N 2692.46 W 5962898.71 N 673379.20 E 9.436 2506.80 12169.49 92.720 26.120 8801.28 8862.58 2538.09 N 2677.99 W 5962930.33 N 673392.93 E 7.790 2538.09 12201.15 92.840 27.990 8799.74 8861.04 2566.25 N 2663.60 W 5962958.82 N 673406.65 E 5.912 2566.25 12230.34 91.600 29.850 8798.61 8859.91 2591.78 N 2649.50 W 5962984.67 N 673420.16 E 7.654 2591.78 12264.95 90.560 31.800 8797.96 8859.26 2621.49 N 2631.77 W 5963014.79 N 673437.19 E 6.384 2621.49 12296.65 91.850 32.970 8797.29 8858.59 2648.25 N 2614.80 W 5963041.95 N 673453.53 E 5.493 2648.25 12325.71 91.300 34.100 8796.49 8857.79 2672.47 N 2598.75 W 5963066.53 N 673469.00 E 4.323 2672.47 12373.15 92.280 36.230 8795.01 8856.31 2711.23 N 2571.44 W 5963105.92 N 673495.39 E 4.940 2711.23 12419.92 92.470 34.550 8793.07 8854.37 2749.32 N 2544.38 W 5963144.64 N 673521.56 E 3.612 2749.32 12516.16 92.780 34.440 8788.66 8849.96 2828.56 N 2489.93 W 5963225.13 N 673574.13 E 0.342 2828.56 12610.85 92.780 34.640 8784.07 8845.37 2906.47 N 2436.31 W 5963304.27 N 673625.92 E 0.211 2906.47 12706.92 93.390 37.820 8778.90 8840.20 2983.84 N 2379.62 W 5963382.95 N 673680.78 E 3.366 2983.84 6 October, 2004 - 15:31 Page 3 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15· 15·26B (mwd) Your Ref: API 500292223502 Job No. AKMW3281391, Surveyed: 22 September, 2004 BPXA BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12801.30 93.090 38.730 8773.57 8834.87 3057.81 N 2321.25 W 5963458.27 N 673737.39 E 1.014 3057.81 12895.18 93.090 37.090 8768.50 8829.80 3131.77N 2263.65 W 5963533.56 N 673793.24 E 1.744 3131.77 12991.29 91.850 35.350 8764.36 8825.66 3209.23 N 2206.92 W 5963612.33 N 673848.14 E 2.222 3209.23 13086.87 91.170 34.300 8761.84 8823.14 3287.66 N 2152.36 W 5963692.02 N 673900.85 E 1.308 3287.66 13182.41 90.740 33.890 8760.25 8821.55 3366.77 N 2098.81 W 5963772.36 N 673952.53 E 0.622 3366.77 . 13277. 64 90.800 33.960 8758.97 8820.27 3445.78 N 2045.66 W 5963852.59 N 674003.81 E 0.097 3445.78 13345.00 90.800 33.960 8758.03 8819.33 3501.65 N 2008.04 W 5963909.32 N 674040.12 E 0.000 3501.65 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13345.00ft., The Bottom Hole Displacement is 4036.55ft., in the Direction of 330.168° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment . 9782.30 9859.00 13345.00 8825.90 8842.79 8819.33 551.55 N 573.80 N 3501.65 N 1787.99 W 1859.42 W 2008.04 W Tie On Point Window Point Projected Survey 6 October, 2004·15:31 Page 4 of 5 Dri/lQuest 3.03.06.006 8PXA North Slope Alaska Survey tool program for 15-268 (mwd) From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 13345.00 8819.33 Halliburton Sperry-Sun Survey Report for P8U_EOA OS 15 - 15-268 (mwd) Your Ref: API 500292223502 Job No. AKMW3281391, Surveyed: 22 September, 2004 8PXA Survey Tool Description MWD Magnetic (15-26) . . 6 October, 2004 - 15:31 Page 5 of 5 OrillQuest 3.03.06.006 TREE = . FMC GEN 4 WELLHEAD = McBlOY 'ÃëTÜAT6R';-~"'~ AXELSON KB. ELBI = 68' BF. ELBI = ? KOP= Max Angle = Datum MD = Datum lV 0 = 8800' SS . 15-26B A:rv NOTES: ON 09/26/04 DCR sheared & W-M plug installed in XN nipple wI ball/rod on top 113-3/8" CSG, 68#, K-55, 10= 12.415" 2085' H 4-1/2" X NIP, 10 = 3.813" 113-3/8" CSG, 68#, L-80, ID = 12.415" 1 I Minimum ID = 3.725" @ XN 3510' ST 4 3 2 1 MD 3140 5239 6469 7695 lVD 3139 5238 6467 7658 GAS LIFT MANDRELS OBI TYÆ VLV LATCH 1.6' MMG OCR RPK .2' MMG DV RK 3.4' MMG DV RK 25.2' MMG DV RK PORT DATE 4-1/2" X NIP. 10 = 3.813" 7" x 4-1/2" Baker S3 Packer 4-1/2" X NIP, 10 = 3.813" TOP OF 7" LNR I I Cement Retainer 1-1 9875' 4-1/2" XN NIP, 10 = 3.725" 4-1/2" LINER TOP / TBR 4-1/2" WLEG 1-1 7" Top of Window 9-5/8" CSG, 47#, L-80, 10 = 8.681" I 14-1/2" TBG, 12.6.#, 13-CR, .0152 bpf, 10 = 3.958"1-1 8884' ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/2" 6 10050 - 10320 S 03/14/00 4-1/2" 6 10244 -11525 S 01/19/92 4 1/2" Liner Shoe 4 1 /2" Liner PBTD 13344' 13259' 1 TOP OF 4-1/2" LNR H 10028' 1 1 TOP OF 4-1/2" LNR - SL TD I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 4-1/2" LNR, 12.6#, L-80, .0152 bpf,ID=3.958" H 11549' 11450' H "G" LNR TOP - 3-1/2" GS FISHNECK LNR 11481' H 2-3/8" X 3-1/2" XO I 1 2-3/8" LNR, 4.6#, L-80 H DATE 1992 05/07/97 12/14/00 09/26/04 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK COMPLETION SIS-lsl CONVERTED TO CANVAS RB Rig Sidetrack Completion DATE RBI BY COMMENTS PRUDHOE BA Y UNIT WELL: 15-26B ÆRMIT No: 1970170 API No: 50-029-22235-02 SEC 22, T11N, R14E, 4078.66 FEL & 4836.85 FNL BP Exploration (Alaska) AI,ASHA OIL AlQ) GAS CONSERVATION COMMISSION . I / / í / I / , FRANK H. MURKOWSKI, GOVERNOR ~ . Œ (ID~ ~~~~æ~ 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 15-26B BP Exploration (Alaska) Inc. Permit No: 204-159 Surface Location: 1030' SNL, 202' EWL, SEC. 22, T11N, R14E, UM Bottomhole Location: 2418' NSL, 1790' WEL, SEC. 16, T11N, R14E, UM Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission itness any required test. Contact the Commission's petroleum field inspector at (907) 659 60 (pager). BY ORDER OF THE COMMISSION DATED this~day of August, 2004 cc: Department ofFish & Game, Habitat Section w/o end Department of Environmental Conservation w/o encl. WGI\- ~ [I q ¡Z.OOt . STATE OF ALASKA. RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AUG 1 7 2004 20 MC 25.005 ~ Alaska Oil & Gas Cons. Commission o Drill III Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1030' SNL, 202' EWL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 115' NSL, 2259'WEL, SEC. 16, T11N, R14E, UM Total Depth: 2418' NSL, 1790' WEL, SEC. 16, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676130 y- 5960456 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 9900 feet Maximum Hole Angle: 94 dearees ) 11b. Current Well Class 0 Exploratory III Development OiAnllBrMMti>le Zone I 0 Stratigraphic Test 0 Service 0 Development Gas Ir$íñ'{¡Te Zone 5. Bond: a Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU 15·26B /' 6. Proposed Depth: 12. Field / Pool(s): MD 13283 TVD 8836 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028306 8. Land Use Permit: 13. Approximate Spud Date: September 10, 2004 14. Distance to Nearest Property: 22,000' 9. Acres in Property: 2560 6" WeiQht 12.6# Grade L-80 ii CouplinQ Lenath IBT-M 3533' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 61.3 feet 15-05 is 747' away at 11660' MD 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3150 Surface: 2370 iTc~Øttih9~~~'l'))iiii i [... ·.oT MD TVD MD;' TVD (includina staae data) 9750' 8823' 13283' 8836' 387 sx Class 'G' /' 18. .....a....'