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200-084
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P-02A PRUDHOE BAY UNIT P-02A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/05/2023 P-02A 50-029-22376-01-00 200-084-0 W SPT 8664 2000840 2166 926 932 927 934 23 293 280 274 4YRTST P Austin McLeod 3/5/2023 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT P-02A Inspection Date: Tubing OA Packer Depth 88 2539 2502 2492IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230305194357 BBL Pumped:4.2 BBL Returned:3.2 Wednesday, April 5, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Cas Conservation Commission DATE: Thursday, March 7, 2019 TO: JjInRegg P.I. Supervisor ,\—c)l l i I (`� SUBJECT: Mechanical Integrity Tests ( l BP EXPLORATION (ALASKA) MC. P -02A FROM: Bob Noble PRUDHOE BAY UNIT P -02A Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT P -02A API Well Number 50-029-22376-01-00 Inspector Name: Bob Noble Insp Num: mitRCN190304I63923 Permit Number: 200-084-0 Inspection Date: 3/3/2019 / Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P02A Type Inj O'TVD 8664 'iTubing: 2948 2950 2948 - 2951 2945 - PTD 2000840 TYPe Test sPr Test psi v66 IA 63 2500 2491 2492 249 BBL Pumped: 4.8 BBL Returned: 3s OA 16 48 - 50 51 53 interval 4YRTST P/F P - --_ I Notes: Thursday, Much 7, 2019 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,April 02,2015 TO: Jim Regg Ney ¢lt IiC P.I.Supervisor i SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC P-02A FROM: Matt Herrera PRUDHOE BAY UNIT P-02A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.�� NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT P-02A API Well Number 50-029-22376-01-00 Inspector Name: Matt Herrera Permit Number: 200-084-0 Inspection Date: 3/10/2015 Insp Num: mitMFH150311062846 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P-02A " iType Inj ' W JTVD 8664 " Tubing f 907 . 910 910 910 PTD 2000840 "'Type Tesii SPT;Test psi 2166 - IA 355 2500 " 2493 - 2490 - Inter- I - - -nterval4TST P/F P OA 6 223 217 217 - Notes: 2 8 BBL's Methanol to fill IA-and complete pressure test. satiHED MAY 2 8 ZO Thursday,April 02,2015 Page 1 of 1 Ir~ ]e Project Well History File Co~' 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 be scanned during a special rescan activity or are viewable by direct inspection of the file. ~_~o_. ~5~ ¥ ~v~,, .,,,o~ ~,,~ ,,~r Organizing l,~o,,-~i [] RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [~'"'~Diskettes, No.I [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~INDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~WINDY Scanning Preparation <:~ x 30 = ((:2~) BY: BEVERLY ROBIN VINCENT SHERY~INDY III IIIIIIIIIII II III TOTAL PAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: "/'/~ ' YES BEVERI~,._Ro__BIN~VINCENT SHERYL MARIA WINDY DATE '~S/ NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES.7~ NO ~u~.o.u~u~, ~.~.CA'.O. COLO.,M~.~ I]1 IIIIIIIIIII II III RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Isl Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA A OKA OIL AND GAS CONSERVATION COMMON OCT 1 5 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well LJ Plug Perforations U Perforate U Other Li Mill Plug Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other Q Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ 200-084-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service Q 6.API Number: Anchorage,AK 99519-6612 50-029-22376-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028288 PBU P-02A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 14410 feet Plugs measured None feet true vertical 8999.41 feet Junk measured 14331 feet Effective Depth measured 14373 feet Packer measured See Attachment feet true vertical 8995.61 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 33-113 33-113 1490 470 Surface 3231 10-3/4"45.5#NT-80 32-3263 32-2841.37 4560 1730 Intermediate None None None None None None Production 12374 7-5/8"29.7#NT-95HS 31-12405 31-8856.66 8180 5120 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 13460-13580 feet 13650-13700 feet 14243-14324 feet 14350-14370 feet True Vertical depth 9006.82-8999.44 feet 8996.13-8994.86 feet 8982.48-8990.78 feet 8993.29-8995.3 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 29-12243 29-8718.81 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: d { r, Intervals treated(measured): SCANNED NOV 1 3 2.V 013 13460'-13580', 13650'-13700' Treatment descriptions including volumes used and final pressure: 49 Bbls 9:1 DAD Acid,2241 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1440 1435 Subsequent to operation: 1736 1039 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUC[] 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: 313-425 Contact Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 10/15/2013 (/LF ,, /®% RBDMS OCT 17 k // Form 10-404 Revised 10/2012 Submit 3 Submit Original Only • • Packers and SSV's Attachment ADL0028288 SW Name Type MD TVD Depscription P-02A PACKER 12178 8576.15 4-1/2"TIW HBBP Packer P-02A PACKER 12239 8627.53 5-1/2"TIW HBBP Packer Casing / Tubing Attachment ADLOO28288 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 33 - 113 33 - 113 1490 470 LINER 326 3-3/16" 6.2# L-80 12189 - 12515 8673.3 - 8947.44 LINER 613 5-1/2" 17# NT80S 12239 - 12852 8715.43 - 9038.99 7740 6280 LINER 1891 2-7/8"6.16# L-80 12515 - 14406 8947.44 - 8999 13450 13890 PRODUCTION 12374 7-5/8"29.7# NT-95HS 31 - 12405 31 - 8856.66 8180 5120 SURFACE 3231 10-3/4"45.5# NT-80 32 - 3263 32 - 2841.37 4560 1730 TUBING 12214 4-1/2" 12.6# L-80 29 - 12243 29 - 8718.81 8430 7500 • • Daily Report of Well Operations ADL0028288 ACTIVITYDATE SUMMARY Job scope: Acid treatment/Mill CIBP 9/13/2013 Rig up and weekly BOP test in progress. Continued on 09/14/13 WSR. Job scope: Acid treatment/Mill CIBP Complete weekly BOP test. MU 1.98" JSN. SI well. RIH w/ nozzle. Set down at 13634' CTM. Clean up 46' sticky interval from 13634' - 13680' CTM (perfs from 13650' - 13700' MD). Tag CIBP at 14002' CTM. PUH above perfs to 14000'. Fluid pack well and perform pre-acid step rate injection test: 1850 psi ©2.5 bpm, 1760 psi @ 2 bpm, 1580 psi @ 1.0 bpm, 1410 psi @ 0.5 bpm. Jet 49 bbl • of 90:10 DAD acid from 13410-13750'with no effect on injectivity. Pump 5 bbl NH4CL spacer© 13410'. Jet 47 bbl of 9:1 mud acid from 13410-13750'with no effect on injectivity. Park @ 13410' and pump 50 bbl NH4CL. down coil. Swap to coil pump and pump remaining stage 4 NH4CL down backside. 9/14/2013 Continued on 09/15/13 WSR. Job scope: Acid treatment/Mill CIBP Continued from 09/14/13 WSR. Pulling out of hole w/coil, pumping NH4CL down backside for acid displacement. After 200 bbl NH4CL pumped down backside. SD pumping 20 minutes, Repeated SRT from 6797', pumping down backside only: 0.5 bpm/1274 WHP, 1 bpm/1380 WHP, 2 bpm/1550 WHP, 3 bpm/1670 WHP, 4 bpm/1766 WHP, 4.9 bpm/1860 WHP. Continue displacing NH4CL down backside for total 369 bbl. MU/RIH w/ milling string w/2.3"junk mill. Tag CIBP at 14012' CTM. Mill CIBP and push to PBTD at 14,331' CTM. Repeat SRT: 0.5 bpm/1040 WHP, 1 bpm/1260 WHP, 2 bpm/1490 WHP, 3 bpm/1680 WHP, 4 bpm/1880 WHP. POOH. Freeze protect coil, tubing, and flowline. RDMO. ***Job Complete*** 9/15/2013 ***Pad Operator informed well is shut in and freeze protected*** • T/I/O= 350/72/0 (Assist S-Line/ Load and Kill/MITxT to 2500 psi PASSED/ MITx IA to 2500 psi PASSED ) Rig to TBG. Pump 5 bbls neat meth spear followed by 255 bbls 2% KCL then 40 bbls diesel to load TBG. Shut down/Standby for S-Line to set @ SSSV. Pump 10 bbls diesel to verify plug is holding. S-Line POOH. Pump .25 bbls diesel to achieve a test pressure of 2500 psi. ( MITxT) TBG lost 92 psi in 1st 15 min and lost 40 psi in 2nd 15 min for a total loss of 132 psi in 30 min test. Passed ) Bleed TBG press. to 295 psi. Rig to IA. Pump 5 bbls diesel down IA to achieve a test press. of 2500 psi. ( MITx IA) IA lost 27 psi in 1st 15 min and lost 8 psi in 2nd 15 min for a total loss of 35 psi in 30 min test. Bleed IA press. to 291 psi. RDMO/ FWHP= 345/291/0 S-Line on well @ 9/18/2013 departure. IA and OA open to gauges. Operator notified of departure. Daily Report of Well Operations ADL0028288 T/I/O= SSV/280/0 Temp= SI PPPOT-T (PASS) Pre Tree Replacement PPPOT-T: Stung into test void (350 psi.). Bled void to 0 psi. Torqued LDS to 450 ft/lbs. Pumped through void, good returns. Pressured test void to 5000 psi. for 30 min. test. Lost 50 psi. in 15 min. 9/19/2013 Lost 0 psi. in second 15 min. (PASS). Bled void to 0 psi. T/I/O= 300/250/0. Performed LTT on SSV, SV(passed). R/U lubricator w. 4" CIW H-plug#286. Set TWC tagging at 120". Performed LTT on TWC (passed). Installed sign on tree. (See log for details.) 9/20/2013 ***Job complete*** T/IA/OA= TWC/250/0. Performed LTI on barriers.(PASSED). Replaced 4-1/16 CIW tree. Torqued • and PT'd. Pulled TWC#286. Installed tree cap and PT'd. RDMO. Open=MV,IA,OA. 9/21/2013 Closed=SSV,WV,SV.***Job Complete*** ***WELL S/I ON ARRIVAL***(tree-replacement) PULLED 4-1/2" DUMMY SSSV PLUG FROM 1,996' SLM. SET 4-1/2" MCX W/ EQ DEVICE @ 1,994' SLM/2,089' MD (serial#M-13, .75" bean). RAN 4-1/2" CHECK SET TO 1,994' SLM. (check set sheared). 9/23/2013 ***WELL S/I ON DEPARTURE***(dso notified of well status). T/I/O = 1050/1100/20. Temp = 120°. Bleed IAP to 500 psi (UIC). Injecting. IA FL @ surface. Bled IAP to (P-01 production) to 420 psi in 15 min. Monitored for 30 min WHPs unchanged. Final WHPs = 1050/420/20. 9/28/2013 SV= C. WV, SSV, MV= O. IA, OA= OTG. NOVP. 10:00 hrs. Ti A41111"� P-02A MT � ''WELL REQIARES A SSSV WHEN ON MI ACTUATOR= BAKER C "" VI/ELL ANGLE>70°@ 12686'. KB ELEV - 87.9' I BF ELE1/= 32.5' Max Angle__._.,_95 , 13885 ' 20'CX*DUCTCR, H -110 Datum MD= 12442' 91.5#,1+40, I 2089' I.J41/2"OTIS HXO SSSV NP,D=3.813" I 0 , [ Datum TVD= 8800'SS D-19.124" GAS LIT MANDRELS 10 314"CSG,45.5#,NT 8E-BTC,D=9.950' H 3263' ST MD TVD DG/ TYPE VLV LATCH FORT DATE 5 3539 3012 51 OTS DMY BK 0 08/19/93 4 6845 5058 53 OTIS DMY BK 0 08/19/93 I L 3 9201 6583 48 OTIS DMY BK 0 08/19/93 2 11036 7794 48 OTIS DMY BK 0 08/19/93 Minimum ID = 2.38" @ 12515' W� 1 12103 8888 33 CMS DMY BK 0 08/19/93 2-718" X 3-3/16" XO o(,*� �*• 12100' H PAacEx SQUEEZE(07113/94) I •• • ►•'•1 v. 12159' H4-1/2"PARKER SWS NP,D=3.813" I 14. 44. 12178' I-7-5/8"X 4-1/2"TIW FBBP PKR 1MLATCH ASSY. (BENNO LNR),D=4.000" TOP OF 3-3/16"X 2-7/8'LN2 -i 12198' 12189' H3.75'BKR DEPLOY SLV W/GS PROFILE,13=3.00" I 12198' 3-1/2"X 3-3/16'XO,D=2.88" 1--------I 12212' I-I4-1/2"SWS NP,D=3.813" (BEM LSE) 12230' H4-1/2"PKR SWN NP,D=3.80°(BEHIND LN2) I I TOP OF 5-112'Lfs11 H 12230' I 12239' I-17-5/8"X 5-1/2"TM/LIP liw/TIEBACK SLV 8HGRD=? 4-1/2"TBG,12.6#,L-80 NSCF, —1 12242' I / - I 12243' 1-14-112'WLEG,D=4..00' I .0152 bpf,D=3.958" 7-5/8'CSG,29.7#,NT95HS NSCC, -I 12405' I-I ' .5186 bpf,D=6.875" WHIPSTOCK w/RA TAG 6 12494' -I -12481 5-1/2'LW,17#,NT-80S NSCC,.0232 bpf,D=4.892" -I -12481 MLLOUT WIDOW(P-02A) 12481'-12489' PERFORATION S*JVLIARY REF LOG:SWS GR/OCL 12/22/00 ANGLE AT TOP PERF: 92° -, 13460' Note:Refer to I�hoduction DB for historical pert data % -4 12615' H3-3/18"X 2-7/8'XO D=2.38" I SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2" 6 13460-13580 0 06/18/06 2" 6 13650-13700 0 06/18/06 2" 6 14243-14324 0 12/23100 2" 6 14350-14370 0 12/23/00 I 14331' I-I FISH-WRP MLLH)&PUSHED TO BTM(9/15/13) I 3-3/16"6.2#,L-80 LM ,.0066 bpf,D=2.78" -I 12515' Pam —I 14373' I 2-7/8"LW,6.16#,L80-STL,.0058 bpf,D=2.37" -I 14406' DATE REV BY CONSENTS DATE REV BY UOM ENTS RSJDHOEBAY UST 08/22193 N28E INFML COMPLETION 01/18/12 TMWJM) ADDED I-QS SAFETY NOTE WELL: P-02A 12/23/00 CTD SIDETRACK(P-02A) 09/14/13 DUI PJC GLV CORRECTIONS PERMT Na: 200-0840 06/01/01 CIIKAK CORRECTIONS 09/16/13 PJC LNR/RIG CORRECTIONS AR No: 50-029-22376-01 09/22/06 AK/PAG PLUG&ADPERF(06/16 818/00 09/17/13 AM PJC WRPTO BTM(9/15/13) Sec.31,T11N,R13E,2623'FSL&2039'FWL 03/04/07 ATD/TLH PKR SQZ(7/13/94) 10/11/13 DU/MD TREE C/O(09/21/13) 02/10111 NB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) • • ww ‘,\ I%%(V THE STATE Alaska it and Gas °fALAS KA Conservation Commission _-=-_ -_ GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS 907.279.1 433 Fax: 907.276.7542 rl :t Marcus Charles `SCAN Production En g ineer 061# P.O.Exploration (Alaska), Inc. no- P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU P-02A Sundry Number: 313-425 Dear Mr. Charles: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this /0 day of August, 2013. Encl. It- STATE OF ALASKA $ i_ „ ALASKA OIL AND GAS CONSERVATION COMMISSION t\ ,a 0 6 Al 3 APPLICATION FOR SUNDRY APPROVALS 0-7.3 S 43 20 AAC 25.280 A 0(1'e e'aa 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate Si • Alter Casing❑ Other. Mil CIBP •J1 2.Operator Name: 4.Current Well Class: :5.Permit to Drill umber. BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 200-084-0 . 