~ rogram: Size Casina 4-1/2" Hole 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): 12483 8898 None I 12483 8898 !':i7A.· . ~ .... Structural r.nnrlllr.tnr Junk (measured): None . I VI.) 3510' 13-3/8" 1425 sx CS III, 400 sx Class 'G' 3510' 3509' i:=ltA 8557' 9-5/8" 2464 sx Class 'G' 8557' 8305' Production l inAr 2042' 7" 55 sx Class 'G' 8288' - 10330' 8134' - 8899' Liner 1521' 4-1/2" Uncemented 10028' - 11549' 8877' - 8914' Liner 1033' 2-3/8" Uncemented 11450' - 12483' 8915' - 8898' 20. Attachments a Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 8880' - 8898' a Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report a Drilling Fluid Program a 20 AAC 25.050 Requirements Perforation Depth MD (ft): 10050' - 12452' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Lowell Crane Title Senior Drilling Engineer Date: Contact Phil Smith, 564-4897 Prepared By Name/Number: i nature Phone 564-4089 Date Terrie Hubble, 564-4628 Permit To Drill API Number: Permit Approv~IJ I _., . See cover letter for Number: <.0 Çl_ /..(" 9 50- 029-22235-02-00 Date: êlIl.'lI 0 other requirements Conditions of Approval: ~amples Required [J Yes )(No Mud Log Required· 0 Yes ~NO , ~Ydro i.~ulfide Measures .BYes 0 No Directional Survey Required )rYes 0 No Other: ft'~r ßC P.E ¡þçoc p ~:J e-€ý t- c. S I~, cDo &ui I-t 1 lY ¡2t/et..:p('Pn( t:L1)f) (/tlf~) t.L"d~' IC,4'::1 { / .Jt ' APPROVED BY r7. 9 ! ~ L ADDroved B\7 ¿, A I THE COMMISSION Date l' /J / ð.,- Form 10-401 ReVised 06'J1õ04 ~ 0 R \ G \ \\\ f\ L ~Ùbmit 1,( Dup(¡cate · . I Well Name: 115-268 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: X = 676,129.6 Y = 5,960,455.6 /' Estimated 1030' FNL 202' FWL Sec. 22, T11N, R14E Umiat Target Location: X = 673,640.0 Y = 5,961,543.0 TVDss 8830' Ivishak Zone 1 A 115' FSL 3021' FWL Sec. 16, T11N, R14E Umiat / Bottom Hole Location: X = 674,050.0 v.JGIt' Y = 5,963,856.0 TVDss 8775' . 2862' FNL 3490C/, FWL Sec. 16, T11N, R14E Umiat / 111ft) sz:. 80 I Rig: 1 Nabors 2ES ,/ I Operating days to complete: 114.5 I AFE Number: 1 PBD4P2275 1 I Estimated Start Date: 1 09/10/04 ~ 13,283' 1 1 TVD: 18,836' 1 ~132.8' I 1 KB: 128.5' I I KBE: 161.3' I Well Design (conventional, slim hole, etc.): I Single String Horizontal Sidetrack 1 Objective: 1 Ivishak Zone 1 A Formation Markers Formation Tops (wp03) MD TVD TVDss Comments CM2 6731 -6670 ABOVE KICKOFF CMl 7434 -7373 " THRZ 7698 -7637 " LCU 7901 -7840 " TJD " TJC 8018 -7957 " TJB 8072 -8011 " TJA 8164 -81 03 " SAG RIVER 8259 -81 98 " SHUBLIK " TSAD 8368 -8307 " TCGL 8528 -8467 " BCGL 8593 -8532 " TZlB 8810 -8749 TZ1 B = 40' TVD above KOP TDF 9955' 8860 -8799 3150 PSI @ 8800' TV~6:9 PPG EMW BSAD 8897 -8836 Not Penètfatéd TD 13,283 8836 TD Criteria: Reach planned TD unless drillinq conditions deteriorate. fl· ç- ~ 15-26B Permit to Drill Page 1 . . Directional - Sperry wp03 KOP: 19900' MD Maximum Hole Angle: _940 in the 6" horizontal section Close Approach Wells: All wells pass major risk criteria for this well plan. The nearest well is 747' ctr-ctr with 19' allowable deviation. Survey Proç¡ram: MWD Standard + IFR/Cassandra Nearest Property Line: 22,000' to the nearest PBU property line Nearest Well within Pool: 15-05 at 747' center to center at 11,660' planned depth. ram WtlFt Grade Con~ Length Top Btm ./ MDITVD MDITVD 6" 12.6# L-80 IBT-M 3533' 9,750'/8823' 13,283/8836' Tubin 12.6# 13Cr-80 V AM To -9720' GL 9,750/8823' PV <10 Flo Pro PV <10 ""~~ Logging Program 6" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GRlRes/ABI Open Hole: None Cased Hole: None Cement Program Size 4.5" 12.6#, L-80 Production Liner Lead: None Tail: Based on 80' shoe track, 3383' of 4-1/2" X 6" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, and 200' of 7" X 4" DP excess. Tail TOC: 9900' MD (Top of Liner) / Total Cement Volume: Tail 80 bbls, 449 ft3,. 8 sacks Class G @ 15.8 ppg, t,1 ft3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. 15-26B Permit to Drill Page 2 . . Production Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure ,/ Disposal . No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class " wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Complete Procedure SUmmary Current Condition: ./ Confirmed badly corroded tubing with Kinley caliper log 4/26/03. Kinley log nearly stuck at 5180'. ./ Left XXN plug in XN nipple 4/26/04. Plug did not pass pressure test. ./ Passed PPPOT-IC to 3000 psi and tubing to 5000 psi on 4/12/04 ./ Failed combo MITIAxT 7/29/04, possible tubing plug or liner top/packer leak. Scope Pre-RiQ Work: 1. RU Slickline and pull the tubing plug from the XN nipple at 8276'. Drift to as close to the top of 4 W' liner at 10,028' MD as hole inclination will allow (-70° at 9500'). 2. Fluid pack as necessary for cement plug. 3. R/U and RIH with coil tubing and spot an LCM pill in the liner. 4. R/U E-line. RIH with tubing punch and punch holes in the center of the first full joint of tubing above the deepest allowable wireline depth (±9400'). 5. Displace the well to clean seawater by circulating down the tubing through the punched tubing holes. Freeze protect to -2,100' MD with diesel. 6. Bleed casing and annulus pressures to zero. 7. Cycle the tubing hanger LDS. 8. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. RiQ Operations: 1. MI I RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPVfTWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull BPVfTWC. 4. R/U. Pull 3 W' tubing from the seal assembly at 10,028'. 5. RIH wI 6" bit I memory CNUGR and 7" casing scraper to top of 4 W' liner. POH, download CNL data. 6. RIH with 7" cement retainer and set at ±9920' to allow for a 9900' whipstock KOP. Fully cement the liner below the retainer (estimated volume = 25 bbls). 15-26B Permit to Drill Page 3 . . 7. Pressure-test the 9 5/8" casin to 3 500 si for 30 inu 8. P/U and RIH with 7" Baker bottom-trip anchor whip stock assembly. and set on bridge plug. Shear off of whip stock. 9. Displace the well to 8.4 ppg Flo-Pro milling I drilling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 7" casing at ± 9,900' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. / 11. Pull up into 9 5/8" casing and conduct an FIT to 10.5 ppg EMW. POOH. 12. M/U 6" Dir/GR/Res/ABI assembly. 