3.Address: Stratigraphic ❑ Service El • 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22376-01-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU P-02A , Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028288 • PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 14410 • 8999 ' 14373 8996 14065 None Casing Length Size MD TVD Burry Collapse Structural Conductor 80 20"91.5#H-40 33-113 33-113 Surface 3231 10-3/4"45.5#NT-80 32-3263 32-2841.37 4560 1730 Intermediate None None None None None None Production 12374 7-5/8"29.7#NT-95HS 31-12405 31 -8856.66 8180 5120 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(tt): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 29-12243 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and IVD(1t): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development ❑ Service El ' 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ID • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Charles Email Marcus.Charies@BP.Com Printed Name Marcus Charles Title Production Engineer Signature Phone 564-4464 Date Prepared by Gerry Catron 564-4424 ?zg•,,... OCI-1,1eo S i 611? COMMISSION USE ONLY � Conditions of approval: Notify Commission so that a representative may witness Sundry Number 31,� -4.3 j Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ MEM& OCT 1 0 2 Other: Spacing Exception Required? Yes El No di Subsequent Form Required: /0 '40+ APPROVED BY Approved by: j' COMMISSIONER THE COMMISSION Date: 8 -/6, /3 > ,40:: g//s// ^ lll ���111 iji5 Form 10-403 Revised 1/2010 �p Ripen Ifrom the date of approval. Submit in Duplicate�wt' Casing Summary ADL0028288 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 91.5# H-40 33 113 33 113 1490 470 H-40 LINER 326 3-3/16" 6.2# L-80 12189 12515 8673 8947 L-80 LINER 1891 2-7/8"6.16# L-80 12515 14406 8947 8999 13450 13890 L-80 LINER 613 5-1/2" 17# NT805 12239 12852 8715 9039 7740 6280 NT80S PRODUCTION 12374 7-5/8"29.7# NT-95HS 31 12405 31 8857 8180 5120 -NT-95HS SURFACE 3231 10-3/4"45.5# NT-80 32 3263 32 2841 4560 1730 NT-80 TUBING 12214 4-1/2" 12.6# L-80 29 12243 29 8719 8430 7500 L-80 • • • • Perforation Attachment ADL0028288 Well Date Perf Code MD Top MD Base TVD Top TVD Base P-02A 6/18/06 APF 13460 13580 9007 8999 P-02A 6/18/06 APF 13650 13700 8996 8995 P-02A 6/16/06 BPS 14243 14324 8982 8991 P-02A 6/16/06 BPS 14350 14370 8993 8995 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • i Packers and SSV's Attachment ADL0028288 Well Facility Type MD Top Description TVD Top P-02A PACKER 12178 4-1/2"TIW HBBP Packer 8664 P-02A PACKER 12239 5-1/2"TIW HBBP Packer 8715 by 0 • r To: Well Services Operations Team Lead Date: 07/31/2013 Wireline Operations Team Lead AFE: APBINJEC From: Marcus Charles, PE IOR: 50 Reviewed by: Laurie Derrick Est. $225,000 Cost. Subject: P-02A Acidize/Mill CIBP 1 F Pump SBG prior to coil job 2 D TIFL 3 S Drift and Tag to deviation 4 C Drift and Tag CIBP @ 14,065' 5 C Perform 1St step rate injectivity test 6 C Acidize perforations between 13,460'-13,580' and 13,650'-13,700' 7 C Perform 2nd step rate injectivity test 8 C Mill CIBP and push to bottom 9 C Perform 3rd step rate injectivity test Current Status: Wag injector: Operable/PWI. Injection: 1,700 bwpd @ 1,393 psi. Target: 2,000 bwpd. Minimum ID: 2.38" @ 12,515' MD-2-7/8" x 3-3/16"XO. Max Deviation: 95 degrees @ 13,885' MD. Last TD Tag: 04/20/07: set down @ 12,508' SLM w/2.25" sample bailer. No sample. Last Downhole Op: 06/08/07: Set MCX @ 2,089' MD. Tubing Volume: Tubing = 186 bbls, liner to perfs = -8 bbls SBHP/SBHT: P-01A: 3,391 psi @ 227°F @ 8800' Datum SS, 52 days SI Latest H2S: Injector Program Objectives The objective of this program is to: • Increase injection to support 6 mmscfd on MI. This will be done by acidizing the open perfs and opening up toe perfs by milling CIBP and pushing to bottom. Well History P-02A is an injector supporting P-01A and P-08A. P-02A is currently injecting produced water because of low MI injection rate. The well was taking -2100 mscf/d @ 3,000 psi. The desired MI injection target is -6,000 mmscf/d. After discussing the pattern, a low MI injection rate may not efficiently sweep oil to offset producers. Prior to P-01A sidetrack, there was a short circuit (in 2006) with a 3 month lag time between P-02A toe perfs and P-01 (only 1200' away). In 2006, a CIBP was set to block off the toe perfs. Perfs were then added above the CIBP. In May 2013, a high pressure pert break down was pumped, slightly increasing injectivity. To further increase the injection, the plan is to acidize the open perfs • • (13,460'-13,580' and 13,650'-13,700') and mill out the CIBP to open the toe perfs. P-01 has been sidetracked to P 01A, which is now 2200' away from the P-02A toe perfs.s. Millin the CIB P will also help to increase the sweep efficiency while on MI and PWI. Integrity: The well passed a MIT-IA to 4000 psi and AOGCC witnessed MIT-IA to 2515 psi on 03/11/11. V There is no tubing caliper on this well and the well was not pre-produced. The packer was cemented in July 1994. Program Contacts Phone—Work Phone—Cell P&Y Pad Engineer Scott Warner 907-564-5865 Pad Engineer Marcus Charles 907-564-4464 907-227-8402 Lead PE Laurie Derrick 907-564-5952 702-308-3386 Perforations and Details: Zone MDT MDB Height Status Z4 13,460' 13,580' 120' OPEN Z4 13,650' 13,700' 50' OPEN Z4 14,243' 14,324' 81' CLOSED Z4 14,350' 14,370' 20' CLOSED Total Perf Footage 120' of open perfs Wellbore Volume 193 bbls to top of perfs IA Volume 317 bbls to top packer squeeze PROCEDURE FB 1. Pump SBG per schedule. DHD 2. Perform TIFL to verify tubing integrity. If TIFL fails, diagnose and repair leak. Change out GLVs as needed to restore tubing integrity. Do not proceed with acid stimulation without a passing TIFL and operable well. Slickline 1. Drift to deviation (slope PE discretion). CTU Acid Stimulation Details Reminder NOTE: Well has L-80 liner. Ensure correct additives are used with any and all acids. Acceptable acid concentrations +/-1% for HCI and +/- 0.25% for HF. Fluids should be 90-110 F. • • Wellbore Volume 198 bbls to CIBP of 14065' MD, 186 bbls tubing volume Volume Across Perfs 1 bbl — 170' in 2-7/8" liner Acid Design 90:10 DAD Acid @ 11.6 gpf—47 bbls 9:1 Mud Acid @ 11.6 gpf—47 bbls Over Flush Design 250 bbls 3% NH4CI Brine + 0.2% F103 Surfactant Pres (P-01A) 3,391 psi @ 227°F @ 8800' Datum SS, 52 days SI Volume (bbls) Volume (gal) Fluid 47 1,974 11.6 gpf 90:10 DAD Acid 47 1,974 11.6 gpf of 9:1 Mud Acid 924 38,808 3% NH4CI + 0.2% F103 51 2,142 Diesel - 51 bbls for ct tubing annulus Acid Composition Medium (175F to Temperature: 225 F) Comp_letion metallurgy: L-80 Loading for: 9:1 Mud 90:10 Product Code: Function: Units: Acid DAD Acid A264 ACI Gal/Mgal 6 6 A201 Inhibitor Aid Gal/Mgal 15 15 A153 Intensifier lb/Mgal 0 0 Flow-back F103 aid Gal/Mgal 2 2 L058 Iron Control lb/Mgal 20 20 Anti- W054 emulsifier Gal/Mgal 5 5 Mutual U067 Solvent Gal/Mgal 50 0 A026 Xylene Gal/Mgal 0 100 U074 Emulsifier Gal/Mgal 0 15 Ammonium Chloride Water Loading for: Product Function: Units: per Mgal F103 Flowback 2 J285 NH4CI lbs/Mgal 250 Pre-Acid Note: Before starting operation please ensure the followings; • Freeze protect flow line as necessary. • • • Do not shut down pumping for dry tags until the previous sweep has reached the surface. If it is necessary to stop pumping at any time, pull the coiled tubing uphole into a more vertical section. CAUTION: During CTU work, please monitor IA pressures and do not exceed 2000 psi during pressure cycles and stress safety precautions with acid use. Target Interval We are targeting 170' of perforated interval. Perferation Interval: 13460 13580 120 13650 13700 50 14243 14324 Closed 14350 14370 Closed Total: 170 CTU Acid Stimulation Procedure 1. Ensure that lateral and wing valves are SI. PT and pickle CT with 5 bbls 90:10 DAD Acid (if necessary). • Filter all fluids possible that will enter the formation to 3 microns onsite immediately prior to pumping down-hole. • Do not add friction reducer to stimulation fluids that will enter the perforations. • Do not exceed 0.65 psi/ft gradient during liquid packing or any other time during the job. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. o Send an electronic copy of the treatment report to Marcus Charles at marcus.charlesabp.com and to Scott Warner @ scott.warnerabp.com 2. MU BHA to include 2.00" OD jet swirl nozzle (min wellbore ID of 2.38"). 3. Knock down WHP enough to RIH w/ 3% NH4CI + 0.2% F103. RIH and tag CIBP noting any restrictions or tight spots. 4. While RIH, load well by pumping at 4-6 bpm down ct and backside with 279 bbls (1.5x tubing volume) of 3% NH4CI + 0.2% F103. 5. Perform step rate injection test. Pump at 0.5, 1, 2, 3, 4, 5 bpm (or 2000 psi maximum pressure) until a relatively stable pressure is achieved at each rate. This is expected to take a few minutes per rate. Total anticipated fluid for the step rate test is about 130 bbls 3% NH4CI +0.2% F103. Record stabilized rate and pressure for each step. • • • 6. After tubing is fluid packed and performing step rate injection test, swap to pumping down ct backside only and pump-51 bbls diesel to allow for 100 psi positive WHP. CT maximum rate (below 0.65 psi/ft frac 7. Pum the following fluids down C at ( p gradient). Pump o Reciprocate nozzle across perforated interval. Stage Vol Cum Vol Step Description Fluid BBL BBL Comment 1 DAD Acid 90:10 DAD Acid 47 47 Reciprocate between 13460' 2 Spacer 3% NH4CI +0.2% F103 5 52 and 13700'. 3 Mud Acid 9:1 Mud Acid 47 99 4 Overflush 3% NH4CI +0.2% F103 250 349 Push acid into formation 7. Perform step rate injection test. Pump at 0.5, 1, 2, 3, 4, 5 bpm (or 2000 psi maximum pressure) until a relatively stable pressure is achieved at each rate. This is expected to take a few minutes per rate. Total anticipated fluid for the step rate test is about 130 bbls 3% NH4CI +0.2% F103. Record stabilized rate and pressure for each step. CTU Mill CIBP 8. POOH. MU BHA to mill 2-7/8"WFD CIBP. 9. RIH to 14,065' MD and Mill CIBP and push to bottom. i. Note: PBTD is 1' below bottom pert. 10.Document new depth of CIBP. 11.Perform step rate injection test. Pump at 0.5, 1, 2, 3, 4, 5 bpm (or 2000 psi maximum pressure) until a relatively stable pressure is achieved at each rate. This is expected to take a few minutes per rate. Total anticipated fluid for the step rate test is about 130 bbls 3% NH4CI +0.2% F103. Record stabilized rate and pressure for each step. 12.POOH. Notify operator to POI or F/P if necessary. 13.RDMO. • S TREE= 4-1/16'5M CW SAFETY NOTES:HU REApN38 AVERAGE 121 porn 5M FMC MELLHEAIX w 'A P-O 2 A MI.EN ON I.W REQUIRES A SSSV WHEN ON KB.ELEV= 873 8 126111r. BF.ELEY• 32.5 KOP• 1391' Atm Angle=; 95'®13895' I 205$' 144.1/2'OTIS WO 888V LANDt1.3 MP,ID•3,613' I Datum M]• 12442 • Datum NCP 8800'8S 10 314"CSG,45.58,111-90 BUTT, =283' I GAS LFT MANDRELS 2476 DpI,D•915" ST MD 1VD OEV TYFE VLV LATCH PORT DOTE Earl 5 3539 2926 51 OT15 DOME BK 01A5b1 4 6845 4978 53 OTIS DONE 8K 01105101 Minimum ID= 2.38 Q 12616 3 9200 0511 48 0118 DOME BK 01105101 2-7/8" X 3-3/18"XO 2 11036 7726 48 oTIS DMY BK 01105A1 1 12103 8545 33 011S ENPTY BK 01105101 4+4' +4' 12100' HPACKEt SQUEEZE(O7N3194) I 44*• i 4 1215$ Ha-1 R"SWS NIP,D•3.513" 1*4 11.1 121115' I—/-blrx4-1/r Iry HMV MKS MATCHASSY,ID -I3.76'BKR DEPLOY SLV VW OS PROFlLE,ID•3.00' ITOP OF 3-3118"LNR 12198' I 12148' I-13-12'X 3-3/16'XO,ID=2.98' I •▪ /r� 12212' H4-12"MAR NP,ID•3.013' (BE NINO LNR) I 7-'310"X 5.117'TM/LNR TOP HNORJPKR 122 ' I ' J-14 112"PKR 9VVF1 NP.ID=3.80 (t3r31F[!LNR W TIEBACK SLV tt: (4-12"T80,12.01.1.80 NSCT, -I 12243' I 12243' I•-I4 117 TBti BAIL MEG I .0152 bpi,0.3,968' 7-518'CSG,29.78,NT9511S NSCC, — 12405' I. A .411e bpf,D■0.070" 5.112'WrD OW 12481'-12489' PERFORATIONSLMIMRY I. 12480' j TOP OFV BTO I REF LOG SWS GRIOLI 12122A0 12494' RA TAG ANGLE AT TOP PERF- 94'(114243 Note:Refer to Production OE for historical psrf dale —13-3M8"X 2-7/W XO 0.2.3W I SIZE SFf INTERVAL OpnlSgz DATE +•;•+•+++•+� •••••■ ` 1406S SET CEP 2 6 13460-13580 0 06118/06 +++++�+++++� 2 6 13850-13700 0 06111Y08 ++i+++i+i++' N +i+i+i+i+i' 2 6 14243-14324 C 12123100 +++++++++a+' 2 6 14350-14370 C 120123100 '+..+..!0.0 N P610 14371' s. 15-1/2-LNR,179,1-80 NSCC,.0232 bpf,D•4992- H 12862' I WR, I3-3/18'5.20,L-90 LNR,.0066 bpf,0=2.7r H 1251W 1TOP OF 2-7/e"LNR H 1251W I2-718'LNR,6.168,L80-STL,.0058 bpf,ID•2.37" H 14406' J DATE REV BY COMMENTS 4TS DATE RS/BY COMMENTS PRUDHOE BAY UNIT 08122193 MOO ORIGINAL COMPLETION 01/18/12 11/PIUMD ADDED FQS SAFETY NOTE W9.L: R02A 12/23100 CTDSIDETRACK PET No: 200-0840 06101/01 CI-VKAK CORRECTIONS AF1it: SO-029-22376-01 09/22/06 AKJPAG PLUG&ADPERF(06116&16/06) See.31,T11N,1213E 03104/07 ATLYTLH PKR$02(7/134) 02/10/11 MBI.IU1D ADDEOSSSV SAFETY NOTE EP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 ;`.. - �:;:: °a, '; 10 RECE1V 0;1 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission AUG 31 2011 333 West 7 Avenue Anchorage, Alaska 99501 Nish ON & Geo Con. cOtm Anchorage Subject: Corrosion Inhibitor Treatments of GPB 3.00- ®V Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB P- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) P -Pad Date: 07/21 /11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na qal P -01 1920920 500292228700 0.30 NA 0.30 NA 0.85 4/24/2010 P -02A 2000840 500292237601 0.30 NA 0.30 NA 4.25 4/25/2010 P -03A 1972280 500292217601 12.70 5.0 0.30 7/12/2010 2.55 8/5/2010 P -04 1910760 500292218000 1.80 NA 1.80 NA 15.30 4/25/2010 P -05A 2000510 500292254501 0.80 NA 0.80 NA 5.95 4/25/2010 P -06B 2051380 500292216602 11.30 3.0 1.00 7/12/2010 9.35 8/5/2010 P -07A 2011960 500292253501 0.50 NA 0.50 NA 1.70 4/24/2010 P -08A 2000850 500292237701 0.10 NA 0.10 NA 0.85 4/24/2010 P -09 1930580 500292236200 0.10 NA 0.10 NA 0.85 4/24/2010 P -10 1910520 500292215800 3.00 NA 3.00 NA 28.05 4/24/2010 P -11 1910290 500292214300 3.00 NA 3.00 NA 23.80 4/23/2010 P -12B 2001330 500292213602 0.30 NA 0.30 NA 0.85 4/23/2010 P -13 1901110 500292208000 0.30 NA 0.30 NA 1.70 4/23/2010 P -14 1910070 500292212900 7.50 NA 7.50 NA 56.10 7/21/2011 P -16 1901630 500292211300 4.30 NA 4.30 NA 37.40 4/22/2010 P -17 1901550 500292210500 8.00 NA 8.00 NA 89.30 4/28/2010 P -19 1901360 500292209400 0.80 NA 0.80 NA 5.10 4/21/2010 P -20B 2001590 500292208902 0.20 NA 0.20 NA 0.85 4/21/2010 P -21B 1970640 500292214802 0.40 NA 0.40 NA 4.30 4/21/2010 P -22 1931210 500292239600 0.30 NA 0.30 NA 1.70 4/23/2010 P -23 1931120 500292239300 0.30 NA 0.30 NA 0.85 4/24/2010 P -24 1970540 500292275500 1.80 NA 1.80 NA 8.50 4/24/2010 P -25 1970260 500292274200 64.00 24.0 2.60 7/17/2011 23.80 7/20/2011 P -26 1962000 500292272700 2.60 NA 2.60 NA 22.10 4/25/2010 P -27 2040500 500292320300 1.00 NA 1.00 NA 6.80 4/25/2010 P -28 2100480 500292342500 1.20 NA 1.20 NA 10.20 8/7/2010 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ZSi DATE: Monday, March 14, 2011 TO: Jim Regg h � P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P -02A FROM: Jeff Jones PRUDHOE BAY UNIT P -02A Petroleum Inspector Src: Inspector Reviewed By: �,, P.I. Supry ., IFae— NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT P -02A API Well Number: 50- 029 - 22376 -01 -00 Inspector Name: JeffJones Insp Num: mitJJ110314070300 Permit Number: 200 -084 -0 Inspection Date: 3/11/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P - 02A' Type Inj. W'` TVD 8664 ' IA 440 2515 ' 2490 2490 P.T.DI 2000840' TypeTest SPT Test psi 2166 J 1 1 OA 470 690 690 690 Interval 4YRTST - P/F P - Tubing 1880 1880 1880 1920 Notes: 3.2 BBLS methanol pumped. 