13. RIH, drill build and horizontal section to planned TO, short trip and/or bit trip as necessary. 14. Circulate, short trip, spot liner running pill, POOH. / 15. Run and cement a 4 W', 12.6#, L-80 solid production liner. POOH UD all drill pipe. 16. RIH with 2 7/8" perf guns and perforate ±1000'. 17. R/U and run 41/2",12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. ,// 18. Set a TWC and test to 1000 psi 19. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 20. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 21. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. 22. Rig down and move off. '-rlJ ~ to ~ 40l Ctlff()C(C..)· Orient whip stock, as desired,' ,/' Post-RiQ Work: 1. Install well house and instrumentation 2. MI I RU slick-line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. ,// 3. POP well to test unit until cleaned up. 15-268 Drilling Program Job 1: MIRU Hazards and Contingencies ~ 15-26A is on 60' centers with 15-06 to the north and 15-05 to the south. No well houses will require removal or shut-in for the rig move onto 15-26A. );> DS15 is not designated as an HzS site. Recent H2S data from the pad is as follows: - Well Name H2S ReadinQ Date #1 Closest SHL 15-06A 8 ppm 3/5/2001 #2 Closest SHL 15-05A No data #1 Closest BHL 15-06A 8 ppm 3/5/2001 #2 Closest BHL C-20B No data / Most wells have more than 10 - 20 ppm H2S recorded. The maximum on the pad is DS15- 21A at 50 ppm >- Post Permit to Drill in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies 15-268 Permit to Drill Page 4 . . ~ DS15-26A has severe corrosion below 5200' MD. Above 5200' MD there is no caliper log since the tool nearly became stuck at that depth, presumably in the corrosion holes. The tubing may be parted at that depth, however since a tubing plug was set at 8276' subsequent to the caliper log it is unlikely that the tubing is parted. Pre-rig wireline work will provide more information. ~ The tubing plug has never passed a pressure test and the last combo MIT failed; a 9 5/8" casing leak is a possibility. A 7" tieback will be performed before setting whipstock if necessary. ~ Be prepared to call out a chemical cut in the event the seal assembly does not pull free. Cut the tubing as deep as possible (±9400') to maximize jarring efficiency on the subsequent fishing run to recover the remaining tubing and seal assembly. ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP Job 7: Drill 6" Production Hole Hazards and Contingencies ~ The wellbore is designed to land 5 feet above BSAD and cut up through Zone 1A into Zone 1B at the toe. Slight undulation of the well path may enhance the well's productivity. ~ A single fault crossing is anticipated. This Fault/Ramp may vary in position from 12,000' MD to 12,400' MD. It may be one single fault, or a series of small step faults. The new seismic has difficulty resolving this event. Even though the fault is oriented in a NW -SE direction, lost circulation is not anticipated. ~ The hardline to North limits interference with 15-45A production & a potential fault. ~ KICK TOLERANCI;.:'::ì In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradiel)VÖf ~5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance ~rifin!;~/ "-"...>~/ Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner 15-26B Permit to Drill Page 5 . . Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg mud will be -750psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Schlumberger Cement Program Job 10: DPC Perforate Production CasinQ Hazards and Contingencies ~ Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Schlumberger perforating practices and recommendations. .:. "DPC Perforating" RP -"""*""-'<---""""""""""'- ..;,¡............~- Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the wel1. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease Riç, Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move off of 15-26B. See MIRU section for nearest well. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 15-268 Permit to Drill Page 6 TREE FMC GEN 4 . WELLHEAD = McEVOY 15-26A ~;OTES' 70· @ 9507' & 90· @ 10962' A c;fuA TOR = AXELSON HROME TBG KB. ELEV = 68' BF. ELEV = ? KOP= 6969' / I Max Angle = 94 @ 11863' 2197' 3-1/2" CAMCO TRDP-2A-SSA Datum MD = 9967' . I Datum lVD = 8800' SS SSSV NIP, ID = 2.81" 113-3/8" CSG, 68#, K-55, 10 = 12.415" I 123' GAS LIFT I'v1ANDRELS 1 TOP OF 13-3/8" CSG 1 L ST MD lVD DEV 1YÆ VLV LATCH PORT DATE 123' Y 1 3206 3205 1 MMG-2 RK 113-3/8" CSG, 68#, L-80, 10 = 12.415" I 3510' ~ ~ 2 5206 5205 1 MMG-2 RK 3 6517 6515 4 MMG-2 RK Minimum ID = 1.995" @ 11481' 4 7515 7494 17 MMG-2 RK 5 7888 7826 32 MMG-2 RK TOP 2-3/8" LNR 6 8010 7926 39 MMG-2 RK 7 8168 8045 42 MMG-2 RK 13-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 1 8030' I , I V I TOP OF 3-1/2" TBG 1 8030' V I I 8276' -i 3-1/2" OTIS XN NIP, 10 = 2.75" I I TOP OF 7" LNR 1 8288' l- I 9-5/8" CSG, 47#, L-80, 10 = 8.681" I 8557' µ ~ i ,;:¡ 10018' -i 3-1/2" TIW OVERSHOT SEAL ASSY I I 13-1/2" TBG, 9.2#, 13-CR. .0087 bpf, 10 = 2.992" l-i 10028' 1 l I 10028' -i 3-1/2" TBG TAIL I 1 TOP OF 4-1/2" LNR l-i 10028' 1 II!! . I H ELMO TT NOT LOGGED I ...... 10038' -1 4-1/2" PORTED JOINT (38.61') 1 I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" J 10244' ~ I I TOP OF 4-1/2" LNR - SL TO I 10244' I I I I 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 1 ~ I I 10330' I I .. I I 11450' "G" LNR TOP- 3-1/2" GS FISHNECK LNR I I I TOP SUB W/30' OF 3-1/2 TBG BELOW I TOP OF 2-3/8" LNR 1 11481' I I I I I ~ I 4-1/2" LNR - SL TO H 11525' ~ 11481' H 2-3/8" X 3-1/2" XO I I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I~ 11549' ~ , , , , , , , , , , , , , , , , ÆRFORA TION SUMI'v1ARY , , , , , REF LOG: GRlCCL ON 06/20/92 , , , , , , , ANGLE AT TOP ÆRF: 83@ 10050' , , , , , Note: Refer to Production DB for historical perf data , , , , , , SIZE SPF INTERV AL Opn/Sqz DATE , , , , , , 2-1/2" 6 10050 - 10320 0 03/14/00 , , , , 4-1/2" 6 10244 - 11525 0 01/19/92 , ~ , 12451' ~, } 12-3/8" LNR, 4.6#, L-80, .00387 bpf. 10 = 1.995" H I TO H 12483' ~ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 1992 ORIGINAL COMPLETION 04/27/03 RLITP ADD #7 GLV WELL: 15-26A 05/07/97 SIDETRACK COMPLETION ÆRMIT No: 1970170 12/14/00 SIS-lsl CONVERTED TO CANVAS API No: 50-029-22235-01 01/23/01 SIS-LG REVISION SEC 22, T11 N, R14E, 4078.66 FEL & 4836.85 FNL 03/01/01 SIS-MD FINAL 03/30/02 RNlTP CORRECTIONS BP Exploration (Alaska) TREE = WB..LHEAD = ACTUATOR = KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD = Datum ìVD = FMC GEN 4 McEVOY AXB..SON 68' 1 ~6B Proposed ~NOTES' 880o'SS 2100' H 4-1/2" X NIP, ID = 3.813" 113-3/8" CSG, 68#, K-55, ID = 12.415" I 113-3/8" CSG, 68#, L-8o, ID = 12.415" I 3510' I Minimum ID = 3.725" @ XN GAS LIFT MANDRB..S ST MD ìVD DEV TYÆ VLV LATCH PORT DATE 4 3 2 1 I TOP OF 7" LNR I I Cement Retainer H 9920' 9675' 9695' 9720' 9740' 9750' 9753' 9900' l-f 4-1/2" X NIP, ID = 3.813" 7" x 4-1/2" Baker S3 Packer 4-1/2" X NIP, ID = 3.813" 4-112" XN NIP, ID = 3.725" 4-1/2" LINER TOP / TBR 4-1/2" WLEG l-f 7" Top of Window 9-5/8" CSG. 47#, L-80, ID = 8.681" I 14-1/2" TBG, 12.6.#, 13-CR, .0152 bpf, ID = 3.958"H 9753' ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/2" 6 10050 - 10320 S 03/14/00 4-1/2" 6 10244 - 11525 S 01/19/92 4 1/2" Liner Shoe 4 1 /2" Liner PBTD 13,283' 13,200' I TOP OF 4-1/2" LNR H 10028' I I TOP OF 4-1/2" LNR- SLTD I 7" LNR, 29#, L-80, .0371 bpf. ID = 6.184" I 4-1/2"LNR,12.6#,L-8o,.0152bpf,ID=3.958" H 11549' .1 11450' H "G"LNRTOP-3-1/2"GSFISHNECKLNR 11481' H 2-3/8" X 3-1/2" XO I 12-3/8" LNR, 4.6#, L-8o H DATE 1992 05/07/97 12/14/00 08/09/04 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK COMPLETION SIS-lsl CONVERTED TO CANV AS PGS Proposed Rig Sidetrack DATE REV BY COMMENTS PRUDHOE BAY UNIT WB..L: 15-26B ÆRMIT No: 1970170 API No: 50-029-22235-02 SEC 22, T11N, R14E, 4078.66 FB.. & 4836.85 FNL BP Exploration (Alaska) COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: 15~26B wp03 (15-26IP!an J5-26B) UP Amoco Depth Fro Dcp(h To ~1JNey/Plan T¡)ol CreaiGd By: Troy Jakabosky Date: 81 I 0/2004 9900.00 1J28HJ Plaunoo: 15-26B wp03 VI7 MWDrlF¡~:cMS WELL DETAILS Nmœ +Ní__" +[í-W Northing Eastíng Latil1lde Longitude Slot 15-26 1621.92 -129.32 5960455,70 676129.67 70"17'5U88N !48"34'24.983W N/A CASING DETAiLS SECTION DETAILS No. TVD MD Name Size See MD Inc Azi TVD +NI-S DLeg TFace VSec Target 8836.31 13283.00 4112" 4.500 I 9900.00 79.13 287.56 8850.86 585.80 -1897.79 .....(}.OO 0.00 1458.74 2 9920.00 79.88 289.88 8854.51 592. II -1916.41 r 12.00 72.00 1473.55 3 10312.68 89.84 319.84 8890.47 813.45 -2232.77 8.00 73.34 1823.72 4 10486.08 89.84 319.84 8890.97 945.97 -2344.62 0.00 0.00 1994.46 5 10719.39 90.00 338.50 8891.30 1145.42 -2463.66 8.00 89.52 2226.72 15·268 Tl 6 10747.37 91.09 338.74 8891.03 1171.48 -2473.86 4.00 12.24 2254.38 7 11320.17 91.09 338.74 8880.10 1705.19 -2681.55 0.00 0.00 2820.26 8 11674.49 91.08 360.00 8873.30 2051.36 -2746.53 6.00 89.83 3152.33 15·268 T2 9 12242.23 91.35 34.07 8860.88 2586.1 0 -2582.69 6.00 89.18 3532.74 to 13283.43 91.35 34.07 8836.30 3448.33 -1999.54 0.00 0.00 3986.12 15-268 T3 ""'''' 1VD ';N/~S ~Ei~W Northing Eusting Shape :s ¢: g :::, +' ~ 0, ~ :E g '" No. No COMPANY DETAILS REFERENCE INFORMATION BPAmo;,.'O r~NúI1h Minimum éùrvalure ISCWSA Trav Cylinœr Nocth E¡¡¡ptical~'Casins Rules l3$ed CASING DETAJLS No. TVD MD Name Sìze 8836.31 13283.00 41/2" 4.500 TARGET DETAJLS Name TVD +N/-S +E/-W Northing Shape 15-26B T3 8836.30 3448.33 -1999.54 5963856.00 674050.00 Point 15·268 T2 887330 2051.36 -2746.53 5962442.00 673336.00 Point 15-26B Geo Poly 8890.30 1063.22 ·2541.72 596J459.00 673563.90 Polygon 15-26B T1 8891.30 lJ45.42 -2463.66 596J 543.00 673640.00 Poínt SURVEY PROGRAM Plan: 15-26B wpÚ3 (I5~26/P!an 15-26B) Depth Fm Depth To SUlVey/Plur¡ 9900.00 ! 3283.43 PJauued: ¡ 5~26B ""'Pm V17 Tool Created By: Troy Jakahosky Checked; Date: 8/JO/2004 MWD+IFR+MS Date: R.cviewed: Date> WELL DETAILS N"", i-Ni-S -<-PJ-W Northing Easting Latitude Longitude Slot 15-26 162L92 -12932 5960455.70 676129.67 700!7'5J.188N I 48"34'24.983W NIA SECTION DETAILS See MD 1nc Azi TVD +N/-S +EI-W DLeg TFace VSec Target I 9900.00 79.13 287.56 8850.86 585.80 -1897.79 0.00 0.00 1458.74 2 9920.00 79.88 289.88 8854.51 592. !! -1916.41 12.00 72.00 1473.55 3 10312.68 89.84 319.84 8890.47 813.45 -2232.77 8.00 7334 1823.72 4 10486.08 89.84 319.84 8890.97 945.97 -2344.62 0.00 0.00 1994.46 5 107J 9.39 90.00 33850 8891.30 !!45.42 -2463.66 8.00 89.52 2226.72 I 5-26B T1 6 10747.37 91.09 338.74 8891.03 !! 71.48 -2473.86 4.00 12.24 2254.38 7 !!320.17 91.09 338.74 8880.10 1705.19 -2681.55 0,00 0.00 2820.26 8 11674.49 91.08 360.00 887330 205 L 36 -274653 6.00 89.83 3152.33 I 5-26B T2 9 J2242.23 91.35 34.07 8860.88 2586.!() -2582.69 6.00 89.J8 3532.74 10 13283.43 91.35 34.07 8836.30 3448.33 -199954 0.00 0.00 3986.12 1 5-26B T3 FORMATION TOP DETAILS No. TYDPath MDPath Formation No formation top details fan on the wellpath. '¡;' ð2 <:> <:> ;!. -E g íJ '£ " > ~ . . BP BP Planning Report Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre bggm2004 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Nortbing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: 70 17 Longitude: 148 34 North Reference: Grid Convergence: 35.236 N 21.213 W True 1.34 deg Well: 15-26 Slot Name: 15-26 Well Position: +N/-S 1621.92 ft Nortbing: 5960455.70 ft Latitude: +E/-W -129.32 ft Easting: 676129.67 ft Longitude: Position Uncertainty: 0.00 ft 70 17 51.188 N 148 34 24.983 W Casing Points 0.00 CM3 0.00 0.00 0.00 CM2 0.00 0.00 0.00 CM1 0.00 0.00 0.00 THRZ 0.00 0.00 0.00 BHRZ 0.00 0.00 0.00 TJC 0.00 0.00 0.00 TJB 0.00 0.00 0.00 TJA 0.00 0.00 0.00 TSGR 0.00 0.00 0.00 TSD 0.00 0.00 0.00 TCGL 0.00 0.00 0.00 BCGL 0.00 0.00 0.00 TZ1B 0.00 0.00 0.00 TDF 0.00 0.00 0.00 BSAD 0.00 0.00 15-26B T3 8836.30 3448.33 -1999.54 5963856.00 674050.00 70 18 25.099 N 148 3523.295 W 15-26B T2 8873.30 2051.36 -2746.53 5962442.00 673336.00 70 1811.358 N 148 35 45.065 W 15-26B Geo Poly 8890.30 1063.22 -2541.72 5961459.00 673563.90 70 18 1.640 N 148 35 39.083 W -Polygon 1 8890.30 1063.22 -2541.72 5961459.00 673563.90 70 18 1.640 N 148 3539.083 W -Polygon 2 8890.30 1148.52 -2297.13 5961550.00 673806.40 70 18 2.480 N 148 35 31.954 W -Polygon 3 8890.30 1737.71 -2424.87 5962136.00 673664.90 70 18 8.274 N 148 35 35.683 W -Polygon 4 8890.30 2329.41 -2403.30 5962728.00 673672.60 70 18 14.094 N 148 35 35.060 W -Polygon 5 8890.30 3017.62 -2189.00 5963421.00 673870.70 70 18 20.863 N 148 35 28.817 W -Polygon 6 8890.30 3488.56 -1710.30 5963903.00 674338.20 70 18 25.496 N 148 35 14.860 W -Polygon 7 8890.30 3698.83 -1974.66 