1 well inspected; no exceptions noted. , t ' ED M /R 3 4 Z WI Monday, March 14, 2011 Page 1 of 1 P-02A (PTD #2000840) no plot after 1 month ofMI injection e e Hi Jim, Here is a TIO plot of P-02A (PTO #2000840) after 1 month on MI injection. stabilized and there Îs no ~Of communication. \~ ~\-\c"" Please let me know if you have any questions. Thank you, The IA pressure has ... ,'..' . ....... ". - }fnna QJu6e, œ fE. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED APR 1 7 2007 " ..... ".....~"....... From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Friday, March 16, 2007 4:42 PM To: Hughes, Andrea Cc: Tom Maunder; Admin AOGCC Prudhoe Bay Subject: Re: WGI-09 (PTO # 2061460), 04-17 (PTO #1860200), P-02A (PTO #2000840), S-114A (PTO #2021980) MIT forms Andrea - PBU P-02A (PTD 2000840) showed a 10% increase in tubing pressure during the pre-Ml swap MITlA. There was no pressure stabilization pressure during the 30 minute test. Please report back I month after beginning Ml on the annulus pressures to make sure this is not an indication of communication (TlO pressure plot would be sufficient). Of course, any indication of annulus pressure communication must be reported to the Commission per AlO 3 Rule 7. Jim Regg AOGCC Hughes, Andrea wrote: Jim, Tom and Bob, Please see the attached MIT forms for the following wells: WGI-09 (PTO # 2061460): MITIA post-initial injection lof2 4/17/20079:01 AM P-02A (PTD #2000840) no plot after 1 month ofMI injection e e 04-17 (PTO #1860200): CMIT-TxIA for variance compliance P-02A (PTO #2000840): MITIA pre-MI swap S-114A (PTO #2021980): MITIA for variance compliance Please call with any questions. «MIT PBU WGI-09 03-12-07 .xls» «MIT PBU 04-17 03-12-07.xls» «MIT PBU P-02A 03-12-07.xls» «MIT PBU S-114A 03-12-07.xls» Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: P-02 no plot.BMP TIO plot.BMP Content-Type: image/bmp Content-Encoding: base64 20f2 4/17/20079:01 AM P-02 TIO 830x283 1 of 1 4/17/20078:25 AM Re: Wlìl-OlJ (PlD # 2061460), 04-17 (PTLJ #1860200), P-02A (PT... Subject: Re: WGI-09 (PTD # 2061460),04-17 (PTD #1860200), P-02A (PT #2000840), S-114A (PTD #2021980) MIT forms <7_ I From: James Regg <jimJegg@admin.state.ak.us> \CPf1 . Ib Ù 7 Date: Fri, 16 Mar 2007 16:42:19 -0800 Andrea - PBU P-02A (PTD 2000840) showed a 10% increase in tubing pressure during the pre-MJ swap MITrA. There was no pressure stabilization pressure during the 30 minute test. Please report back I month after beginning MI on the annulus pressures to make sure this is not an indication of communication (TIO pressure plot would be sufficient). Of course, any indication of annulus pressure communication must be reported to the Commissi¡Q~AlO 3 Rule 7. Jim Regg AOGCC Hughes, Andrea wrote: 5CA.l\\NEO MAR 2 7 2007 Jim, Tom and Bob, Please see the attached MIT forms for the following wells: WGI-09 (PTO # 2061460): MITIA post-initial injection 04-17 (PTO #1860200): CMIT-TxIA for variance compliance P-02A (PTO #2000840): MITIA pre-MI swap S-114A (PTO #2021980): MITIA for variance compliance Please call with any questions. «MIT PBU WGI-09 03-12-07 .xls» «MIT PBU 04-17 03-12-07.xls» «MIT PBU P-02A 03-12-07.xls» «MIT PBU S-114A 03-12-07.xls» Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 I of I 3/16/20074:46 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / P pad 03/13/07 Andrea Hughes T?:ør1 '5/IH Ð7Lf .ry;O"' 0<6' ¡,/ <{ o P ...-r-;. I ! ~('1 f~$SIA,'e. II\.Cf'~f€ w~ t t be ~~d ~ ~ J e.M.d 3//6107 Interval P/F Interval P/F TYPE TEST Codes M ::: Annulus Monitoring p ::: Standard Pressure Test R::: Internal Radioactive Tracer Survey A::: Temperature Anomaly Survey D ::: Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V::;:. Required by Variance T::: Test during Workover 0= Other (describe in notes) MIT PBU P-02A 03-12-07.xls ,. 1)7l(bþ' STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS o o [2] RECE'VED SEP 1 3 2006 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: DevelopmentP Stratigraphic Stimulate 0 a - Waiver 0 Time Extension 0 Anchoral: t: Re-enter Suspended Well 0 5. Permit to Drill Number: 200-0840 3. Address: Exploratory Service P 6. API Number: 50-029-22376-01-00 P.O. Box 196612 Anchorage. AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 87.9 KB P-02A ADLO-028288 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY FIELD Field/ PRUDHOE OIL POOL Pool 8. Property Designation: Total Depth measured 14410 feet Plugs (measured) None true vertical 8999.41 feet Junk (measured) None Effective Depth measured 14373 feet true vertical 8996 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20" 91.5# H-40 30' - 110' 30' - 110' 1490 470 SURFACE 3228' 10-3/4" 45.5# NT80LHE 32' - 3263' 32'-2841 ' 5210 2480 PRODUCTION 12374' 7-5/8" 29.7# NT95HS 31' - 12405' 31' - 8857' 8180 5120 LINER 317' 3-3/16" 6.2# L-80 12198' 12515' 8681' - 8947' 10160 10530 LINER 1891' 2-7/8" 6.16# L80 12515' - 14406' 8947' - 8999' 13450 13890 Perforation depth: Measured depth: 13460 - 14370 True Vertical depth: 8995 - 9007 - - " c 2.Gn~, 5GANNED SEP 1 ~j 'VI.; - Tubing: (size, grade, and measured depth) 4-1/2", 12.6#, L-80 12243' Packers and SSSV (type and measured depth) 7-5/8" HBBP PACKER 12178' o o o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 12019 740 o ~9 1W 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil' Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl o o Tubing pressure 1200 1318 13. ervice P WDSPl Contact Gary Preble Signature ! Title Data Engineer Phone 564-4944 Date 9/8/2006 lilGfNAL \~BDMS 8Ft SEP 1 4 1006 Submit Original Only r ....1" (" .... P·02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ***Continue WSR from 6/16/06*** Perf from 13,650'-13,700' and 13,550' - 13,580' using 2" TCP, Power Jet 6 spf, 60 deg. phasing. Perform weekly BOP tests. MU BHA w/ PDS memory logging tools in 2.2" carrier. RIH. ***Continue on 6/18/06*** from RIH and PDS memory logging tools in a 2.2" carrier. Log up @ 40 fpm from 13700' -13100' Flag CT @ 13,450' CTM. POOH. -30 ft correction. RIH w/TCP 2"x30' Power Jet 6 SPF, 60 Deg. Phasing Perforate 13,460' - 13,550' in 3 runs. WSR from 6/18/06*** protect well with 38 bbls 50/50 meth. CTU #5 Need to get a hold of town engineer for initial injection rate *** Job Complete***LEFT WELL SHUT IN*** BBLS 38 1 % KCL 6 50/50 METH 44 TOTAL ) ) AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 5C_EO JAN 112\)\)0 Was never dist. after completion in Dec 2000 Re: Distribution of Survey Data for Well P-02A PB 1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 12,300.00 I MD Window / Kickoff Survey: 12,454.00' MD (if applicable) Projected Survey: 12,906.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.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. I Ancho~e, AK 99518 t I / ) Date '1v~~ Signed U.fitI Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 08-Dec-05 ;\ (j \) - (J g ~ F.'I L ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ,..-, Co' I L ,- '<t&1 l kruS Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.lus;·~dm_Maunder@admln.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / P Pad 09/03/05 Donald Reeves ~ÐO"" O~ ~ Packer Depth weIlIP-02A I Type Inj. Is TVD I 8,665' Tubing P.T .D. 2000840 Type test P Test psi 2166 Casing Notes: Four year AOGCC MITIA - declied by Chuck Scheve OA Pretest 200 270 o Initial 350 2,500 o 15 Min. 30 Min. 250 175 Interval 2,440 2,410 P/F o 0 4 P weill I Type Inj. I I TVD I Tubing Interval I P.T.D. Type test Test psi Casing P/F Notes: OA weill Type Inj. I TVD I Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA weill I Type Inj. I TVD I Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA weill Type Inj. I TVD I Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) SC.l~NNEL SEP í:~ ]. ;~OO:~ MIT Report Form BFL 9/1/05 MIT PBU P-02, 09-03-05,xls F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Permit to Drill 2000840 MD 14410 '-" TVD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. PRUDHOE BAY UNIT P-02A Operator BP EXPLORATION (ALASKA) INC 8999 ' Completion Dat 12/23/2000" Completion Statu WAGIN Current Status WAGIN APl No. 50-029-22376-01-00 UIC Y ~' REQUIRED INFORMATION Mud Log No Sample N._g_o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No (data taken from Logs Portion of Master Well Data Maint ED C GR Gamma Ray,,~ ...... ED D Ver LIS Verificationc._..-.-~ Rpt Ver LIS Verification ED D Ver LIS VedficatioE~,,~-~''''- ED C Cn See Note~..,,..~---' Interval OH I Start Stop CH 11973 14373 Case Received 11/16/2001 Dataset Number _..~_ _ m__m .e_nt_s ...... 10440,-..~ Rpt ~~-'- ED C Cn See Note~,,- Directional Survey ,nal Survey FINAL FINAL FINAL 1 1 1 1 12000 12682 CH 12460 14391 Case 12460 14391 Case 12442 12875 Case 12440 12906 Case 12442 12875 Case 12461 14410 Case 2/23/2001 2/23/2001 2/23/2001 712/2002 7/2/2002 7/2/2002 12/13/2002 7/2/2002 12/13/2002 Dir Survey Digital Data Dir Survey Paper Copy 12000-12682 Color Pdnt 11164 ~,~-~' 11165c'"1~ 11419 (..Di~l Well Logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity PB1 11418 Digital Well Logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity Well Cores/Samples Information: Name Start Interval Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 1/16~2003 Permit to Drill 2000840 Well Name/No. PRUDHOE BAY UNIT P-02A Operator BP EXPLORATION (ALASKA) INC MD 14410 TVD 8999 Well Cored? Y/~ Chips Received? ~ Analysis R ~.c.e. iv~.d ? Completion Dat 12/23/2000 Completion Statu WAGIN Current Status WAGIN Daily History Received? Y~ N Formation Tops ~'~/N APl No. 50-029-22376-01-00 UIC Y Comments: Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 16, 2002 MWD Formation Evaluation Logs ' P-02A PB1, AK-MW-00283 P-02A PBI: Digital Log Images 50-029-22376-70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY O1~ THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED DEC 1 2002 Alaska 0i~ & t3as Con~. 'Commission A~cho~ge To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 16, 2002 MWD Formation Evaluation Logs ' P-02A, AK-MW-00283 P-02A: Digital Log Images 50-029-22376-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED DEC 1 2002 Alaska Oi-~ & Gas Cons. WEI.I. LOG TRANSMITrAL To: State of Alaska April 25, 2000 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7a Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs P-02A & P-02A PB 1 AK-MW-00283 2 LDWG formatted Disks with verification listing. API#: 50-029-22376-01 & 50-029-22376-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED JU' 2. 2002 · AlaekaOil&Ga Cons. Schlmkerger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Al'iN: Sherrie 11/1,5/01 NO. 1634 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay,Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD 'L.-01 ~:~yT-~.,~:~--...': 21320 MDT 06119101 1 1 P-02A '~:~O-"~'~c~:' 21453 MGR 12/22/00 1 D.S. 15-16 /~c/--O~'7~L~ 21473 SCMT-A 10/26/01 2 D.S. 15-16 21473 SCMT-BB 10/26/01 2 F-22 / ~.--~O ~:,,,~ 21413 RST 09/14/01 D.S. 5-23A ~ O I"'/~>'~''' 21457 MCNL 10/16/01 1 1 1 D.S. 9-04A /C~,_.~,..(~)~;~ 21458 RST 10/18/01 1 1 1 D.S. 9-42A (qc]~...-~ 21459 RST 10/22/01 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 'BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED NOV 1 2001 Alaska Oil & Gas Cons. Commis,~n Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ^TEN: Sherrle STATE OF ALASKA "' ALASK ,JIL AND GAS CONSERVATION CO~w ~SlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 2001 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-084 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 . ~ 50-029-22376-01 4. Location of well at surface ........... .'. . LO(~'~I 9. Unit or Lease Name ... 2624' NSL, 2039' EWL, SEC. 31, T11N, R13E, UM '. '" , . ~_,~/)-~ Prudhoe Bay Unit At top of productive interval ! _../_~ ._' .z ~....__.O'~' ~,u ~ 65' NSL, 2487' EWL, SEC. 19, T11N, R13E, UM ~ .,....:;.:,.. :;.; ', At total depth I i,. ~ 10. Well Number 3784' NSL, 2672' EWL, SEC. 30, T11N, R13E, UM ! ...,~/2... t ..... ~ P-O2Ai · ~.,.'~L'~ ........... ,'TL..L-~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 87.90' ADL 028288 12. Date Spudded12/9/2000 113' Date T'D' Reached 114' Date c°mp'' susp'' °r Aband'l 2/19/2000 1 2/23/2000 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f c°mpleti°nsOne 17. Total Depth (MD+TVD) 1 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 14410 8999 FTI 14373 8996 FTI [] Yes [] NoI (Nipple) 2089' MDI 1900' (Approx.) 22. Type Electdc or Other Logs Run MWD, GR, ROP, RES, CBL, CCL 23. ' CASING, LINER AND CEMENTING RECORD .... CASING SE'CrlNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 110' 30" 280 cu ft Arcticset 10-3/4" 45.5# NT80LHE 35' 3263' 13-1/2"187 cu ft CS III, 63 cu ft Class 'G' 7-5/8" 29.7# NT95HS 31' 12405' 9-7/8" 1858 cu ft Class 'G' 5-1/2" 17# NT80S 12239' 12481' 6-3/4" 140 cu ft Class 'G' 2.7ia. x3-3/16. 6.16# L-80 12189' 14406' 3-3/4" 122 cu ft Class 'G' 24. Perforations pp. en to. Producti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and ~merva~, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 12243' 12178' MD TVD MD TVD 14243' - 14324' 8982' - 8991' 14350' - 14370' 8993'- 8995' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 25 Bbls of MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 1, 2001 Water Injection Date of Test Hours Tested PR~3DUCTION FOR OIL-BBL ' GAS. MCF WATER-BBL CHOKE SIZE I GAS'OIL RATIO " TEST PERIOD I ,, ,,, Flow Tubing Casing Pressure CALCULATED OIL'BBL GAS-MCF WATER'BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE"DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 ORIG!kI, ! Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Shubiik A 12475' 8916' Shublik B 12536' 8961' Shublik C 12567' 8980' ~,~ :~,, '.~,,;; ....,' .,,.,. .., Sadlerochit 12628' 9007' FE3 3 Z031 31. List of Attachments: Summary of Daily Drilling Reports, Surveys (Submitted by Vendor) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~_ '~~ Title Technical Assistant Date P-02Ai 200-084 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. h'EM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. h'EM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL l[ ~ ~--- ~-- 11 i i 111111 BP EXPLORATION FEB 3 7001 Page 1 of 12 Operations Summa Report Alaska Oil & Gas Cons. Commission Legal Well Name: P-02 i Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 12/3/2000 06:00 - 21:00 15.00 RIGU OTHR PRE Standby on P-09L1 waiting for I&E, wellhouse removal and blade and grade (required about 50 yds of gravel) location 21:00 - 22:00 1.00 RIGU PRE Move DS/N #1 from P-09L1 and spot over P-02 22:00 - 00:00 2.00 RIGU PRE Accept for operations at 2200 hrs 12/3/00. Remove tree cap. NU BOPE. Spot misc equipment. FC RU berm and spot slop tank 12/4/2000 00:00 - 00:30 0.50 RIGU PRE Fin NUBOPE. Phz 1 00:30 - 06:30 6.00 RIGU PRE Test BOPE. AOGCC waived witness 06:30 - 08:15 1.75 RIGU PRE Open well. On vacuum. Prep to PT inner reel valve and CTC. Phz 1/2. 08:15- 09:00 0.75 RIGU ClRC PRE Thaw frozen charge pump. 09:00 - 09:20 0.33 RIGU PRE PT inner reel valve. 09:20 - 09:45 0.42 STWHIP WEXlT MU cement stinger (BHA #1). 09:45 - 12:30 2.75 STWHIP WEXlT Attempt RIH. Tag swab. Swab not fully open (18 turns). Required pipe wrench to get it open four more turns. RIH circulating. Got returns immediately. Hole full. Try injectivity. 2.0 BPM; 550 psi. Continue RIH circulating, losing about 0.5 BPM. Tag whipstock 12511' CTM. Correct (-21') to 12490'. 12:30 - 12:45 0.25 STWHIP WEXlT Est inj at 1.5 BPM; 500 psi steady. 12:45 - 13:15 0.50 STWHIP WEXlT Safety meeting with cementers. 13:15 - 13:45 0.50 STWHIP SEQP WEXlT Prep for cement job. Attempt to PT cement lines. Chunk of cement blocking one of the cementers valves. 13:45 - 16:00 2.25 STWHIP WEXlT Pump 5 bbls water and PT cement lines. Mix and pump 40 bbls 17 ppg G cement: 10 bbls neat, 25 bbls w/20 ppg aggregate, 5 bbls neat. Displace at 3 bpm. Close choke with cement 10 bbls from nozzle. With nozzle floating at 12485', bullhead cement to perfs at 2.0 BPM; 800 psi. Saw P-response with cement 4 bbls out nozzle (2 bbls out perfs). Let WHP increase to 1200 psi. Est 12 bbls behind pipe. Bleed 2 bbls to pits. Lay in remaining cement 1:1 with WHP at 1200 psi. No losses to formation while laying in cement. Pull to safety. Park. 1200 psi sqz holding solid. 18:00 - 17:00 1.00 STWHIP WEXlT Jet down to 12420' with 1.5 ppb biozan at 3 BPM. Repeat pass in casing. Chase OOH. Flag pipe 12300' EOP. 17:00 - 19:00 2.00 STWHIP WEXlT POOH, washing across jewelry. 19:00 - 21:35 2.58 STWHIP WEXlT RIH w/used 3.80" window milI-BHA #2 21:35 - 22:05 0.50 STWHIP WEXlT Tag XN @ 12242' CTD. PUH 45K, start motor. Stall at 12239' CTD. Corr to 12230' ELMD. Mill XN nipple in 20 min. Dress up 22:05 - 22:20 0.25 STWHIP WEXlT RIH at rate looking for TOC. Found prior flag at 12410' (should have been 12385.1' on this run-must have had some slippage during cement ops). Did not correct. Found hard cement at 12438'. PUH and reflag at 12300' EOP 22:20 - 00:00 1.67 STWHIP WEXlT POOH 12/5/2000 00:00-00:30 0.50 STWHIP WEXlT Finish POOH. Phzl/2 00:30 - 00:50 0.33 STWHIP WEXlT LD mill (3.80"). MU UR assy. Comp str=2000 psi 00:50 - 03:05 2.25 STWHIP WEXlT RIH w/BHA #3 03:05 - 03:30 0.42 STWHIP WEXlT Corr to flag -14.1'. RIH @ min rate and tag at 12434' CTD. Muse, muse. Corr to 12438'. PUH 45K to 12270' and start pump. Open blades and dress liner w/o resistance 12260-438', 2.5/2400 03:30 - 05:00 1.50 STWHIP BHA WEXlT Underream cemert from 12438-441'. First 2' acted normal at 20'/hr. After stall and PU started stacking with no steady motor work. Had to push to stall motor' 05:00 - 07:30 2.50 STWHIP BHA WEXlT POOH to check BHA 07:30 - 08:00 0.50 STWHIP BHA WEXlT LD BHA. UR looks like it never opened up (packed with cement). Circumferential grooves on tool (aggregate?) from milling 2' pilot hole. Printed: 1126/2001 4:33:33PM BP EXPLORATION FEB 2 3 200I Page 2 of 12 Operations Summary ReportAlaska Oil & Gas Cons. Commission Anchora~ie Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 121512000 07:30 - 08:00 0.50 STWHIP BHA WEXIT Body cracked. 08:00 - 11:00 3.00 STWHIP BHA WEXlT Call for another UR. Rig-up MWD to get us a tie-in. Phz 2 11:00 - 13:00 2.00 STWHIP BHA WEXIT MU another Reeves UR on MWD (BHA ~4). RIH. Tie-in at flag. Correct depth (-20'). 13:00 - 13:15 0.25 STWHIP BHA WEXIT Est circ. 2.6 BPM/3450 psi. RIH and tag lightly 12427°. PU. BHA started moving at 12424'. 13:15 - 14:30 1.25 STWHIP WEXIT Log up 2.5/3150 for tie-in. Good overlay. Correct depth +16' minus 3' stretch for up pass -- +13'. 14:30 - 15:30 1.00 STWHIP WEXIT Mill cement with UR from 12440' - 12452' avg 50 FPH, 1000 WOB, 250 psi motor diff. Make repeat pass. Pump 15 bbl sweep. 15:30 - 15:45 0.25 S'I'VVHIP WEXlT Log tie-in down to verify up log. No correctioin. TOC @ 12452' corrected depth (9/12~93 jewelry log). 15:45 - 16:30 0.75 STWHIP WEXIT Chase pill to surface before pulling through tail. 16:30 - 17:00 0.50 STWHIP WEXlT Drop pumps to close UR and POOH. Stuck at 12260' (UR 17' below tail). Can't go up or down. Start pumping. Not stalled. Work tools. Broke free going down. PUH dragging. Circulate to clean-up around BH^. SD. PUH clean through tail. POOH. 17:00 - 17:45 0.75 STWHIP OCOL WEXIT Fix level-wind override pawl. 17:45- 19:45 2.00 STWHIP WEXIT POOH. 19:45 - 21:10 1.42 STWHIP WEXIT LD UR assy (nothing missing and no scars). Change MWD probe. MU one step milling assy on 2.5 deg motor wi MWD 21:10 - 23:10 2.00 STWHIP WEXIT RIH w! BHA #5 23:10 - 23:30 0.33 STWHIP WEXIT Tag at 12463' CTD. PUH 53.6k and start motor. Orient around 23:30 - 00:00 0.50 STWHIP WEXIT RIH and mill 2' at 68R. Corr to 12454', flag (white) 12/6/2000 00:00 - 13:30 13.50' STWHIP WEXlT Time mill window per schedule. Phz 2. Drill formation 15 - 20 FPH. Pump 30 bbl sweep. Back ream window. Tie-in. Correct depth (+2'). SD pumps for Sag flow test. No flow. Dry tag clean. Window 12,457' - 12465'. Formation drilled to 12474'. 13:30- 16:15 2.75 STWHIP WEXlT POOH. Phz 112 16:15 - 17:15 1.00 STWHIP WEXIT LD motor/mill. Good center wear on mill. MU 1.75 deg motor and tapered mill. 17:15 - 19:15 2.00 STWHIP WEXIT RIH w! BHA #6 19:15 - 19:20 0.08 STWHIP WEXIT Corr-10' at 12010'. RIH 19:20 - 19:40 0.33 STWHIP WEXIT Begin tie-in to GR @ 12399", corr-5', 120R 19:40 - 20:15 0.58 STWHIP WEXlT Orient around. 2% KCl water=2.6/2430 8.64 ppg 'in', 8.42 ppg 'out', 53.5K 20:15 - 22:05 1.83 STWHIP . WEXlT Ream window at 41 R, 2.6~2430 from first stall at 12455.6'-12470.9' and acted like formation. Backream, clean 22:05 - 23:05 1.00 STWHIP. WEXIT Start Aphron mud system and ream thru at 63R to 12471.3', backream clean 23:05 - 23:45 0.67 STWHIP !WEXIT Ream thru at 86R to 12471.9', backream clean 23:45 - 00:00 0.25 STWHIP WEXlT Ream thru at 108R to 12471.6'. Aphrons=2.5/3550 8.92 ppg 'in', 8.65 ppg out, 37k. Gonna be marginal for drilling using CT pressure limits. Phz 112 1217/2000 00:00 - 00:10 0.17 STWHIP WEXlT RIH w/o pump to 12472' (clean) 00:10 - 00:45 0.58 STWHIP WEXIT POOH for drlg assy. Phz 1/2 wind 24-40 mph 00:45 - 02:40 1.92 STWHIP WEXIT Pinhole at 10250' (10125' EOP). 670k RF. POOH filling from BS !02:40 - 04:00 1.33 STWHIP WEXIT LD drilling BHA. Tapered mill in gauge. MU nozzle '04:00 - 06:00 2.00 DRILL PROD1 Displace CT to N2 and bleed off pressure 06:00- 13:00 7.00 DRILL WIND PROD1 Begin Standby. WOW (wind 24-42 mph) for crane 13:00 - 14:30 1.50 DRILL COIL PROD1 Pull back coil to reel and secure (zero rig rate). Phz 1 14:30- 17:30 3.00 DRILL WIND PROD1 Resume Standby. Winds calming down a bit. Get crane moving. 17:30 - 20:00 2.50 DRILL REEL PROD1 End Standby (zero rig rate). Position crane for reel pick. Swap reels. Pdnted: 1/26/2001 4:33:33PM BP EXPLORATION FEB 2 3 ~0~ge 3 of 12 Operations Summary Report A~s~aOil&G~s Cons. Commis:ion Anchora.~e Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 12/7/20oo 17:3o - 20:00 2.50 DRILL REEL PROD1 Found problem with carrier pin. Remove reel motor drive plate. Will require machine work. 20:00- 00:00 4.00 DRILL REEL PROD1 Begin Downtime for machine work 12/8/2000 00:00 - 00:00 24.00 DRILL REEL PROD1 WO repair of reel drive pin Conduct Prespud mtg Slip and cut drlg line 12/9/2000 00:00 - 02:00 2.00 DRILL REEL PROD1 Fin repairs 02:00- 03:30 1.50 DRILL REEL PROD1 Install drive assy 03:30 - 06:00 2.50 DRILL REEL PROD1 Pull CT to injector and stab. Install CTC. Hook up hardline to reel 06:00 - 06:30 0.50 DRILL REEL PROD1 Fill CT w/mud and pump dart. Dart hit at 57.4 bbl. 08:30 - 07:00 0.50 DRILL REEL PROD1 Pull test and pressure test CTC - OK. End of rig repair period at 07:00 hrs. 07:00 - 08:00 1.00 DRILL PROD1 MU drilling BHA. M09X, 2.9 deg motor, shock sub MWD/GR. MU injector. 08:00 - 10:45 2.75! DRILL PROD1 RIH with build assembly to 12415' and correct to 12400'. 10:45 - 11:00 0.25 DRILL PROD1 Orient around to 35R to exit window. 11:00 - 11:15 0.25 DRILL PROD1 RIH - no pump and tag up at 12470' - saw slight bobble at 12454' - may be top of cement whipstock. Pull up hole to start logging down from 12410' bit depth for tie-in. 11:15 - 11:45 0.50 DRILL PROD1 Log down from 12410' bit depth and make correction (+8'). SD pump and exit window - OK. Tag bottom. 11:45 - 13:45 2.00 DRILL PROD1 Start drilling. 2.6/2.6 bpm. 3950 psi. 60R. ROP 30 fph. Get 2 clicks. Drill to 12523'. Get 1 click. Started seeing losses at 12525'. 2.5 in/2.2 out. 3800 psi. 62R. 45-75 fph. 13:45 - 15:15 1.50 DRILL PROD1 Continue drilling ahead monitoring losses. Levelled out at 12535' - well may be breathing slightly. 12566': 2.5/2.5 bpm. 3900 psi. 62R. 15-20 fph. Pump pressures continue to be v. high and we are running very close to pump trip limits. Any additional motor work trips pumps. 15:15 - 17:30 2.25 DRILL PROD1 Reduce pump to 2.4 bpm & PP to 3700 psi - try there. 12605': 2.4/2.4 bpm. 3800 psi. 52R. 18-20 fph - (Shublik). No further losses noted. 17:30 - 21:25 3.92 DRILL PROD1 Cont drilling in Shublik 15-25'/hr. Get 1 click at 12610' for 70R. Penetrate Zone 4 @ 12630' and P rate incr to 50-90'/hr 2.4/3600/80R. Drill to 12741' 21:25 - 21:35 0.17 DRILL PROD1 Wiper to window. Not getting required turn or build after entering Zone 4 21:35- 23:50 2.25 DRILL DIR PROD1 POOH for motor, Phz 1 23:50- 00:00 0.17 DRILL DIR PROD1 Change motor 12/10/2000 00:00 - 00:30 0.50 DRILL DIR PROD1 Change motor from 2.85 to 2.6 deg SR 00:30 - 02:30 2.00 DRILL DIR PROD1 RIH w/BHA #8 02:30 - 03:00 0.50 DRILL PROD1 Corr -10' @ 12410'. RIH and set down at 12425'? Log tie-in at GR spike @ 12399'. 2.4/3500/160L. Found counter had slipped (new pipe). Correct to ELMD. Clean 'out' MM. WHP was as high as 100 psi causing losses of 0.3 bpm 03:00 - 03:15 0.251 DRILL PROD1 Orient to 51R and go thru window clean 03:15 - 03:30 0.25 DRILL PROD1 Precautionary ream to TD at 12742' 03:30 - 04:05 0.58 DRILL PROD1 Orient from 22L to 45R in one click. Drilling 70'/hr to 12780' 04:05 - 04:50 0.75 DRILL PROD1 Drilling 80'/hr @ 68R until 12795'. Work 30 rain to make a foot. 04:50 - 05:20 0.50 DRILL PROD1 Wiper to window. Phz 1/2 05:20 - 10:30 5.17 DRILL PROD1 Resume making slow hole 2.4/3600/74R 12812': 2.5/2.5 bpm. 3930 psi. 68R. 12-15 fph. Samples show drilling clay. Continue slower drilling to 12906' and finish build/turn section. Printed: 1/26/2001 4:33:33PM BP EXPLORATION FEB 2 3 ZOO1 Page4of12 Operations Summary Rep [ a oil & c, as cons. Commission Anchora,qe Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 12/lO/2000 10:30 - 13:3o 3.00 DRILL PROD1 POH for bit & BHA change. Flag pipe at 11200' EOP. 13:30- 15:45 2.25 DRILL PROD1 OOH. Stand back injector. LD bit, motor, shock sub. MU bit #2 DS49, 1.1 deg motor, MWD EWR/GR. Programme EWR. MU injector. 15:45 - 18:00 2.25 DRILL PROD1 RIH. Saw bobble on wt at 12445'. Top or bottom of window. Pull up to tie in. 18:00 - 19:00 1.00 DRILL PROD1 Log down from 12370' uncorrected bit depth, add 11'. RIH and begin MAD pass and stalled at 12489' at 22R. Corrected wrong direction... 19:00 - 20:00 1.00 DRILL DIR PROD1 Attempt to get by bottom of window at 22R, 48R, 64R, 107R, 18L w/o SUCCESS 20:00 - 22:10 2.17 DRILL DIR PROD1 POOH for reamer 22:10 - 23:55 1.75 DRILL DIR PROD1 LD drilling BHA (bit like new). Download resistivity tool. MU 3.80" tapered mill w/3.80" string reamer w/MWD on 1.1 deg motor 23:55 - 00:00 0.08 DRILL DIR PROD1 RIH w/BHA #10 12/11/2000 00:00 - 02:05 2.08 DRILL DIR PROD1 RIH w/BHA #10 02:05 - 02:25 0.33 DRILL DIR PROD1 Tie-in to GR @ 12399', corr -15'. 2.3/3200/90L 02:25 - 02:40 0.25 DRILL DIR PROD1 Orient 02:40-03:05 0.42 DRILL DIR PROD1 Try to get in window 27R, 43R, 76R, 102R. Set down below lip each time. 03:05- 05:10 2.08 DRILL DIR PROD1 POOH 05:10 - 06:00 0.83 DRILL DIR PROD1 LD BHA. Cement on nose of tapered mill 06:00 - 17:00 11.00 DRILL PROD1 Weekly BOPE test. Witness waived by AOGCC Rep J. Jones. Test choke manifold while waiting on grease crew to grease swab and master valve. Continue with test after grease crew greased tree valves. 17:00 - 18:00 1.00 DRILL DIR PROD1 WO engineering to finalize plan forward 18:00 - 19:00 1.00 DRILL PROD1 MU 3.80" pilot mill on 1.75 deg motor .19:00 - 21:20 2.33 DRILL PROD1 RIH w/BHA #11 21:20 - 21:50 0.50 DRILL PROD1 Corr -10' at 12420'. Begin tie-in to GR at 12399'. Corr additional -9'. 