5964107.00 674069.00 70 18 27.563 N 148 35 22.572 W . . BP BP Planning Report -Polygon 8 8890.30 3463.58 -2479.64 5963860.00 673569.70 70 18 25.248 N 148 3537.297 W -Polygon 9 8890.30 2897.94 -2801.91 5963287.00 673260.80 70 18 19.684 N 148 3546.689 W -Polygon 10 8890.30 2604.30 -2778.48 5962994.00 673291.10 70 18 16.796 N 148 35 46.002 W -Polygon 11 8890.30 2112.00 -2901.16 5962499.00 673180.00 70 1811.954 N 148 3549.574 W -Polygon 12 8890.30 1604.98 -2822.12 5961994.00 673270.90 70 18 6.968 N 148 35 47.264 W -Polygon 13 8890.30 1063.22 -2541.72 5961459.00 673563.90 70 18 1.640 N 148 35 39.083 W 15-26B T1 8891.30 1145.42 -2463.66 5961543.00 673640.00 70 18 2.449 N 148 3536.809 W Plan Section Information 9900.00 79.13 287.56 8850.86 585.80 -1897.79 0.00 0.00 0.00 0.00 9920.00 79.88 289.88 8854.51 592.11 -1916.41 12.00 3.75 11.59 72.00 10312.68 89.84 319.84 8890.47 813.45 -2232.77 8.00 2.54 7.63 73.34 10486.08 89.84 319.84 8890.97 945.97 -2344.62 0.00 0.00 0.00 0.00 10719.39 90.00 338.50 8891.30 1145.42 -2463.66 8.00 0.07 8.00 89.52 15-26B T1 10747.37 91.09 338.74 8891.03 1171.48 -2473.86 4.00 3.91 0.85 12.24 11320.17 91.09 338.74 8880.10 1705.19 -2681.55 0.00 0.00 0.00 0.00 11674.49 91.08 360.00 8873.30 2051.36 -2746.53 6.00 0.00 6.00 89.83 15-26B T2 12242.23 91.35 34.07 8860.88 2586.10 -2582.69 6.00 0.05 6.00 89.18 13283.43 91.35 34.07 8836.30 3448.33 -1999.54 0.00 0.00 0.00 0.00 15-268 T3 Survey 9900.00 79.13 287.56 8850.86 8789.56 585.80 -1897.79 0.00 5960996.83 674218.80 Start Dir 12/10 9920.00 79.88 289.88 8854.51 8793.21 592.11 -1916.41 12.00 5961002.70 674200.03 Start Dir 8/100 9925.00 79.99 290.27 8855.38 8794.08 593.80 -1921.03 8.00 5961004.28 674195.37 MWD+IFR+MS 9950.00 80.57 292.21 8859.60 8798.30 602.73 -1944.00 8.00 5961012.67 674172.20 MWD+IFR+MS 9975.00 81.17 294.15 8863.57 8802.27 612.44 -1966.69 8.00 5961021.85 674149.30 MWD+IFR+MS 10000.00 81.77 296.07 8867.28 8805.98 622.94 -1989.08 8.00 5961031.81 674126.67 MWD+IFR+MS 10025.00 82.38 298.00 8870.72 8809.42 634.19 -2011.13 8.00 5961042.54 674104.36 MWD+IFR+MS 10050.00 83.00 299.91 8873.91 8812.61 646.19 -2032.82 8.00 5961054.04 674082.39 MWD+IFR+MS 10075.00 83.63 301.83 8876.82 8815.52 658.93 -2054.14 8.00 5961066.27 674060.79 MWD+IFR+MS 10100.00 84.26 303.73 8879.46 8818.16 672.39 -2075.04 8.00 5961079.24 674039.58 MWD+IFR+MS 10125.00 84.90 305.64 8881.82 8820.52 686.56 -2095.50 8.00 5961092.91 674018.79 MWD+IFR+MS 10150.00 85.55 307.54 8883.90 8822.60 701.40 -2115.50 8.00 5961107.29 673998.45 MWD+IFR+MS 10175.00 86.20 309.43 8885.70 8824.40 716.92 -2135.02 8.00 5961122.34 673978.57 MWD+IFR+MS 10200.00 86.85 311.33 8887.21 8825.91 733.09 -2154.03 8.00 5961138.06 673959.19 MWD+IFR+MS 10225.00 87.51 313.22 8888.44 8827.14 749.88 -2172.50 8.00 5961154.41 673940.33 MWD+IFR+MS 10250.00 88.17 315.11 8889.39 8828.09 767.29 -2190.43 8.00 5961171.39 673922.01 MWD+IFR+MS 10275.00 88.84 316.99 8890.04 8828.74 785.28 -2207.77 8.00 5961188.97 673904.25 MWD+IFR+MS 10300.00 89.50 318.88 8890.40 8829.10 803.83 -2224.52 8.00 5961207.13 673887.07 MWD+IFR+MS 10312.68 89.84 319.84 8890.47 8829.17 813.45 -2232.77 8.00 5961216.55 673878.59 End Dir : 1031 10325.00 89.84 319.84 8890.51 8829.21 822.87 -2240.72 0.00 5961225.78 673870.43 MWD+IFR+MS 10350.00 89.84 319.84 8890.58 8829.28 841.98 -2256.84 0.00 5961244.50 673853.86 MWD+IFR+MS 10375.00 89.84 319.84 8890.65 8829.35 861.08 -2272.97 0.00 5961263.22 673837.29 MWD+IFR+MS 10400.00 89.84 319.84 8890.72 8829.42 880.19 -2289.09 0.00 5961281.94 673820.73 MWD+IFR+MS 10425.00 89.84 319.84 8890.79 8829.49 899.29 -2305.22 0.00 5961300.66 673804.16 MWD+IFR+MS 10450.00 89.84 319.84 8890.86 8829.56 918.40 -2321.34 0.00 5961319.38 673787.59 MWD+IFR+MS 10475.00 89.84 319.84 8890.93 8829.63 937.50 -2337.47 0.00 5961338.10 673771.03 MWD+IFR+MS 10486.08 89.84 319.84 8890.97 8829.67 945.97 -2344.62 0.00 5961346.40 673763.68 Start Dir 8/100 10500.00 89.85 320.95 8891.00 8829.70 956.69 -2353.49 8.00 5961356.91 673754.56 MWD+IFR+MS 10525.00 89.86 322.95 8891.07 8829.77 976.38 -2368.90 8.00 5961376.23 673738.70 MWD+IFR+MS . . BP BP Planning Report 10550.00 89.88 324.95 8891.12 8829.82 996.59 -2383.61 8.00 5961396.09 673723.52 MWD+IFR+MS 10575.00 89.90 326.95 8891.17 8829.87 1017.30 -2397.60 8.00 5961416.47 673709.04 MWD+IFR+MS 10600.00 89.92 328.95 8891.21 8829.91 1038.49 -2410.87 8.00 5961437.34 673695.28 MWD+IFR+MS 10625.00 89.93 330.95 8891.24 8829.94 1060.13 -2423.39 8.00 5961458.68 673682.26 MWD+IFR+MS 10650.00 89.95 332.95 8891.27 8829.97 1082.19 -2435.15 8.00 5961480.45 673669.99 MWD+IFR+MS 10675.00 89.97 334.95 8891.29 8829.99 1104.65 -2446.12 8.00 5961502.65 673658.49 MWD+IFR+MS 10700.00 89.99 336.95 8891.30 8830.00 1127.48 -2456.31 8.00 5961525.23 673647.77 MWD+IFR+MS 10719.39 90.00 338.50 8891.30 8830.00 1145.42 -2463.66 8.00 5961543.00 673640.00 15-26B T1 10725.00 90.22 338.55 8891.29 8829.99 1150.64 -2465.72 4.00 5961548.17 673637.83 MWD+IFR+MS 10747.37 91.09 338.74 8891.03 8829.73 1171.48 -2473.86 4.00 5961568.80 673629.19 End Dir : 1074 10750.00 91.09 338.74 8890.98 8829.68 1173.92 -2474.82 0.00 5961571.23 673628.18 MWD+IFR+MS 10775.00 91.09 338.74 8890.51 8829.21 1197.22 -2483.88 0.00 5961594.30 673618.58 MWD+IFR+MS 10800.00 91.09 338.74 8890.03 8828.73 1220.51 -2492.95 0.00 5961617.37 673608.97 MWD+IFR+MS 10825.00 91.09 338.74 8889.55 8828.25 1243.80 -2502.01 0.00 5961640.45 673599.36 MWD+IFR+MS 10850.00 91.09 338.74 8889.07 8827.77 1267.10 -2511.07 0.00 5961663.52 673589.75 MWD+IFR+MS 10875.00 91.09 338.74 8888.60 8827.30 1290.39 -2520.14 0.00 5961686.59 673580.15 MWD+IFR+MS 10900.00 91.09 338.74 8888.12 8826.82 1313.69 -2529.20 0.00 5961709.67 673570.54 MWD+IFR+MS 10925.00 91.09 338.74 8887.64 8826.34 1336.98 -2538.27 0.00 5961732.74 673560.93 MWD+IFR+MS 10950.00 91.09 338.74 8887.17 8825.87 1360.27 -2547.33 0.00 5961755.82 673551.32 MWD+IFR+MS 10975.00 91.09 338.74 8886.69 8825.39 1383.57 -2556.40 0.00 5961778.89 673541.72 MWD+IFR+MS 11000.00 91.09 338.74 8886.21 8824.91 1406.86 -2565.46 0.00 5961801.96 673532.11 MWD+IFR+MS 11025.00 91.09 338.74 8885.73 8824.43 1430.16 -2574.53 0.00 5961825.04 673522.50 MWD+IFR+MS 11050.00 91.09 338.74 8885.26 8823.96 1453.45 -2583.59 0.00 5961848.11 673512.90 MWD+IFR+MS 11075.00 91.09 338.74 8884.78 8823.48 1476.74 -2592.65 0.00 5961871.18 673503.29 MWD+IFR+MS 11100.00 91.09 338.74 8884.30 8823.00 1500.04 -2601.72 0.00 5961894.26 673493.68 MWD+IFR+MS 11125.00 91.09 338.74 8883.82 8822.52 1523.33 -2610.78 0.00 5961917.33 673484.07 MWD+IFR+MS 11150.00 91.09 338.74 8883.35 8822.05 1546.63 -2619.85 0.00 5961940.40 673474.47 MWD+IFR+MS 11175.00 91.09 338.74 8882.87 8821.57 1569.92 -2628.91 0.00 5961963.48 673464.86 MWD+IFR+MS 11200.00 91.09 338.74 8882.39 8821.09 1593.21 -2637.98 0.00 5961986.55 673455.25 MWD+IFR+MS 11225.00 91.09 338.74 8881.92 8820.62 1616.51 -2647.04 0.00 5962009.63 673445.64 MWD+IFR+MS 11250.00 91.09 338.74 8881.44 8820.14 1639.80 -2656.11 0.00 5962032.70 673436.04 MWD+IFR+MS 11275.00 91.09 338.74 8880.96 8819.66 1663.10 -2665.17 0.00 5962055.77 673426.43 MWD+IFR+MS 11300.00 91.09 338.74 8880.48 8819.18 1686.39 -2674.23 0.00 5962078.85 673416.82 MWD+IFR+MS 11320.17 91.09 338.74 8880.10 8818.80 1705.19 -2681.55 0.00 5962097.46 673409.07 Start Dir 611 00 11325.00 91.09 339.03 8880.01 8818.71 1709.69 -2683.29 6.00 5962101.92 673407.23 MWD+IFR+MS 11350.00 91.10 340.53 8879.53 8818.23 1733.14 -2691.93 6.00 5962125.17 673398.04 MWD+IFR+MS 11375.00 91.10 342.03 8879.05 8817.75 1756.81 -2699.95 6.00 5962148.64 673389.46 MWD+IFR+MS 11400.00 91.10 343.53 8878.57 8817.27 1780.69 -2707.35 6.00 5962172.34 673381.51 MWD+IFR+MS 11425.00 91.11 345.03 8878.09 8816.79 1804.75 -2714.12 6.00 5962196.23 673374.17 MWD+IFR+MS 11450.00 91.11 346.53 8877.60 8816.30 1828.98 -2720.26 6.00 5962220.31 673367.47 MWD+IFR+MS 11475.00 91.11 348.03 8877.12 8815.82 1853.36 -2725.77 6.00 5962244.55 673361.39 MWD+IFR+MS 11500.00 91.11 349.53 8876.64 8815.34 1877.87 -2730.63 6.00 5962268.94 673355.96 MWD+IFR+MS 11525.00 91.10 351.03 8876.16 8814.86 1902.51 -2734.85 6.00 5962293.47 673351.16 MWD+IFR+MS 11550.00 91.10 352.53 8875.67 8814.37 1927.25 -2738.43 6.00 5962318.12 673347.01 MWD+IFR+MS 11575.00 91.10 354.03 8875.19 8813.89 1952.07 -2741.35 6.00 5962342.86 673343.50 MWD+IFR+MS 11600.00 91.10 355.53 8874.71 8813.41 1976.96 -2743.63 6.00 5962367.69 673340.64 MWD+IFR+MS 11625.00 91.09 357.03 8874.24 8812.94 2001.90 -2745.25 6.00 5962392.59 673338.44 MWD+IFR+MS 11650.00 91.09 358.53 8873.76 8812.46 2026.88 -2746.22 6.00 5962417.53 673336.89 MWD+IFR+MS 11675.00 91.08 0.03 8873.29 8811.99 2051.87 -2746.53 6.00 5962442.51 673335.99 MWD+IFR+MS 11700.00 91.10 1.53 8872.81 8811.51 2076.86 -2746.19 6.00 5962467.50 673335.74 MWD+IFR+MS 11725.00 91.12 3.03 8872.33 8811.03 2101.84 -2745.19 6.00 5962492.49 673336.15 MWD+IFR+MS 11750.00 91.14 4.53 8871.84 8810.54 2126.78 -2743.55 6.00 5962517.46 673337.21 MWD+IFR+MS . . BP BP Planning Report 11775.00 91.16 6.03 8871.33 8810.03 2151.67 -2741.25 6.00 5962542.40 673338.93 MWD+IFR+MS 11800.00 91.18 7.53 8870.82 8809.52 2176.49 -2738.29 6.00 5962567.28 673341.30 MWD+IFR+MS 11825.00 91.19 9.03 8870.31 8809.01 2201.22 -2734.69 6.00 5962592.08 673344.32 MWD+IFR+MS 11850.00 91.21 10.53 8869.78 8808.48 2225.85 -2730.45 6.00 5962616.81 673347.99 MWD+IFR+MS 11875.00 91.23 12.03 8869.25 8807.95 2250.36 -2725.56 6.00 5962641.42 673352.30 MWD+IFR+MS 11900.00 91.24 13.53 8868.71 8807.41 2274.74 -2720.03 6.00 5962665.92 673357.26 MWD+IFR+MS 11925.00 91.26 15.03 8868.17 8806.87 2298.96 -2713.86 6.00 5962690.28 673362.85 MWD+IFR+MS 11950.00 91.27 16.53 8867.62 8806.32 2323.01 -2707.06 6.00 5962714.48 673369.09 MWD+IFR+MS 11975.00 91.28 18.03 8867.06 8805.76 2346.87 -2699.64 6.00 5962738.51 673375.95 MWD+IFR+MS 12000.00 91.29 19.53 8866.50 8805.20 2370.53 -2691.59 6.00 5962762.35 673383.44 MWD+IFR+MS 12025.00 91.30 21.03 8865.93 8804.63 2393.98 -2682.93 6.00 5962785.99 673391.55 MWD+IFR+MS 12050.00 91.31 22.53 8865.36 8804.06 2417.18 -2673.65 6.00 5962809.41 673400.28 MWD+IFR+MS 12075.00 91.32 24.03 8864.79 8803.49 2440.14 -2663.77 6.00 5962832.59 673409.62 MWD+IFR+MS 12100.00 91.33 25.54 8864.21 8802.91 2462.83 -2653.29 6.00 5962855.52 673419.56 MWD+IFR+MS 12125.00 91.33 27.04 8863.63 8802.33 2485.24 -2642.23 6.00 5962878.18 673430.10 MWD+IFR+MS 12150.00 91.34 28.54 8863.05 8801.75 2507.35 -2630.58 6.00 5962900.55 673441.23 MWD+IFR+MS 12175.00 91.34 30.04 8862.46 8801.16 2529.15 -2618.35 6.00 5962922.63 673452.94 MWD+IFR+MS 12200.00 91.35 31.54 8861.88 8800.58 2550.62 -2605.56 6.00 5962944.39 673465.22 MWD+IFR+MS 12225.00 91.35 33.04 8861.29 8799.99 2571.75 -2592.21 6.00 5962965.83 673478.07 MWD+IFR+MS 12242.23 91.35 34.07 8860.88 8799.58 2586.10 -2582.69 6.00 5962980.40 673487.26 End Dir : 1224 12250.00 91.35 34.07 8860.70 8799.40 2592.54 -2578.34 0.00 5962986.93 673491.45 MWD+IFR+MS 12275.00 91.35 34.07 8860.11 8798.81 2613.24 -2564.33 0.00 5963007.96 673504.97 MWD+IFR+MS 12300.00 91.35 34.07 8859.52 8798.22 2633.94 -2550.33 0.00 5963028.98 673518.48 MWD+IFR+MS 12325.00 91.35 34.07 8858.93 8797.63 2654.64 -2536.33 0.00 5963050.00 673531.99 MWD+IFR+MS 12350.00 91.35 34.07 8858.34 8797.04 2675.35 -2522.33 0.00 5963071.03 673545.50 MWD+IFR+MS 12375.00 91.35 34.07 8857.75 8796.45 2696.05 -2508.33 0.00 5963092.05 673559.01 MWD+IFR+MS 12400.00 91.35 34.07 8857.16 8795.86 2716.75 -2494.32 0.00 5963113.08 673572.52 MWD+IFR+MS 12425.00 91.35 34.07 8856.57 8795.27 2737.46 -2480.32 0.00 5963134.10 673586.04 MWD+IFR+MS 12450.00 91.35 34.07 8855.98 8794.68 2758.16 -2466.32 0.00 5963155.12 673599.55 MWD+IFR+MS 12475.00 91.35 34.07 8855.38 8794.08 2778.86 -2452.32 0.00 5963176.15 673613.06 MWD+IFR+MS 12500.00 91.35 34.07 8854.79 8793.49 2799.56 -2438.32 0.00 5963197.17 673626.57 MWD+IFR+MS 12525.00 91.35 34.07 8854.20 8792.90 2820.27 -2424.32 0.00 5963218.19 673640.08 MWD+IFR+MS 12550.00 91.35 34.07 8853.61 8792.31 2840.97 -2410.31 0.00 5963239.22 673653.60 MWD+IFR+MS 12575.00 91.35 34.07 8853.02 8791.72 2861.67 -2396.31 0.00 5963260.24 673667.11 MWD+IFR+MS 12600.00 91.35 34.07 8852.43 8791.13 2882.37 -2382.31 0.00 5963281.27 673680.62 MWD+IFR+MS 12625.00 91.35 34.07 8851.84 8790.54 2903.08 -2368.31 0.00 5963302.29 673694.13 MWD+IFR+MS 12650.00 91.35 34.07 8851.25 8789.95 2923.78 -2354.31 0.00 5963323.31 673707.64 MWD+IFR+MS 12675.00 91.35 34.07 8850.66 8789.36 2944.48 -2340.30 0.00 5963344.34 673721.16 MWD+IFR+MS 12700.00 91.35 34.07 8850.07 8788.77 2965.18 -2326.30 0.00 5963365.36 673734.67 MWD+IFR+MS 12725.00 91.35 34.07 8849.48 8788.18 2985.89 -2312.30 0.00 5963386.38 673748.18 MWD+IFR+MS 12750.00 91.35 34.07 8848.89 8787.59 3006.59 -2298.30 0.00 5963407.41 673761.69 MWD+IFR+MS 12775.00 91.35 34.07 8848.30 