2.4/2980/41 R 21:50 - 22:25 0.58 DRILL PROD1 RIH at rain rate to set down at 12475' at 41R. PUH and had 10k overpull (clean on down pass thru window). Chk TF @ 58R. Get 1 click. Try it again at 75R and set down at 12466'. Chk TF @ 8OR. Get 1 click. Try it again at 92R. Set down at 12466'. Chk TF @ 95R 22:25 - 22:40 0.25 DRILL PROD1 Orient around to verify first tag 22:40 - 23:00 0.33 DRILL PROD1 Try at 24R and got to 12466'. At 41R got to 12466'. Chk TF @ 41R. Muse-must have got lucky earlier, but proves we can still exit window 23:00 - 23:10 0.17 DRILL PROD1 Orient 180 out 23:10 - 23:15 0.08 DRILL PROD1 Try it at 128R and set down at 12466'-good cement to here 23:15 - 23:45 0.50 DRILL PROD1 Discuss w/D Hearn-will give up trying to salvage this window and cut a new one.. Begin tie-in, 2.5/3200/122L, add 2'. 23:45 - 00:00 0.25 DRILL PROD1 Begin time mill at 12450' 1.0'/min 2.5/3200/122L. Phz 1 12/12/2000 00:00 - 00:15 0.25 DRILL PROD1 Got motor work at 12467' and had to slow P rate to 0.5'/min. Got reactive to 173R. Mill to drill offat 12470'. Phz 1 00:15 - 01:15 1.00 DRILL PROD1 Repeat dressing 12450-470' three more times at 122L 01:15 - 01:45 0.50 DRILL PROD1 Mill firm cement from 12470-475' @ 122L 01:45 - 02:45 1.00 DRILL PROD1 Dress 12450-472' at 1.0'/rain 2.5/3160/116L. On second pass had stall at 12470'. PUH 02:45 - 02:55 0.17 DRILL PROD1 Tie-in 2.4/3050/111 L, no corr 02:55 - 03:55 1.00 DRILL PROD1 Start dressing again from 12450-472'. Motor work at 12470.6' and 12471.6' first pass. Next two clean 03:55- 04:10 0.25 DRILL PROD1 Orient 04:10 - 04:20 0.17 DRILL PROD1 Begin tie-in 2.4/3000/30R, no corr 04:20 - 04:45 0.42 DRILL PROD1 RIH 20'/min to 12475' at 35R. TF was 10R at TD. PUH, get two clicks. RIH at 75R to 12475'. Mill cement ramp from 12475-478' at 0.3'/min, Printed: 1/26/2001 4:33:33 PM BP EXPLORATION Page 5 of 12 FEB 3 001 Operations Summary Report ^les[ia 0il & Gas Cons. Commission Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 12/1212000 04:20 - 04:45 0.42 DRILL PROD1 600 psi diff at avg 35R 04:45 - 05:20 0.58 DRILL PROD1 Dress from 12447-472' 2.613230/69R three times 05:20 - 05:30 0.17 DRILL PROD1 Flag at 12472' bit and 12300' EOP 05:30 - 07:15 1.75 DRILL PROD1 POOH for one step mill 07:15 - 07:45 0.50 DRILL PROD1 OOH. Stand back injector. LD BHA. 07:45 - 12:30 4.75 DRILL BARR PROD1 Tear choke manifold downstream line apart looking for obstruction causing back pressure on well when circulating. Snake lines as far as possible and can find no restriction. Found paddle on gate valve that was not fully retracting - may be 3roblem. Clean and re-assemble valve and piping. 12:30 - 13:10 0.67 STWHIP WEXIT MU milling BHA. 13:10 - 15:00 1.83 STWHIP WEXlT RIH. Tie in to flag. Tag up at 12480'. Pull up hole and tie in. Make +1' correction. Go back down and tag at 12481'. Pull up 1' and start time milling window per schedule. 15:00 - 20:00 5.00 STWHIP WEXIT Mill new window in time drilled 0.1' increments. TF 55R. 20:00 - 00:00 4.00 STWHIP WEXlT Mill new window. Time drill as per procedure. TF -- 55R. 12/13/2000 00:00 - 02:00 2.00 STWHIP I WEXlT Mill new window as per procedure. TF = 55R. 2.4 BPM, 3010 psi, Time 02:00 - 03:00 1.00 STWHIP WEXIT Mill window at 2 FPH, 2500# WOB, 2.4 BPM, 3250 psi, 60 R TF. 03:00 - 04:45 1.75 STWHIP WEXlT Saw increase in ROP at 12487 ft. Window from 12481 - 12487 ft. D ~ formation at 6 FPH, from 12487 - 12495 ff. 5000# WOB, 55R TF. 2.4 BPM, 3250 psi. 04:45 - 07:00 2.25 STWHIP WEXIT POOH for mill and motor change out. 07:00 - 08:00 1.00 STWHIP WEXlT OOH. Stand back injector. LD mill & motor. MU 3.79" tapered mill & 1.75 deg motor on BHA and RIH. MU 'injector. 08:00 - 11:00 3.00 STWHIP OTHR WEXIT Replace multiple broken pins in injector head drive chains. 11:00 - 13:00 2.00 STWHIP WEXlT RIH with mill to dress window. 13:00 - 14:00 1.00 STWHIP WEXIT Dry tag at 12500' and correct depth to 12495' - assume TD. PUH to 12400' and log down to tie in. Correction: (-13'). 14:00 - 16:30 2.50 STWHIP WEXIT Start milling to clean up window. Window appears clean. Back ream @ 10-20 fph in each quadrant from 12489' up to 12479'. Pull up to 12450' and RIH to 12493' dry. TD tag -window appears fine. 16:30 - 18:40 2.17 STWHIP WEXlT POH for drilling package. 18:40 - 19:00 0.33 STWHIP WEXIT Lay out milling BHA. Taper mill at full gauge, 3.80". 19:00 - 20:00 1.00 DRILL PROD1 MIU MWD BHA #13 with 2.6 deg short radius motor, Bit #1RR, M09BQPX. 20:00 - 23:00 3.00 DRILL PROD1 RIH with BHA #13. 23:00 - 23:40 0.67 DRILL PROD1 Logged Tie-in with GR, -20 ft CTD to correct to AWS GPJCCL of 9/12/93. 23:40 - 23:50 0.17 DRILL PROD1 Orient TF to 35R. 23:50 - 00:00 0.17 DRILL PROD1 RIH with no pump. Went thru window OK. RIH to 12492 ft. Start pump, 2.5 BPM at 3200 psi. TF-- 57R. 12114/2000 00:00 - 02:00 2.00 STWHIP PROD1 Drilling build section, 52R TF, 2.5 BPM, 3300 psi, 14 K dwn wt, 40 k up wt. Swap to new mud while drilling. Drilled to 12545 ft. 02:00 - 04:20 2.33 DRILL PROD1 Drilling, TF = 74R, 25 FPH, 2.4 BPM, 3300 psi, Drilled to 12590 ft 04:20 - 06:00 1.67 DRILL PROD1 Drilling, TF = 74R, 25 FPH, 2.4 BPM, 3300 psi, Drilled to 12616 ft 06:00 - 07:45 1.75 DRILL PROD1 Drilling, TF-- 85R, 25 FPH, 2.4 BPM, 3300 psi. Drill to 12689'. 07:45 - 08:00 0.25 DRILL PROD1 Short trip to window. Hole condition good. 08:00 - 08:15 0.25 DRILL PROD1 Orient up above window and run back to bottom. Took weight going thru window. 08:15 - 10:00 1.75 DRILL PROD1 Drill ahead: 12775': 2.4~2.4 bpm. 3550 psi. 70R. 120-140 fph. Cont drilling to 12843'. 10:00 - 10:15 0.25 DRILL PROD1 100' wiper trip - OK. .J Printed: 1/26/2001 4:33:33PM BP EXPLORATION FEB ~, 3 ~001 Page6of12 Operations Summary ReportAia~ka oil & Gas Cons. Commission Anchora,qe Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC I Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 12114/2000 10:15 - 11:00 0.75 DRILL PROD1 Drill ahead: 12850'. 2.4~2.4 bpm. 3500 psi. 97R. 50-60 fph. 12885'. 2.4/2.4 bpm. 3600 psi. 102R. 50-60 fph. End of build/turn at 12885' MD. Landed at 8951' TVD. 11:00 - 13:30 2.50 DRILL PROD1 POH for BHA change. 13:30 - 14:15 0.75 DRILL PROD1 ;OOH. Stand back injector. Change bit and motor. LD shock sub. MU HYC DS49 (RR), 1.1 deg motor, MWD. MU injector. 14:15- 16:30 2.25 DRILL PROD1 RIH. 16:30 - 17:00 0.50 DRILL PROD1 Log down from 12410' bit depth. Correction (-7'). 17:00 - 17:10 0.17 DRILL PROD1 Run thru window - slight bobble. RIH to bottom. 17:10 - 17:20 0.17 DRILL PROD1 Drill to 12906' - depth of original hole. Revert to planned time. 17:20 - 18:40 1.33 DRILL PROD1 Drill ahead in Z4. 12910': 2.4~2.4 bpm. 3800 psi. 50R. 100-120 fph. 12945': 2.5~2.5 bpm. 3450 psi. 90R. Drilling with -8000 to -12000 lbs string wt. 18:40 - 20:20 1.67 DRILL PROD1 Drilling, still drilling with negative wt at surface, add 2 drums of friction reducer. 2.4 BPM, 3100 psi, 80 FPH, 47 K up wt. Drill to 13,005 ft. Overpull. Stacking wt. 20:20 - 21:30 1.17 DRILL PROD1 Short trip to window. RIH to TD. Hole clean. 21:30 - 23:40 2.17 DRILL PROD1 Drilling, TF = 83R, 2.5 BPM, 3200 psi, 100 FPH. stacking wt. Drilled to 13,117 ft. 23:40 - 00:00 0.33 DRILL PROD1 Short trip to window. RIH to TD. Hole clean. 12/15/2000 00:00 - 00:30 0.50 DRILL PROD1 RIH to TD. Hole was clean. 00:30 - 01:00 0.50 DRILL PROD1 Drilling, 110 FPH, 100R TF, 2.5 BPM, 3400 psi, Drilled to 13,177 ft. 01:00 - 01:20 0.33 DRILL PROD1 Orient TF to 90L. 01:20 - 02:30 1.17 DRILL PROD1 Drilling, 97L TF, 2.5 BPM, 3400 psi, 110 FPH ROP. Drilled to 13,250 ft. Stacking wt. 02:30 - 03:40 1.17 DRILL PROD1 Short trip to window, up wt = 44K, dwn wt = 12K. RIH to TD. 03:40 - 04:50 1.17 DRILL PROD1 Drilling, TF = 90L. 100 FPH, 2.4 BPM, 3200 psi. Drilled to 13290 ft. 04:50 - 06:00 1.17 DRILL PROD1 Drilling, TF -- 90L. 100 FPH, Drilled to 13,342 ft. 06:00 - 06:45 0.75 DRILL PROD1 Drill to 13392'. Drilling with negative wt in clean sand. 06:45 - 07:45 1.00 DRILL PROD1 Wiper trip to window and back to bottom. Hole appears clean. 07:45 - 09:30 1.75 DRILL PROD1 Drill to 13410'. Slid OK for a few feet but now cannot get good weight transfer - continuous stalls trying to get on bottom. Get it drilling for a while. 13430': 2.5/2.5 bpm. 3600 psi. 108L. 100 fph. Losing mud over shakers. Struggle down to 13460'. 09:30 - 12:00 2.50 DRILL i PROD1 Trip up to window to try and. clean up hole. Order up a new FIo-Pro system from MI plant. Current system has >1000' drilled. 12:00 - 13:10 1.17 DRILL PROD1 Drill ahead - good weight transfer initially with ROP 90-100 fph. Continue drilling but increasing problems with weight transfer. 13545': 2.4/2.4 bpm. 3500 psi. 80L. 60-100 fph. 13:10 - 13:45 0.58 DRILL PROD1 Cont drilling ahead while pumping 20 bbl aphron pill with 2 drm lechithin to CT. Cont trying to drill - no change as pill went out bit to annulus. Unable to make further progress below 13555'. 13:45 - 14:45 1.00 DRILL PROD1 Wiper trip up to window. 14:45 - 16:00 1.25 DRILL PROD1 Pull up to 12410' and log back down for tie in pass. Correction: (+28'). 16:00 - 17:00 1.00 DRILL PROD1 RIH to bottom. Printed: 1/26/2001 4:33:33 PM FEB BP EXPLORATION 7 of 12 Operations Summary Report Alnska 0il & Gas Cons. Commission Anchorage Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 1211512000 17:00 - 17:15 0.25 DRILL PROD1 Orient for 90L. 17:15 - 18:00 0.75 DRILL PROD1 Drill ahead and start displacing new FIo-Pro down CT. Same problem with weight transfer as before before new mud reached bit & drilling with -ve wt. New mud improved situation some and now drilling with +ve wt. 13623': 2.5~2.5 bpm. 3500 psi. 125L. 70-100 fph. 18:00 - 19:50 1.83 DRILL PROD1 Drilling, TF -- 108L, ROP = 60 FPH, 2.5 BPM, 3100 psi, CT sliding well now. drilling with 12K positive wt at surface. drilled to 13724 f. 19:50 - 21:30 1.67 DRILL !PROD1 Short trip to window. Hole clean. RIH to TD. Full returns. 21:30 - 23:50 2.33 DRILL PROD1 Drilling, TF = 102L, 2.6 BPM, 3200 psi, 110 FPM, Zone 4 sand. Drilled to 13,900 ft. 23:50 - 00:00 0.17 DRILL PROD1 Short trip to window. 1211612000 00:00 - 01:00 1.00~ DRILL PROD1 RIH to TD. Hole clean. 01:00 - 01:30 0.50 DRILL PROD1 Orient TF to 100R. 01:30 - 01:45 0.25 DRILL PROD1 Safety Meeting, review safe driving, slips / trips and frost bite with all personnel. ,01:45 - 04:30 2.75 DRILL PROD1 Drilling, TF -- 100R, 80 FPH. Several overpulls at 13,940 ft. Stack wt at that depth, overpull off bottom. Drill ahead stacking wt. Several overpulls from shales at 13,920 ft. Drill to 14,000 ft with negative wt at surface. Cleaned up shale with about 10 passes thru shale section. 04:30 - 05:00 0.50 DRILL PROD1 Drilling, TF = 90R, 60 FPH. Stack wt, Overpull. Drilled to 14,019' 05:00 - 06:00 1.00 DRILL PROD1 Short trip to window, Hole clean. Park bit at 12,500 ft 06:00 - 11:00 5.00 DRILL REEL PROD1 Drill out and replace broken bolts in reel stand where hydraulic reel motor clamps to reel stand on driller side. 11:00 - 12:00 1.00 DRILL PROD1 Pull up above window to 12390' and Icg back down to tie in for depth correction: (+26'). 12:00 - 13:00 1.00 DRILL PROD1 RIH to bottom. 13:00 - 13:15 0.25 DRILL PROD1 Orient for 90R. 13:15 - 14:15 1.00 DRILL PROD1 Drill ahead with +ve 2-5K string wt dribbling in 1 drum lubetex. 14050': 2.3/2.3 bpm. 3500 psi. 75R. 50-80 fph. Z4 sand. Drill to 14085'. 14:15 - 15:45 1.50 DRILL PROD1 Circ up sample for geology. Looking for Shublik. Short trip while CBU. No Shublik in sample but pyrite indicates very top Z4. 15:45 - 16:15 0.50 DRILL PROD1 RIH to bottom to turn well down. Current TVD is 8883' ~ 14085' MD. 16:15 - 17:15 1.00 DRILL PROD1 Drill ahead. Making no progress. Appear to be getting weight to bottom :and getting some differential but no drill-off. Bit may be balled or damaged from pyrite. Drilled to 14,087 ft. 17:15 - 20:00 2.75 DRILL PROD1 POH to check bit & BHA for problems or damage. 20:00 - 21:15 1.25 DRILL PROD1 =Change out motor, bit, MWD and orientor. Bit was 1-1-1 21:15 - 23:30 2.25 DRILL PROD1 RIH with MWD BHA #15, 1.0 deg bend motor, DS49 bit #5. 23:30 - 00:00 0.50 DRILL PROD1 Tied-in with BHCS/GR at 12397 ft, [ - 23 ft CTD] 12/17/2000 00:00-01:00 1.00 DRILL PROD1 'RIHto 14086 ft. Clean holetoTD. 12Kdwnwt. OrientTFtolowside. 01:00 - 03:00 2.00 DRILL PROD1 . Drilling, slow steady progress. ROP = 20 FPH. Drilled to 14100 ft. 'Mud pump started leaking. Picked up and changed mud pumps. RIH. Bit balled. Un-ball bit. 03:00 - 04:45 1.75 DRILL PROD1 , Drilling, TF = 167R, 40 FPH, 2.4 BPM, 3300 psi. Drilled to 14152' 04:45 - 05:15 0.50 DRILL PROD1 Drilling, TF '- 161R, 50 FPH, 2.4 BPM, 3300 psi, Drilled to 14175' 05:15 - 05:45 0.50 DRILL PROD1 Orient around to 90R. 05:45 - 06:30 0.75 DRILL PROD1 i Drilling, TF = 90R, 50 FPH, Drilled to 14,205 ft. 84 deg incl. 06:30 - 09:15 2.75 DRILL PROD1 !Drilling, TF = 105R. 14225': 2.4/2.4 bpm. 3800 psi. 77R. 30-40 fph. +ve string wt. Printed: 1/26/2001 4:33:33 PM BP EXPLORATION FEE~ ~ 3 ;~0.1:,ageR1 8 of 12 Operations Summary Report Alaska Oil & G~s Cons. Commission Anch0rage Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 1211712000 06:30 - 09:15 2.75 DRILL PROD1 :Orient straight up. ~ 14250': 2.2~2.2 bpm. 3600 psi. 15R. 30 fph. -ve string wt. Increasing problems getting motor differential. Bit bailing? or cuttings beds? PP also has increased - 100 bbl new mud ordered with 6% lubetex for addition to system. 09:15 - 12:15 3.00 DRILL PROD1 Wiper trip to window. RIH to bottom. Work bit back to bottom - shales may have swelled. 12:15 - 14:15 2.00 DRILL PROD1 Drill ahead with 100 bbl new rio-pro w/6% lubetex going downhole. Unable to make any progress. Bit appears balled again. Spin just off bottom - no success. Set on bottom and just let it drill off. No progress. 14:15 - 15:15 1.00 DRILL PROD1 Pull up hole and try to clean bit off in clean sand. RIH to bottom. MWD quit working - giving anomalous pulses & pressures seem erratic. 15:15 - 18:00 2.75 DRILL PROD1 POH to check bit and MWD. 18:00 - 19:50 1.83 DRILL PROD1 CCH. Stand back injector. Bit was clean and undamaged but some white clay on BHA. Chg MWD probe, bit and shock sub, M/U new CTC. 19:50 - 22:00 2.17 DRILL PROD1 RIH with MWD BHA #16. 22:00 - 22:30 0.50 DRILL PROD1 Log tie-in with BHCS/GR, -20 ff CTD. 22:30 - 00:00 1.50 DRILL PROD1 RIH to TD. Sat down in shale at 14080 ft. Orient TF to 90R. RIH and ream down to 14,115 lt. 12/18/2000 00:00 - 01:30 1.50 DRILL PROD1 Ream shales at 14070 - 14215 ft. 01:30 - 03:30 2.00 DRILL PROD1 Ream shales at 14070 - 14223 ft. Unable to get past 14223 ft. 03:30 - 04:15 0.75 DRILL PROD1 Circulate in new FIoPro [old mud at 0.8% drill solids] 04:15 - 04:30 0.25 DRILL PROD1 Ream to TD of 14253 ft. Some motor work and stacking wt, but not near as bad. 04:30 - 06:15 1.75 DRILL PROD1 Drilling, TF = 90R, ROP -- 90 FPH, 2.4 BPM, 3300 psi, 84 deg incl. drilling with positive wt. Drilled to 14360 ft. 06:15 - 06:45 0.50 DRILL PROD1 Drilling, TF = 90R. Drill to 14368'. ROP decreasing - possible shale. 06:45 - 08:00 1.25 DRILL PROD1 Wiper trip to window. Occasional overpulls near bottom. POH slow to 14000'. Pull up above window to 12400' for tie in. 08:00 - 08:45 0.75 DRILL PROD1 Log down for GR tie-in for depth correction: (+22.5'). 08:45 - 09:45 1.00 DRILL PROD1 RIH to bottom. TD -- 14,384 ft. 09:45 - 11:15 1.50 DRILL PROD1 Attempt to drill ahead. Cannot make progress. Get motor differential on bottom but no drill off whatsoever as if stalled at v. Iow pressure. Sperry MWD has indications of Iow impeller RPM and trend worsening so possible washout above MWD in BH^. 11:15 - 14:15 3.00 DRILL OTHR PROD1 POH for inspection, pressure test, change out of BHA components. 14:15 - 15:15 1.00 DRILL PROD1 CCH. Stand back injector. Pressure test BHA, CT and connector to 3000 psi - all OK. Inspect equaliser and motor. Both appear to be in good shape - no sign of washing or excessive play in motor. Cannot find any obvious problem with BHA components. No reason found for Iow impeller RPM either. 15:15 - 20:00 4.75 BOPSUF PROD1 Test BOPE 300~3500 psi. Witnessing of test waived by AOGCC Rep Chuck Scheve. E-mail report to AOGCC. 20:00 - 20:45 0.75 DRILL PROD1 MIU MWD BHA #16 with 0.7 deg motor and DS49 bit # 20:45 - 23:00 2.25 DRILL PROD1 RIH with BH^ #16. Shallow test Sperry tools. RIH. 23:00 - 23:30 0.50 DRILL PROD1 Log tie-in with BHCS/GR. [-22 ft CTD]. 23:30 - 00:00 0.50 DRILL PROD1 RIH to TD. 12/19/2000 00:00 - 01:15 1.251 DRILL PROD1 Ream shales from 14060 - 14384 ft. 01:15 - 03:00 1.75, DRILL PROD1 Drilling, 130R, 2.2 BPM, 2600 psi, Spud several times, drilled 8 ft. Stopped drilling again, spud several times, change pump rate. Shale sand sequence. Unable to get enough WOB to drill shale. Sand drills OK. 03:00 - 03:30 0.50 DRILL PROD1 Drilling, Spud and make slow progress. Drilled to 14394 ft. Printed: 1/26/2001 4:33:33 PM BP EXPLORATION FEB 2 3 2001 Page 9 of 12 Operations Summary Repo la , a oit & Cons.Commisci0n Ancilorage Legal Well Name: P-02 .Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC I Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 12/19/2oo0 03:30 - 04:15 0.75 DRILL PROD1 Ream shales up to 14000 fi. Ream back to TD of 14394 ft. 04:15 - 05:15 1.00 DRILL PROD1 Drilling with new FIoPro in open hole w/5% Lubetex to reduce drag. Spud to get WOB. No progress. Depth = 14394' Uncorr. 05:15 - 06:30 1.25 DRILL PROD1 POH to window - had to break circ below window to get thru same. 06:30 - 07:15 0.75 DRILL PROD1 Log down for tie in and correct depth (+15'). 07:15 - 09:15 2.00 DRILL PROD1 POH. Flag pipe at 12300' bit depth. 09:15 - 09:30 0.25 DRILL PROD1 OOH. Stand back injector. Lay out BHA components. 09:30 - 10:45 1.25 DRILL PROD1 MU logging BHA # 18 with EWR/GR tool. Programme tool. 10:45 - 13:00 2.25 DRILL PROD1 RIH for resistivity logging run. 13:00 - 15:15 2.25 DRILL PROD1 Correct depth at flag. Log down wo pump to 12510' - below window. Break ciro and log down at 850 fph. Started taking weight at 14105'. 15:15 - 16:15 1.00 DRILL PROD1 Work thru tight spot & continue down to 14148' - tight. Then 14155', 14167'. Pull up and ream from 14120' to 14190'. PU and ream down to 14224'. Continue working down to 14283'. Pull up to 14190' and try to ream back down - no success. Pull up to 14100' - pulls up above 70 klbs. 16:15 - 17:30 1.25 DRILL PROD1 Ream from 14100' - no go. Pull up to 14070' and ream down to 14105'. Continue down to 14300' & took wt. Work thru and RIH clean to 14395'. Tag up 3 times at same depth wo further progress. May be bottom and cannot go further - coil Iockup. 17:30 - 18:00 0.50 DRILL PROD1 Log up from bottom to 14000'. 18:00 - 20:00 2.00 DRILL PROD1 POH with logging BHA. Flagged CT at 12,000 fi EOP. 20:00 - 22:30 2.50 DRILL PROD1 L/O drilling/logging BHA. Download data from Sperry Res/GR. Final TD from Sperry logging run was 14,410 fi BKB. 22:30 - 23:30 1.00 CASE COMP Prep rig floor to run 2 7/8" liner. Clear / raise cat-walk. 23:30 - 00:00 0.50 CASE COMP Safety Meeting, review liner running operations / hazards. 12/20/2000 00:00 - 02:00 2.00 CASE COMP Run 35 jts, 2 7/8", 6.16#, STL, L-80 Liner. Stop and fill liner. Torque STL to 1600 fi-lbs. 02:00 - 03:30 1.50 CASE COMP Run 26 jts, 2 7~8" liner, 10 fi pup, XO and 10 jts, 3 3/16", TCII, liner. 03:30 - 05:00 1.50 CASE COMP M/U Baker Deployment sleeve and CTLRT. M/U DS BHA. M/U Baker CTC, press/pull test. 05:00 - 07:45 2.75~ CASE COMP RIH with liner on CT. BHA = 2227 fi. Circ at min. rate. Get shoe thru window to 12545'. Something hung up -got thru on 3 rd attempt. Cont RIH- work thru 13870', 14130', 14165', 14185', 14205' (ugly), 14235', 14270', 14340', 14390'. Tag bottom? at 14410' several times - same. On bottom. 07:45 - 11:15 3.50 CASE COMP Load 5~8" releasing ball in CT ball drop manifold. Circ down. Ball not on seat at 70 bbl away. SD and check to see if ball left reel manifold - it didn't. Re-position reel and launch ball again - still did not launch. Attempt #3 - ball left but did not see it land on seat or seat is washed - no press increase. 11:15 - 13:00 1.75 CASE OCOL COMP Load and pump second ball down - confirm ball in CT reel, no doubt. Ball did not go on seat. Try pumping at max rate (3.8 bpm) and working pipe to try and shear off liner deployment sleeve - no success. Prep to ciro with Dowell cement unit to get higher rate & pressure. 13:00 - 13:15 0.25 CASE COMP Safety meeting to discuss hazards of high pressure pumping with rig crew, cementers, Peak. 13:15 - 14:30 1.25 CASE OCOL COMP Prime up cement unit. Isolate in MM and rig pumps. Test lines to 7500 psi. Pump down coil at 4.4 bpm (max for cmt pump). SD and move pipe - no success. Try again 4.5 bpm 4600 psi (max). Work pipe & PU - no success. Cannot release deployment tools. Discuss with Anch ODE 14:30 - 19:00 4.50 CASE OCOL COMP Wait on call from HB&R to see if they have big unit available to get more rate to try and release off deployment sleeve. Ball seat may have Printed: 1126/2001 4:33:33 PM BP EXPLORATION FEi3 ~ 3 ZIPS'ge 10of12 Operations Summary Report Alaska0il &Gas Cons. Commission Anchorage Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 121312000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 12120/2000 14:30 - 19:00 4.50 CASE OCOL COMP sheared prematurely before liner released. HB&R unit doesn't put out enough rate/pressure. Consider options w/Anch ODE & Baker. : 19:00 - 21:45 2.75 CASE OCOL COMP POOH with liner, 65K up wt off bottom, overpull in lower shales, then pulled easily to window [44K up wt, 2.1 BPM, 2500 psi, 40 FPM]. Pulled easily thru window. POOH. 21:45 - 00:00 2.25 CASE OCOL COMP At surface, Release Baker CTLRT from deployment sleeve. Recover two 0.625" steel balls from catcher [2 were pumped]. M/U new Baker CTLRT to sleeve. Pull test. Ready to RIH. 1212112000 00:00 - 01:45 1.75 CASE OCOL COMP RIH with liner on CT. 01:45 - 02:45 1.00 CASE OCOL COMP RIH thru window, no wt loss, Up wt = 46K, Dwn wt = 18K. RIH at 50 FPM and 0.2 BPM. Set down at 14270, 14350 ff. Landed liner atTD at 14,410 ff BKB, [14,418 ft CTD]. Set down 3 times at same depth. 02:45 - 04:15 1.50 CASE OCOL COMP Drop 0.63" steel ball, circ. down hole at 2.1 BPM. Heard ball moving in CT. Slow down to 0.5 BPM at 40 bbls. CT Cap = 58.4 bbls. Pump 64 bbls, ball not on seat, no press increase. Stop pump, pick up still have liner, set down, pump 1 bpm, to 67 bbls, still have liner. No ball at surface. 04:15 - 05:30 1.25 CASE OCOL COMP Pump second steel ball. Ball on seat at 63 bbls. Ball seatsheared at 3300 psi. Pick up. Pull free at 36K. CTLRT free from liner. Set down wt on liner and circ. at 2.8 BPM. 05:30 - 08:30 3.00 CEMT COMP Circ well to 2 % KCL water. 2.8 BPM, 3150 psi, Full returns. Continue displacement for additional cleanup while cementers arrive on location. 08:30 - 09:00 0.50 CEMT COMP RU cementers. 09:00 - 09:15 0.25 CEMT COMP PJSM with all personnel to identify & discuss hazards of high pressure pumping & working in reelhouse. 09:15 - 10:00 0.75! CEMT COMP Air up, prime up, batch mix +/- 22 bbl class G slurry @ 15.8 ppg. Fill lines and pressure test to 3500 psi - no leaks. Pump 5 more bbl water. 10:00 - 10:15 0.25 CEMT COMP Start downhole with cement - 2.8 bpm @ 2750 psi. Full returns. Pump 21.5 bbl slurry from MM. SD pumping & load dart in reel manifold. 10:15 - 10:45 0.50 CEMT COMP Pump 2 bbl disp. SD & verify dart has gone - OK. Continue displacement. 3.0 bpm. Caught cement at 14 bbl away. Cont displacement - 2.9 bpm @ 2250 psi. Reduce to 2.4 bpm with cement @ shoe - losing 0.4 bpm based on MM in/out. Dart landed and sheared liner wiper w/3800 psi at 58.5 bbl away. 10:45 - 11:00 0.25 CEMT COMP Cont disp @ 2.5 bpm. Slow to 1.0 bpm 1.5 bbl before calc bump plug. Plug bumped at 71.0 bbl away vs 71.8 bbl calc. Pressure up to 2000 psi. Bleed off pressure and verify floats holding - OK. ClP @ 10:50 hrs. Pressure up to 500 psi and unsting from liner - OK. 11:00 - 13:00 2.00 CEMT, COMP POH with liner running tool circ at 2.9 bpm to chase cement OOH. Saw some cement contamination in returns when POH but no green cement. 13:00 - 13:30 0.50 CEMT COMP OOH. Stand back injector. LD CTLRT. 13:30 - 13:45 0.25 CEMT COMP PJSM for PU 1 1/4" CSH workstring. 13:45 - 16:15 2.50 CEMT COMP MU jetting nozzle, 74 jts CSH workstring, Dowell package. MU connector and injector. 16:15 - 18:15 2.00 CEMT COMP RIH to clean out inside liner. RIH to top of liner. 18:15 - 21:00 2.75 CEMT COMP RIH inside liner. Pump 1.6 BPM, 2160 psi, RIH at 350 Fpm. RIH to PBTD of 14,375 ft. [top of liner wiper plug]. No cement in liner. 21:00 - 21:15 0.25 CEMT COMP Safety Meeting, review MSDS Hazards and PPE for pumping bleach. 21:15 - 22:00 0.75 CEMT COMP Circ 15 bbls bleach to nozzle and lay in liner. 22:00 - 23:30 1.50 CEMT COMP POOH with CT. 23:30 - 23:45 0.25 CEMT COMP Safety meeting, review hazards for standing CSH workstring back. Printed: 1/26/2001 4:33:33 PM FEB 2 3 Z001 BP EXPLORATION Page 11 of 12 Operations Summary ReportAlas' a oil & c. s cons. Commission Anchorage Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 12/21/2ooo 23:45 - oo:oo 0.25 CEMT COMP Stand back 37 stds of CSH workstring. 12/22/2000 00:00 - 00:30 0.50 CEMT COMP Stand back CSH workstring, clear rig floor. 00:30 - 02:30 2.00 CEMT COMP WOC, cement in place at 11:00 hrs. 02:30 - 03:00 0.50 CEMT COMP Press test liner lap with 1,000 psi. Good test. 03:00 - 04:30 1.50 CEMT COMP R/U SWS E-Line euipment to run Cement bond log. 04:30 - 06:00 1.50 CEMT COMP RIH with CBL / GR / CCL. Got down as deep as 12682'. 06:00 - 07:30 1.50 CEMT COMP Log from 12682' up to 12000' - above TOL. Preliminary interpretation shows good cement up to 12300' - 180' above window. 07:30 - 08:45 1.25 CEMT COMP POH with CMT. LD tool. 08:45 - 09:30 0.75 CEMT COMP RD SWS. 09:30 - 10:30 1.00 CEMT COMP Pressure IA to 500 psi and tubing to 2200 psi. Hold for 30 min to verify liner and cement integrity. Pressure dropped 75 psi in 30 min - good test. 10:30 - 10:45 0.25 PERF COMP PJSM for picking up & running perf guns. 10:45 - 11:30 0.75 PERF COMP MU perf guns. Check CMT log and see that liner depths may be off @ 16' high. This will impact perforating strategy. Discuss with Anch ODE and Asset. 11:30 - 12:00 0.50 PERF OTHR COMP LD perforating guns and prep to run memory GR/CCL for depth correlation. '12:00 - 13:00 1.00 PERF OTHR COMP Wait on delivery of memory GR from SWS. 13:00- 13:15 0.25 PERF OTHR COMP Safety meeting. 13:15 - 13:45 0.50 PERF OTHR COMP M/U SWS Memory GR logging tool. 13:45 - 15:00 1.25 PERF OTHR COMP RIH with 37 stds CSH. BHA total length = 2326.3 ft. 15:00 - 17:00 2.00 PERF OTHR COMP RIH with CT at 100 FPM, 0.5 bpm, 250 psi. 17:00 - 18:00 1.00 PERF OTHR COMP Log down at 60 FPM from 12,000 ft. Stop pump at 13,800 ft. Tag PBTD at 14,365 ft CTD. 18:00 - 19:00 1.00 PERF OTHR COMP Log up at 60 FPM to 12000'. 19:00-20:30 1.50 PERF OTHR COMP POOH. 20:30 - 21:30 1.00 PERF OTHR COMP SB CSH. 21:30 - 23:00 1.50 PERF OTHR COMP Download GR/CCL data. Corrected PBTD = 14371'. Fax log to down and wait for perf instructions. 23:00 - 23:15 0.25 PERF COMP Safety meeting with perf gang. 23:15 - 00:00 0.75 PERF COMP MU 2" guns. 12/23/2000 00:00 - 00:15 0.25 PERF COMP Finish MU perf guns. 00:15 - 01:15 1.00 PERF COMP MU 35 stands CSH. 01:15 - 03:30 2.25 PERF COMP RIH. Tag TD 14,359' CTM (corrected depth 14371'). 03:30 - 04:30 1.00 PERF COMP Circlulate 15 bbls lith hyp and chase with 5/8" ball. Shear seat in firing head at 3100 psi. Perforate 14243' - 14324' (2", 6 SPF PJ charges) and 14350'- 14370' (2", 6 SPF BH charges). 04:30 - 07:00 2.50 PERF COMP Clean PU off bottom. POOH. No initial losses noted. 07:00 - 07:15 0.25 PERF COMP Safety Meeting, review hazards for standing back workstring 07:15 - 08:30 1.25 PERF COMP Stand back 37 stds workstring. 08:30 - 08:45 0.25 PERF COMP Safety Meeting, review hazards I procedures to recover perf guns. 08:45 - 10:00 1.25 PERF COMP Recover guns, all shots fired. Remove guns from pipe shed. 10:00 - 11:45 1.75 RIGD 'COMP RIH with nozzle to 2000 ft. Lay in MEOH at 50%. POOH. Stand back injector. 