8787.00 3027.29 -2284.30 0.00 5963428.43 673775.20 MWD+IFR+MS 12800.00 91.35 34.07 8847.71 8786.41 3048.00 -2270.30 0.00 5963449.46 673788.72 MWD+IFR+MS 12825.00 91.35 34.07 8847.12 8785.82 3068.70 -2256.29 0.00 5963470.48 673802.23 MWD+IFR+MS 12850.00 91.35 34.07 8846.53 8785.23 3089.40 -2242.29 0.00 5963491.50 673815.74 MWD+IFR+MS 12875.00 91.35 34.07 8845.94 8784.64 3110.10 -2228.29 0.00 5963512.53 673829.25 MWD+IFR+MS 12900.00 91.35 34.07 8845.35 8784.05 3130.81 -2214.29 0.00 5963533.55 673842.76 MWD+IFR+MS 12925.00 91.35 34.07 8844.76 8783.46 3151.51 -2200.29 0.00 5963554.58 673856.27 MWD+IFR+MS 12950.00 91.35 34.07 8844.17 8782.87 3172.21 -2186.28 0.00 5963575.60 673869.79 MWD+IFR+MS 12975.00 91.35 34.07 8843.58 8782.28 3192.91 -2172.28 0.00 5963596.62 673883.30 MWD+IFR+MS 13000.00 91.35 34.07 8842.99 8781.69 3213.62 -2158.28 0.00 5963617.65 673896.81 MWD+IFR+MS 13025.00 91.35 34.07 8842.40 8781.10 3234.32 -2144.28 0.00 5963638.67 673910.32 MWD+IFR+MS 13050.00 91.35 34.07 8841.81 8780.51 3255.02 -2130.28 0.00 5963659.69 673923.83 MWD+IFR+MS . . BP BP Planning Report 13075.00 91.35 34.07 8841.22 8779.92 3275.72 -2116.28 0.00 5963680.72 673937.35 MWD+IFR+MS 13100.00 91.35 34.07 8840.63 8779.33 3296.43 -2102.27 0.00 5963701.74 673950.86 MWD+IFR+MS 13125.00 91.35 34.07 8840.04 8778.74 3317.13 -2088.27 0.00 5963722.77 673964.37 MWD+IFR+MS 13150.00 91.35 34.07 8839.45 8778.15 3337.83 -2074.27 0.00 5963743.79 673977.88 MWD+IFR+MS 13175.00 91.35 34.07 8838.86 8777.56 3358.54 -2060.27 0.00 5963764.81 673991.39 MWD+IFR+MS 13200.00 91.35 34.07 8838.27 8776.97 3379.24 -2046.27 0.00 5963785.84 674004.91 MWD+IFR+MS 13225.00 91.35 34.07 8837.68 8776.38 3399.94 -2032.26 0.00 5963806.86 674018.42 MWD+IFR+MS 13250.00 91.35 34.07 8837.09 8775.79 3420.64 -2018.26 0.00 5963827.88 674031.93 MWD+IFR+MS 13275.00 91.35 34.07 8836.50 8775.20 3441.35 -2004.26 0.00 5963848.91 674045.44 MWD+IFR+MS 13283.00 91.35 34.07 8836.31 8775.01 3447.97 -1999.78 0.00 5963855.64 674049.76 41/2" 13283.43 ./ 91.35 34.07 8836.30 8775.00 3448.33 -1999.54 0.00 5963856.00 674050.00 15-26B T3 TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 136 DATE 08~17'()lf 6~bl~o'FHE å~ ~~~(C, $ leo.oo ~ (J) '-- .. ... .' . . ·······--UOlIARS First National Bank Alaska . Aocho..,., AK 99501 ~ ' ~ MEMO \S·~~ 1 ( ~ "Mastercard Check" I: ~ 2 5 2000 b 0 I: q q ~ ~ II' b 2 2 7 II' ~ 5 5 b II- 0 ~ ~ b . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME It ú I )'-2C£ P1D# 20,--/ -/5 í -XDeVe!opment Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE". APPLIES (OPTIONS) MULTI Tbe permit is for a new weUbore segment of LATERAL existing well . Permit No, API No. . (If API number Production.sbould continue to be reponed as last two (2) digits a function 'of tbe original API number. stated are between 60-69) above. P~OT HOLE In accordance witb 20 AAC 25.005(f), aJl (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) .' and API Dumber (SO - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. DRY DITCH All dry ditcb sample sets submitted to tbe SAMPLE Commission must be in DO greater ·tban 3D' sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample inter:vaJs through target zones. .' . . o o Well bore seg Annular Disposal - Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 1.5.-26B Program DEV PLORATION (ALASKA) INC Initial ClasslType _DEV 11~GeoArea 890 Unit 11650 On/Off Shore On Administration Pj;![IT]it fee õ!ttached _ _ - - - - - ~ - - - - - Yj;!$- - - - - - - - - - 2 Leõ!sj;!number _apRro¡::¡riate. - - - - - - - - - - Yj;!$ - - - - 3 _U.nique well_n_arne_and oumb.er _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ - . -. - -. - - - Yj;!$-- . - - - - - - - - - - - - - - - - -- 4 WellJQcated ina d_efined pooL _ - - -- - - - - - Ye$ . 5 WellJQcated prpper .distance. from driJling unitb.oundary. _ _ . _ Yj;!S. 6 WellJQcated pr.oper .distance. from other wells - - - - - - _. Yj;!S._ - - -- .. - - - . 7 _S_utficienLacreõ!geayõ!ilable in_dJilIiog unjL . - - - - - - - - - Yj;!s_ - - - - - - -- 8 Jtdj;!viated, js weJlbQre platincJuded _ . . - - - -- . - Yj;!s 9 .Operator only õ!ffected party _ _ . . - - - - - . Yj;!s 10 _Ope~ator has.appropriate_b.ond inJQrce . _ _ _ _ _ _ . _ _ . _ _ _ . _ . _ _ _. _ _. _ _Yes __ - - - - - - - - - - - - - - - - - -- 11 pj;!(mit c.an be issued wjthQut çonserva.tion order _ . . - - - - - - . . _Yj;!$ Appr Date 12 pj;![IT]it c_an be issued wjthQut ªdminist~atille.apprpval _ _ . - - - - - Yj;!s RPC 8/18/2004 13 Can permit be approved before 15-day wait Yes 14 WeJI Jocated within area al1d.strata authorized by_lojectioo Order # (put 10# in. cpmm_eots) (for. _NA . - - - - - 15 AJI wells_wit!1inJl4.mite_area_of (eyiew jdj;!otified (Fp(!~ervjCj;!.w.eU onlYL _ _ _ _ _ _ - . _ - - _ .NJ\_ _ _ - - - - - - - - - - - - - - - - - -- 16 PJe-produced injector; duration.of pre-production Ij;!Ss t!1õ!113 months_ (For_service welt QnJy) NA. 17 .A{::MP.F]ndjngof CQm;istency_h_as been Jssued_ for.tbis project NA - Engineering 18 _C.ondu_ctor stringpJQvided . - - -- _NA _ 19 _SjJlfaœcasingpJQtects all known_ USDWs _ . - - - - - NA 20 CMT v_oJ adeQuate_ to circ_uJate_ on _conduçto~ & SUJ( C$g _ - - - - - - _NA __ - - - - - - - - - 21 _CMT v_oJ adequate. to tie-in JQng _string tosjJlf csg. _ _ - - - - - - NA - - -- 22 CMT will coyeraJl koown _productiye bQrizol1s. Yj;!s_ . - - - - - - - - - - - - 23 C.asiog designs õ!deQuaie fp( C,T~ B_&permafrpst . _ _ . - - - - Yj;!s. 24 _Adequatetõ!n_kage.oJ reserve pit _ _ Yes Nõ!bors_2ES. . 25 Jta_ re-drill~ bõ!s_a_ to-40;3 fQr abandonment bej;!n aRPJQved _ _ . Yes. * - - - -- - - - - -- 26 AdequateweUbore sepªratjo.n_proposed. _ _ . _ _ _ . _ _ _ _ _ _ . _ _ . _ _ - . _ Yj;!S_ . - - - - - - - - - - - - - - - - - - - 27 J(djverter Jeq_uired, dQes jt meet reguJaJions_ . - - - - - NA Sidet(a~. _ . - - - -- Appr Date 28 _DJilliog flujd_program schematic_& etluipJistadequate. _ . . _ _ . Yj;!s_ _ MªxMW8,5.RPg, . _ _ . _ _ . WGA 8/19/2004 29 BOPEs,d_oJhey meetreguJation . _ - - - - - - - .Yes. 30 .BOPE_press raJil1g õ!ppropriate; .test to _(put psig tn _comments) _ _ . Yj;!s. Test to _3500_ psi. _MSF' 23JO psi 31 _Choke_manjfold cQmpJies w/APt RF'-53 (May 84). - - - - - Yj;!s - - - - 32 Work will occ_ur withplJtoperation_sbutdown_ _ . . - - - - - - - - Yj;!S 33 Js presençe oJ H2S gõ!s. prQb.able _ . - - - - - - - - - - - - - - - - - Yj;!s 50 ppm. 34 Mecha_nicaLcpodJtlol1 p{ weHs within I\OR yerified (for_ service well ol1Jy) _ . NA Geology 35 pj;!rmit can be issued wlo hyd~ogen_ s_uJfide meõ!s_uœs _ . . - - - - - No_ 36 D_atapJesented on. RoteJ1tiõ!1 pveJpress\.lrezOl1es. NA Appr Date 37 _Sj;!tsmic_an.tlysis. Qf shaJlow gas_zPl1es_ . NA RPC 8/18/2004 38 Seabed _condjtipo survey (if Qff-shpœ) . _ . . _NA 39 _ CQnta_ct namelp!1oneJor_weekly progresueRorts [expIQratpr:y .0111YL . _ _ . NA - Geologic Date: Engineering Date C#-~"e' Commissioner Commissioner: Dj:s ~llr/1- e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infonnation 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. . . Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 01 16:18:00 2004 Reel Header Service name...... .......LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date. ....................04/11/01 Origin...................STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments..... .......... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 15-26B 500292223502 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 01-NOV-04 MWD RUN 1 MW0003281391 J. SACK R. BORDES MWD RUN 2 MW0003281391 J. BOBBITT R. BORDES 22 11N 14E 1029 202 MSL 0) 61. 30 32.80 OPEN HOLE BIT SIZE (IN) 6.000 6.000 CASING SIZE (IN) 7.000 7.000 DRILLERS DEPTH (FT) 9859.0 9859.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). ~ð'(-15( . . 3. 15-26B WAS DRILLED FROM A WHIPSTOCK POSITIONED AT 9859'MD IN THE 15-26A WELLBORE. THE BOTTOM OF THE WHIPSTOCK WAS AT 9871'MD. THE WHIPSTOCK WAS POSITIONED AND THE WINDOW WAS MILLED DURING RUN 1. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND AT-BIT INCLINATION (ABI). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 12' DOWNHOLE,PER E-MAIL FROM K. COONEY (SIS/BP) DATED 30 SEPTEMBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1 & 2 REPRESENT WELL 15-26B WITH API#: 50-029-22235-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13345'MD/8819'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMÞ. RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/1l/01 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPM RPS RPX FET $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9808.5 9871.5 9883.5 9883.5 9883.5 9883.5 9883.5 STOP DEPTH 13304.0 13356.5 13311.0 13311.0 13311.0 13311. 0 13311. 0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9808.5 GR 9796.5 . . 13356.5 $ 13344.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 9796.5 9885.0 MERGE BASE 9885.0 13344.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-tl~e...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9808.5 13356.5 11582.5 7097 9808.5 13356.5 ROP MWD FT/H 0.2 572.52 137.623 6971 9871.5 13356.5 GR MWD API 15.63 221. 99 56.6185 6992 9808.5 13304 RPX MWD OHMM 4.49 417 . 83 72.7871 6856 9883.5 13311 RPS MWD OHMM 7.19 1839.28 83.9208 6856 9883.5 13311 RPM MWD OHMM 21.64 2000 82.0998 6856 9883.5 13311 RPD MWD OHMM 37.87 2000 94.4216 6856 9883.5 13311 FET MWD HOUR 0.16 22.54 0.872952 6856 9883.5 13311 First Reading For Entire File..........9808.5 Last Reading For Entire File...........13356.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...04/11/01 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/11/01 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.001 Comment Record . FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 9796.5 9859.5 STOP DEPTH 9822.5 9885.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type... ..0 Logging Direction.......... .......Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWDOI0 19-5EP-04 Insite 66.37 Memory 9885.0 9859.0 9885.0 .0 .0 TOOL NUMBER 62456 6.000 9859.0 FLO-PRO 8.40 67.0 9.4 3500 12.5 .000 .000 .000 .000 .0 100.0 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 . . GR MWDOI0 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9796.5 9885 9840.75 178 9796.5 9885 ROP MWDOIO FT/H 0.2 8.69 4.395 52 9859.5 9885 GR MWDOIO API 15.63 32.89 23.984 53 9796.5 9822.5 First Reading For Entire File..........9796.5 Last Reading For Entire File...........9885 File Trailer Service name... ......... .STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/11/01 Maximum Physical Record..65535 File Type............... .LO Next File Name.. .........STSLIB.003 Physical EOF File Header Service name... ... .......STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation...... .04/11/01 Maximum Physical Record..65535 File Type............... .LO Previous File Name.... ...STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 9823.0 9871.5 9871.5 9871.5 9871. 5 9871.5 9885.5 STOP DEPTH 13292.0 13299.0 13299.0 13299.0 13299.0 13299.0 13344.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 22-SEP-04 Insite 66.37 Memory 13345.0 9885.0 13345.0 79.5 93.5 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 " BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 62456 130910 . . # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 9859.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FloPro 8.40 58.0 9.1 4000 14.0 1.050 .520 .850 .900 68.0 143.0 68.0 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units........ ...Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9823 13344.5 11583.8 7044 9823 13344.5 ROP MWD020 FT/H 0.66 572.52 138.624 6919 9885.5 13344.5 GR MWD020 API 17.55 221.99 56.8677 6939 9823 13292 RPX MWD020 OHMM 4.49 417.83 72.7871 6856 9871.5 13299 RPS MWD020 OHMM 7.19 1839.28 83.9208 6856 9871. 5 13299 RPM MWD020 OHMM 21.64 2000 82.0998 6856 9871.5 13299 RPD MWD020 OHMM 37.87 2000 94.4216 6856 9871. 5 13299 FET MWD020 HOUR 0.16 22.54 0.872952 6856 9871.5 13299 First Reading For Entire File..........9823 Last Reading For Entire File...........13344.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/11/01 Maximum Physical Record..65535 .. . . Fi 1 e Type................ La Next File Name...........STSLIB.004 Physical Ear Tape Trailer Service name.............LISTPE Date.................... .04/11/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.... .............STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...__........LISTPE Date.....................04/11/0l Origin.................. .STS Reel Name................ UNKNOWN Continuation Number......OI Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical Ear Physical EOF End Of LIS File