11:45 - 15:00 3.25 RIGD COMP Close swab valve and master valve. Clean rig pits. Nipple down BOPE. 15:00 - 15:30 0.50 RIGD COMP Pressure test tree cap to 4000 psi. OK. Well is secured. RELEASED RIG AT 15:30 HRS, 12/23/2000, TOTAL TIME ON WELL WAS 19 DAYS, 17.5 HOURS. Printed: 1/26/2001 4:33:33 PM BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: P-02 Common Well Name: P-02 Spud Date: 12/4/2000 Event Name: REENTER+COMPLETE Start: 12/3/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 12/23/2000 15:00- 15:30 0.50 RIGD COMP ~' ,~ ~, ~ t.~'~ ~, '~..;~,.~... ~ FEa 2, 3 ~OOl Alas,~a Oil & C.,~s Cons. Commjs;io~ Anchorage Printed: 1/26/2001 4:33:33PM Schlumberger Alaska Data & Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 854 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Color Well Job # Log Description Date Blueline Sepia Prints CD J-23 PRODUCTION PROFILE 001231 1 1 R-12 PROD PROFILE W/GHOST & DEFT 010101 1 1 W-37 LEAK DETECTION LOG 010101 1 1 B-08 20491 RST-SIGMA 001124 1 1 1 P-02A 21015 $CMT 001222 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 1/10/01 BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska ~9508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Al-tN: Sherrie Received 17-Jan-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well P-02A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,300.00' MD Window / Kickoff Survey: 12,481.00' MD Projected Survey: 14,410.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) North Slope AlaSka Alaska Drilling & Wells PBU_WOA P Pad, Slot P-02 P-O2A Surveyed: 19 December, 2000 DEFINITIVE SURVEY REPORT 17 January, 2001 Your Ref: APl 500292237601 Surface Coordinates: 5947352.45 N, 631320.48 E (70° 15' 51.2262" N, 148° 56' 17.7593" W) Kelly Bushing: 87.90ft above Mean Sea Level DRILLING SERVICES Survey Ref: svy10696 A Halliburton Company Sperry-Sun Drilling Services Survey Report for P-O2A Your Ref: AP1 500292237601 Surveyed: f9 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) 12300.00 32.050 22.409 8679.12 8767.02 12400.00 30.790 24.960 8764.46 8852.36 12481.00 32.470 28.010 8833.43 8921.33 12511.06 44.380 40.970 8856.98 8944.88 12543.66 53.280 55.020 8878.48 8966.38 12578.26 59.350 73.410 8897.77 8985.67 12611.66 66.800 83.260 8912.92 9000.82 12650.06 69.700 99.260 8927.22 9015.12 12686,06 71.890 114.730 8939.13 9027.03 12725.06 81.210 125.800 8948.22 9036.12 12760.46 87.710 137.480 8951.65 9039.55 12790.46 90.530 148.650 8952.11 9040.01 12820,86 90.530 158.500 8951.83 9039.73 12855.46 91.490 171.330 8951.21 9039.11 12891,43 91.390 178.240 8950.31 9038.21 12927.43 95.010 183.110 8948.30 9036.20 12965.83 94.310 190.490 8945.17 9033.07 12992.03 92.990 192.600 8943.51 9031.41 13022.03 91.930 194.880 8942.22 9030.12 13059.43 93.430 202.270 8940.47 9028.37 13089.83 93.600 205.960 8938.60 9026.50 13122.83 93.690 210.880 8936.50 9024.40 13155.23 93.690 214.390 8934.42 9022.32 13191.03 93.080 226.350 8932.30 9020.20 13227.03 93.340 221.600 8930.28 9018.18 13275.83 93.870 214.040 8927.21 9015.11 13307.63 93.690 211.930 8925.11 9013.01 13338.23 92.370 207.010 8923.49 9011.39 13372.23 92.280 204.200 8922.11 9010.01 13405.43 91.580 200.160 8920.99 9008.89 Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 7863.92N 312.08 E 5955220.62 N 631495.35 E 7911.66 N 333.00 E 5955268.71 N 631515.43 E 7949.66 N 351.96 E 5955307.04 N 631533.73 E 7964.80 N 362.70 E 5955322.36 N 631544.20 E 7980.97 N 380.96 E 5955338.85 N 631562.19 E 7993.26 N 406.77 E 5955351.59 N 631587.77 E 7999.18 N 435.88 E 5955358.02 N 631616.77 E 7998.35 N 471.38 E 5955357.80 N 631652.29 E 7988.42 N 503.76 E 5955348.44 N 631684.84 E 7969.30 N 536.40 E 5955329.89 N 631717.80 E 7945.92 N 562.65 E 5955306.98 N 631744.46 E 7921.99 N 580.65 E 5955283.36 N 631762.87 E 7894.80 N 594.16 E 5955256.41 N 631776.85 E 7861.46 N 603.14 E 5955223.24 N 631786.42 E 7825.68 N 606.41 E 5955187.51 N 631790.31 E 7789.75 N 605.99 E 5955151.59 N 631790.51 E 7751.77 N 601.46 E 5955113.54 N 631786.65 E 7726.16 N 596.23 E 5955087.83 N 631781.86 E 7697.05 N 589.11E 5955058.60 N 631775.25 E 7661.66 N 577.22 E 5955023.01N 631763.98 E 7633.97 N 564.82 E 5954995.11N 631752.07 E 7605.01N 549.15 E 5954965.89 N 631736.91E 7577.79 N 531.72 E 5954938.36 N 631719.95 E 7550.61 N 508.61 E 5954910.79 N 631697.32 E 7524.75 N 483.66 E 5954884.50 N 631672.83 E 7486.31 N 453.82 E 5954845.54 N 631643.66 E 7459.70 N 436.55 E 5954818.62 N 631626.85 E 7433.10 N 421.52 E 5954791.77 N 631612.29 E 7402.47 N 406.84 E 5954760.89 N 631598.15 E 7371.75 N 394.32 E 5954729.95 N 631586.16 E 1.83 2.86 47.65 42.29 47.48 34.45 39.41 41.02 36.48 37.61 38.39 32.40 37.18 19.21 16.84 19.24 9.49 8.37 20.14 12.13 14.88 10.81 33.39 13.19 15.50 6.64 16.62 8.26 12.34 Alaska Drilling & Wells PBU WOA P Pad Vertical Section Comment 7863.92 TIE ON POINT MWD Magnetic 7911.66 7949.66 7964.80 7980.97 7993.26 7999.18 7998.35 7988.42 7969.30 7945.92 7921.99 7894.8O 7861.46 7825.68 7789.75 7751.77 7726.16 7697.05 7661.66 7633.97 7605.01 7577.79 7550.61 7524.75 7486.31 7459.70 7433.10 7402.47 7371.75 WINDOW POINT 17 January, 200f - 11:39 Page 2 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for P-O2A Your Ref: AP1 500292237601 Surveyed: f9 December, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 13437.83 92.020 195.940 8919.98 9007.88 13476.03 92.550 192.250 8918.45 9006.35 13506.03 93.080 186.270 8916.98 9004.88 13559.63 94.750 183.280 8913.32 9001.22 13599.23 93.340 177.130 8910.52 8998.42 13637.83 91.760 170.980 8908.80 8996.70 13670.63 91.580 169.220 8907.85 8995.75 13710.83 90.880 160.780 8906.98 8994.88 13740.43 91.580 157.440 8906.35 8994.25 13773.23 92.460 153.050 8905.19 8993.09 13814.63 93.950 148.480 8902.87 8990.77 13848.03 94.220 143.380 8900.49 8988.39 13885.43 95.100 136.700 8897.45 8985.35 13917.03 94.920 143.550 8894.69 8982.59 13944.03 93.780 146.190 8892.64 8980.54 13981.23 92.990 147.420 8890.44 8978.34 14026.43 93.200 149.570 8888.00 8975.90 14056.63 93.980 153.290 8886.11 8974.01 14089.23 93.250 161.840 8884.05 8971.95 14119.83 90.180 158.500 8883.14 8971.04 14153.25 87.010 162.890 8883.95 8971.85 14185.85 84.020 162.710 8886.50 8974.40 14215.45 80.240 166.410 8890.56 8978.46 14265.63 83.930 170.980 8897.47 8985.37 14295.83 84.810 17i.860 8900.43 8988.33 14372.13 84.110 181.700 8907.82 8995.72 14410.00 84.110 181.700 8911.70 8999.60 7340.96 N 384.28 E 5954699.00 N 631576.67 E 7303.95 N 374.99 E 5954661.83 N 631568.02 E 7274.39 N 370.17 E 5954632.19 N 631563.72 E 7221.11 N 365.72 E 5954578.84 N 631560.19 E 7181.63 N 365.58 E 5954539.36 N 631560.74 E 7143.29 N 369.57 E 5954501.10 N 631565.41E 7111.00 N 375.21 E 5954468.91 N 631571.60 E 7072.21N 385.60 E 5954430.31N 631582.67 E 7044.57 N 396.15 E 5954402.86 N 631593.70 E 7014.81 N 409.87 E 5954373.34 N 631607.94 E 6978.75 N 430.06 E 5954337.64 N 631628.75 E 6951.16 N 448.71E 5954310.38 N 631647.88 E 6922.60 N 472.64 E 5954282.25 N 631672.30 E 6898.46 N 492.81 E 5954258.46 N 631692.89 E 6876.44N 508.30 E 5954236.71 N 631708.76 E 6845.37 N 528.63 E 5954206.00 N 631729.63 E 6806.89 N 552.21E 5954167.94 N 631753.89 E 6780.43 N 566.62 E 5954141.73 N 631768.76 E 6750.38 N 579.03 E 5954111.90 N 631781.68 E 6721.62 N 589.40 E 5954083.32 N 631792.56 E 6690.10 N 600.44 E 5954052.00 N 631804.15 E 6659.05 N 610.05 E 5954021.13 N 631814.30 E 6630.80 N 617.86 E 5953993.02 N 631822.59 E 6582.08 N 627.59 E 5953944.48 N 631833.17 E 6552.37 N 632.07 E 5953914.84 N 631838.17 E 6476.64N 636.34 E 5953839.20 N 631843.76 E 6438.99 N 635.22 E 5953801.54 N 631843.30 E Dogleg Rate (°/100ft) 13.09 9.75 19.99 6.38 15.90 16.43 5.39 21.06 11.53 13.64 11.59 15.25 17.96 21.60 10.62 3.92 4.77 12.56 26.27 14.82 16.20 9.19 17.79 11.64 4.11 12.87 0.00 Alaska Drilling & Wells PBU WOA P Pad Vertical Section Comment 7340.96 7303.95 7274.39 7221.11 7181.63 7143.29 7111.00 7072.21 7044.57 7014.81 6978.75 6951.16 6922.60 6898.46 6876.44 6845.37 6806.89 6780.43 6750.38 6721.62 6690.10 6659.05 6630.80 6582.08 6552.37 6476.64 6438.99 PROJECTED SURVEY f7 January, 200f - 11:39 Page 3 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for P. O2A Your Ref: AP1500292237601 Surveyed: f9 December, 2000 North Slope Alaska Alaska Drilling & Wells PBU WOA P Pad All data is in feet 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. Magnetic Declination at Surface is 26.656° (07-Dec-00) The Dogleg Severity is in Degrees per 100 feet. 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 14410.00ft., The Bottom Hole Displacement is 6470.24ft., in the Direction of 5.634° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 12300.00 8767.02 7863.92 N 312.08 E 12481.00 8921.33 7949.66 N 351.96 E 14410.00 8999.60 6438.99 N 635.22 E Comment TIE ON POINT WINDOW POINT PROJECTED SURVEY 17 January, 200t - t1:39 Page 4 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for P-O2A Your Ref: AP1 50029223760f Surveyed: fO December, 2000 North Slope Alaska Alaska Drilling & Wells PBU WOA P Pad Survey tool program for P-O2A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 12300.00 8767.02 12300.00 8767.02 14410.00 8999.60 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gym (P-02) MWD Magnetic (P-02A) 17 January, 2001 - 11:39 Page 5 of 5 DrillQuest 2.00.06 Re: P-O2ai-200-084 Subject: Re: P-02ai--200-084 Date: Fri, 01 Dec 2000 11:40:25 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Stagg, Ted O (ORBIS)" <StaggTO@BP.com> Ted, Thanks for the information. No need to send the new drawing. We will just look for it in the 407. Good luck. Tom "Stagg, Ted 0 (ORBIS)" wrote: The Nordic coil drilling rig is currently on P-OgL 1, just getting started. The next well, P-O2ai, is going to have a slight change in the completion. Rather than a 2 7/8" oemented liner we are planning to install a 3 $/16" x 2 7/8" cemented liner. The 2 7/8" ~11 be used in the open hole as it can be properly centralized and conditions for liner cementing are very good. However, we can provide for a future Tiny Tool sidetrack option by crossing the liner over to 3 3/16"just outside the window. The 3 3/16" would then extend up into the existing tubing tail. The liner cement will still be designed to cover 200 ft above the window to achieve the rock solid lap test required for injectors. With this as the only change from the approved Permit to Drill (200-084) do I need to file anything further v~th you? I can fax over a new proposed completion schematic if you want it. Please advise. Ted Stagg ~~eer Alaska Oil and Gas Conservation Commission 1 of 1 12/1/00 11:40 AM ALASKA OIL AND GAS CONSERVATION COPI~IlSSION Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Prudhoe Bay Unit P-02Ai BP Exploration (Alaska) Inc. Permit No: 200-084 Sur Loc: 2624'NSL, 2039'EWL, Sec. 31, T1 IN, R13E, UM Btmhole Loc. 3531'NSL, 2548'EWL, Sec. 30, TI IN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THiE COMMISSION DATED this ,~0'~ day of June, 2000 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ~_ AND GAS CONSERVATION COMMIL _.ION PERMIT TO DRILL 20 AAC 25.005 [] Drill lie Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I '2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 87.90' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028288,,o7--~ ~ '4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 2624' NSL, 2039' EWL, SEC. 31, T11N, R13E, UM Prudhoe Bay Unit , At top of productive interval 8. Well Number 61' NSL, 2413' EWL, SEC. 19, T11N, R13E, UM P-02Ai Number 2S100302630-277 At total depth 9. Approximate spud date 3531' NSL, 2548' EWL, SEC. 30, T11N, R13E, UM 06/15/00 Amount $200,000.00 12. Distance to nearest property line 113. Distahce to nearest well ' 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028283, 1747' MDI No Close Approach 2560 14660' MD / 8965' TVD ! 6. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e') (2)} Kick Off Depth 12485' . Maximum Hole Angle 95 ° Maximum surface, 2.544 psig, At t.otal depth, (TyD) 8800' ! 3600 psig 18. Casing Program Specifications Setting Depth Size . Top Bottom . Quantity of Cement. Hole Casin.q Weiqht Grade Couplinq Len.qth 'MD TVD MD TVD (include sta.qe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2439' 12221' 8612' 14660' 8965' 118 cuft Class 'G' 19. ~o be completed for Redrill', Re-entry, and Deepen' operations. ' ......... Present well condition summary Total depth: measured 12852 feet Plugs (measured) Sandback to 12608' CTM true vertical 9231 feet Effective depth: measured 12770 feet Junk (measured) Wireline tool string lost in hole, 28' long (11/93) true vertical 9163 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 280 cu ft Arcticset 110' 110' Surface 3207' 10-3/4" 187 cuft CS III, 63 cu ft Class 'G' 3263' 2841' Intermediate 12349' 7-5/8" 1858 cu ft Class 'G' 12405' 8857' Production Liner 613' 5-1/2" 140 cuft Class 'G' 12239' - 12852' 8715' - 9231' Perforation depth: measured 12580'-12624' ' ...... ',~'t/' ..... '~'~ ~000 true vertical 9005' - 9042' Alaska 0ii & Gas Cons. C0rnmission 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch ~1~1~'~' Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 ..... Prepared By Name/Numbe~ ' Tei~fe ~lubbl~, 564-4628 21. I hereby certify that foregoing'i~ true and ~orrect to the b~st oi"m~,'~nowledge ..... ' ! __' ' ' ' tls · _ , ,, Signed Ted Stagg Title CT Drilling Engineer Date Permit Number I APl Number Approval Date I See cover letter I 5o-029-22376-01.,, , , ¢-I forotherrequireme, n. ts . Conditions of Approval: Samples Required r'l Yes J~[No Mud Log Required [] Yes Hydrogen Sulfide Measures ~'Yes [] No Directional Survey Required ']~'Yes [] No Required Working Pressure for BOPE [] 2K; [] 3K; I~,~K; [] 5K; [] 10K; [] 15K by order of "' '" Approved By r~m,~,~.,~, ~.,c'.lul::i'3 i:~mmissi0.ner ..... the commission Date.~.. ............................. Form 10-401 Rev. 12-01-85 D Taylor Seamount Submit In Triplicate BPX P-02ai Sidetrack Summary of Operations: P-02i is being sidetracked to improve injection support in Zone 4B. This sidetrack will be conducted in two phases. Phase 1: Set whipstock, cement perfs, mill window: Planned for June 8-11, 2000. · A Mechanical Integrity Test will be performed. · A whipstock drift will be run. · A multi-arm caliper will be run. · E-Line will be used to set the whipstock at approx. ~12,475' MD. · Service coil will be used to cement perfs and mill the window. Phase 2: Drill and Complete sidetrack: Planned for June 15, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. Mud Program: · Phase 1: Seawater · Phase 2: FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 12,221' MD and cemented with approx. 21 bbls. cement to bring cement 200 ft above the window. The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. Well · · · Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. Real Time Resistivity logs will be run. A cement evaluation log is not scheduled for the 2 7/8" liner as the bond log on the original 5 ~/~" liner shows good cement above the planned window in the Shublik. Hazards Five faults with lost circulatin potential are identified. Res. pressure is normal. Reservoir Pressure Res. pressure is estimated to be approx. 3600 psi @ 8800ss. Max. surface pressure with gas (0.12 psi/E) to surface is 2544 psi. TREE: 4-1/16" - 5M CIW WELLHEAD: 11"- 5M FMC ~,CTUATOR: AXEL P-02ai Proposed Completion KB. ELEV = 87.9' BF. ELEV = 32.5' SSSV LANDING NIPPLE (OTIS)( 3.813" ID) 12089'1 10-3/4", 45.5,Wff, I 3263,I NT-80LHE Butt KOP @ 500' Max Angle @ 50° 4-1/2", 12.6#/ft, NSCT, L-80 TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBIJFT GAS LIFT MANDRELS CW / 1" BK L ~,TCHI N° MD(RKRI[ · 5 3539' 2926' 4 6845' 4978' 3 9200' 6511' 2 11,036' 7728' 1 12,103' 8545' PERFORATION SUMMARY Top of 5-1/2 liner ! 12,239' 7-5/8" liner hanger 7-5/8",29.7# [ 12,405, NT95HS NSCC P-02a whipstock is to be set in the Shublik to avoid Sag R. Existing perfs to be squeezed. 2 7/8" liner to be cemented approx. 200 ft above the window. NOTE: AN ERROR WAS FOUND IN THE TUBING STRAPPING, TUBING DEPTHS CAN BE WRONG UP TO 62' DEPENDING ON LOCATION. PBTD I 12,770'1 5-1/2", 17 #/f, L-80 NSCC [ 12,852' SWS Nipple, 41/2" 75/8" TIW pkr assy TIW latch assy SWS Nipple, 4-1/2" 4-1/2", 12.6 #/ft, L-80 TAILPIPE 4-1/2 .... SWN" NIPPLE (Parker) (3.725" ID) 12,159' 12,178' I I 4-1/2" WLEG 12,243' ELMDI 12~243' Sand back to 12608' CTM 12640' CTM Fish. 1112/93 . IWL Tool String 28' Long X 2.5" Max OD IPlus 0.0108 Wire I P-02 P-02ai case 102g 15/23/00 Kick off from Shublik 12,175 ft open hole IFaults 1-5 are shown with lapprox, orientation. I I -1,000 -500 0 500 X distance from Sfc Loc 1,000 9,000 8,500 8,000 7,500 7,000 6,500 6,000 1,500 IWell Name P-02 CLOSURE Distance 6,209 ft Az 4 de~l NEW HOLE E/W (X) NIS Kick Off 215 7,957 TD 404 6,195 State Plane 631,724 5,953,548 Surface Loc 631,320 5,947,352 DLS degll00 Tool Face Length Curve 1 6 30 20 Curve 2 35 60 337 Curve 3 35 Curve 4 6 -90 479 'Curve 5 6 90 275 Curve 6 6 -90 324 Curve 7 6 -150 550 2,175 Drawn: 5/24/2000 14:05 Plan Name: Case 102g P-02 Vertical Section 0 500 8750 8800 8850 8900 8950 900O Path Distance(Feet) 1,000 1,500 2,000 2,500 3,000 3,500 Angle ~ K.O.= 33 deg MD:12485 4,000 9O50 9100 Tot Drld:2175 ft 1466O TD Marker Depths ~Orig Wellborn TSAG I 8,8031~'~ TSHU I 8,8281 8,9651 8,965]ff TVD TSAD ] 8,918Jf TVD KickOff I 8,8371fTVD I 12,485 Iff MD Deprtr ~KO 7,974 ff MD KO Pt 12,485] MD New Hole 2175[ I Total MD 14,660I 'rVD TD 8,96SI DLS degl100 Tool Face Length Curve 1 6 30 20 Curve 2 35 60 337 C~rve 3 35 90 ~Jg0 Curve 4 6 Curve 5 6 -90 479 90 275 -90 324 Curve 6 6 Curve 7 6 -150 550 2,175 Drawn: 5/24/2000 14:05 Plan Name: Case 102g U.I Z 12" 22.5" 7 1/16" Annular Blind/Shear 7 1/16" Pipe/Slip 2 3/8" 18" i~, 7 1/16" Pipe [i , J ,, ~ 2 3/8" SWAB OR MASTER VALVE I ! ~ STATE OF ALASKA --._~. ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Fype of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown [] Plugging [] Time Extension [] Pull Tubing [] Vadance [] Re-Enter Suspended Well [] Stimulate [] Perforate [] Other Plug Back for Sidetrack Name of Operator BP Exploration (Alaska) Inc. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2624' NSL, 2039' EWL, SEC. 31, T11N, R13E, UM At top of productive interval 61' NSL, 2413' EWL, SEC. 19, T11N, R13E, UM At effective depth 155' NSL, 2460' EWL, SEC. 19, T11N, R13E, UM At total depth 197' NSL, 2481' EWL, SEC. 19, T11N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 87.90' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number P-02i 9. Permit Number 193-084 10. APl Number 50- 029-22376-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 12852 feet 9231 feet 12770 feet 9163 feet Length Size Structural Conductor 110' 20" Surface 3207' 10-3/4" Intermediate 12349' 7-5/8" Production Liner 613' 5-1/2" Plugs (measured) Sandback to 12608' CTM Junk (measured) Wireline tool string lost in hole, 28' long (11/93) Cemented MD ']-VD 280 cu ft Arcticset 187 cu ft CS III, 63 cu ft Class 'G' 1858 cu ft Class 'G' 140 cu ft Class 'G' 110' 3263' 12405' 12239'-12852' 110' 2841' 8857' 8715'-9231' Perforation depth: measured 12580' - 12624' true vertical 9005' ~ 9042' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 12243' '¢ 2 6 2000 Ala~ka Oi~ & Gas Cons Oommi~ion Anc'h0r~e Packers and SSSV (type and measured depth) 7-5/8" TIW packer at 12178'; 4-1/2" Otis 'HXO' landing nipple at 2089' ~3. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 4. Estimated date for commencing operation June 8, 2000 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Name of approver Date Approved Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 17. ' hereby certify that th,e foT/~rue and correct to the best of my knowledge ./." '~ / '.'~Z~0~ Signed Ted Stagg ~~'~S Title CT Ddlling Engineer Date · .' '... ""' :.":: :".: c~mm!ssion Use:Oniy:'..i'::~.'..':' i,':',,. :'.: ...'... : .. '. ' Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- Annroved bv order of the Commission I Approval No. Commissioner Date Submit In Triplicate ARCO Alaska, Inc. KUPARUK SATELLITE DISBURSEMENT ACCT P.O. Box 103240 Anchorage, AK 99510-3240 PAY TO THE ORDER OF: STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE 206000204 MAY 16, 2000 VOID AFTER 90 DAYS 311 0927473 The First National Bank of Chicago-0710 Chicago, Illinois Payable Through FCC National Bank Wilmington, Delaware EXACTLY ********-*** 100 DOLLARS AND O0 CENTS .,;*********** I00.00 TRACE NUMBER: 206000204 ,' ;~0 f=O00 ;~0 L,,' ~:0 ~, ], ;i, 00 ;~P, ~,'.: Dc] ;=?[. WELL PERMIT CHECKLIST COMPANY ~"~ WELL NAME ~ ~Z.,~ PROGRAM: exp dev redrll ,'" serv / wellbore seg ann. disposal para req FIELD & POOL ~:~ ~/~ INIT CLASS ~~- V' /~--~,'"~/'~/ GEOL AREA ,~ '~'~ UNIT# ~//~ ~--K""~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ............ v .,.., ......... 2. Lease number appropriate.'~..~..~-.~..'?-..=~."./?'-.'~, f'~../'.4~. ~/ 3. Unique well name and number .................. 4. Well located in a defined pool .................. DATE ..q. 30-00 ENGINEERING DATE 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor 8, surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~:::5 psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY DATE A/~ Y N) Y N 30. Permit can be issued wlo hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... ~ Y N 32. Seismic analysis of shallow gas zones ............. ,~,~ Y N 33. Seabed condition survey (if off-shore) ............. ,~/,~ Y N 34. Contact name/phone for weekly progress reports [exploratoryortl.~ Y N (~ N y ([J~""~ ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERI,_NG: UIC/~nnular COMMISSION: Comments/Instructions: 0 Z o :Z -I -r c:~msoffice\wordian~liana\checklist (rev. 02117/00) Well Histocy File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi ,. No Special'effort has been made to chronologically organize this category of information, r, . Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLlb SRevlsion: 4 $ Fri Jun 28 08:21:41 2002 Reel Header Service name ............. LISTPE Date ..................... 02/06/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... O1 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/06/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA P-O2A 500292237601 BP Exploration (Alaska), Inc. Sperry Sun 28-JUN-02 MWD RUN 11 MWD RUN 12 MWD RUN 13 JOB NUMBER: AK-MW-00283 AK-MW-00283 AK-MW-00283 LOGGING ENGINEER: B. JAHN B. JAHN B. JAHN OPERATOR WITNESS: MASKELL/WHIT MASKELL/WHIT MASKELL/WHIT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 14 MWD RUN 15 MAD RUN 16 AK-MW-00283 AK-MW-O0283 AK-MW-00283 B. JAHN B. JAHN B. JAHN MASKELL/WHIT MASKELL/WHIT MASKELL/WHIT 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .' 31 liN 13E 2624 2039 87.90 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 3263.0 7.630 12405.0 5.500 12481.0 ! tlI !. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. '~. I'-~D RUNS 8 -10 ARE FOR MILLING WINDOW AND ARE NOT PRESENTED. 3. MWD RUNS 11 - 15 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. '4. MWD RUN 16 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 5. GAMMA RAY (SGRD) LOGGED BEHIND CASING FROM 12461' MD, 8817' SSTVD TO 12481' MD, 8833' SSTVD. ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) DATA WAS OBTAINED ON A MADPASS ON MWD RUN 16. THIS RUN WAS PERFOMED TO OBTAIN THE RESISTIVITY DATA OVER THE DRILLING INTERVAL. NO DRILLING WAS PERFORMED ON THIS RUN. THE RESISTIVITY DATA IS PRESENTED ON THE DRILLING LOG AND NO MADPASS LOG IS PRESENTED. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC GR LOG OF 12/22/00 WITH KBE = 87.9' A.M.S.L.. THIS WELL KICKS OFF FROM P-02 AT 12481' MD, 8833' SSTVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. MHD RUNS 11 - 16 REPRESENT WELL P-O2A WITH API 50-029-22376-01. THIS WELL REACHED A TOTAL DEPTH OF 1.4410' MD, 8912' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY SGRC = SMOOTHED GAMMA 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 $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12460.5 14391.0 ROP 12496.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 12460.5 12474.5 12486.0 12488 5 12503 0 12507 5 12513 0 12518 5 12521 5 12527 5 12531 5 12534 5 12550.0 12559.5 12562.5 12567.5 12569.0 12571.0 12572.0 12575.0 12583.0 12589.0 12597.5 12605.5 12608.0 12611.5 12614.0 12640.5 12642.5 12654.0 12669.5 12689.0 12694.0 12710.5 12715.0 12718.0 12725.5 12732.5 12735.5 12750.5 12764.5 12767.5 12772.5 12842.0 12843.5 12845.5 12847.0 12873.5 12894.5 12906.5 12915.0 12922.0 12928.0 12940.0 12945.0 12950.5 12955.5 12958.5 12979.5 12983.5 12987.0 13000.5 13005.0 13006.5 13014.5 13020.5 13041.0 13043.0 14416. GR 12461.0 12475.0 12486.5 12488.5 12503.5 12507.0 12513.5 12518.5 12522.0 12527.5 12533.0 12536.0 12551.5 12561.0 12564.0 12569.0 12570.5 12572.0 12573.0 12576.0 12584.0 12590.5 12598.0 12606.0 12608.0 12612.0 12614.5 12640.0 12642.5 12653.0 12667.0 12687.5 12691.5 12710.0 12714.5 12719.0 12725.5 12732.0 12734.5 12752.0 12766.0 12769.5 12774.0 12844.5 12845.5 12848.0 12850.0 12880.0 12902.0 12916.0 12924.0 12931.5 12937.5 12950.0 12956.5 12959.'5 12964.5 12967.0 12989.0 12991.5 12997.5 13009.0 13014.0 13017.0 13025.5 13031.0 13044.0 13049.0 EQUIVALENT UNSHIFTED DEPTH 13044.5 13048.5 13053.0 13055.5 13059.5 13069.0 13073.5 13075.0 13077.0 13096.5 13103.5 13108.5 13115.0 13123.5 13128.5 13139.5 13141.5 13143.0 13152.0 13160.5 13168.0 13190.5 13195.5 13201.0 13216.5 13234.0 13253.5 13257.0 13260.5 13270.0 13277.5 13286.0 13292.5 13295.0 13302.0 13305.5 13312.5 13319.5 13328.0 13336.0 13341.5 13349.5 13354.0 13357.5 13364.5 13368.0 13382.0 13390.0 13400.5 13408.0 13413.0 13417.0 13423.0 13431.5 13433.5 13439.5 13453.5 13456.5 13460.5 13472.0 13484.5 13491.0 13494.0 13505.0 13515.0 13521.5 13524.5 13526.0 13538.0 13575.5 13582.0 13590.0 13594.5 13603.0 13611.0 13051.0 13054.5 13057.0 13059.5 13063.0 13074.5 13078.5 13082.5 13085.5 13107.5 13113.5 13117.5 13125.0 13135.5 13140.0 13149 0 13150 5 13152 5 13160 0 13166 0 13173 0 13196.5 13201.5 13207.0 13223.0 13239.5 13252.5 13255.5 13260.0 13271.5 13279.0 13288 0 13295 0 13298 0 13301 0 13305 5 13314 0 13323 5 13332 5 13340 5 13345 0 13356 5 13362.5 13366.5 13371.0 13374.0 13386.5 13392.5 13401.5 13409.0 13412.0 13417.0 13421.0 13429.5 13431.5 13438.5 13450.0 13453.0 13457.0 13468.5 13482.0 13488.5 13492.0 13504.5 13516.0 13522.5 13525.0 13527.5 13541.0 13578.5 13582.0 13591.0 13596.5 13605.5 13611.5 13613.0 13620.0 13642.5 13644.5 13652.5 13656.5 13669.5 13672.5 13683.5 13692.5 13700.0 13702.5 13705.5 13717 5 13719 5 13725 5 13751 0 13756 5 13762 5 13768 5 13772.5 13775.5 13787.0 13790.5 13799.5 13808.5 13825 5 13827 0 13842 0 13846 5 13852 0 13859 0 13874 0 13889 0 13892 0 13907 0 13911 0 13916 0 13932.5 13949.0 13956.0 13962.0 13974.0 13977.0 13987.0 14009.5 14013.5 14016.0 14020.0 14054.5 14066.0 14071.5 14076.5 14086.0 14110.0 14115.5 14136.5 14158.0 14167.0 14182.5 14190.5 14194.0 14205.5 14213.0 14222.5 14225.0 14231.5 14239.0 14250.0 14275.0 14277.0 14281.5 14286.5 14292.0 14297.0 13613.5 13620.5 13643.5 13646.0 13653.0 13657.0 13669.0 13673.0 13683.5 13693.5 13698.5 13701.0 13704.5 13715.0 13718.5 13725.5 13752.5 13761.0 13766.5 13774.5 13779.5 13783.5 13792.0 13796.0 13808.0 13814.5 13830.5 13833.0 13846.5 13852.0 13857.0 13862.5 13878.5 138'89.0 13892.5 13905.5 13910.5 13915.0 13931.5 13949.5 13954.0 13960.0 13975.5 13978.0 13988.0 14010.5 14015.5 14017.5 14019.5 14053.0 14062.5 14068.5 14073.0 14084.0 14109.5 14116.5 14135.0 14155.5 14165.5 14181.0 14188.0 14193.0 14204.0 14211.5 14222.0 14224.0 14226,.5 14228.5 14244.5 14274.0 14,~75.5 14281.0 14285.5 14291.5 14297.0 14304.5 14307.5 14309.0 14312.0 2.4313.5 14315.0 14315.5 14317.0 14318.5 14320.5 14322.5 14324.0 14325.5 14326.5 14334.0 14335.0 14337.0 14336.5 14350.5 14345.0 14364.5 14358.5 14416.0 14410.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 11 MWD 12 MWD 13 MWD 14 MWD 15 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 12461.0 12888.0 12888.5 14084.0 14084.5 14247.0 14247.5 14383.0 14383.5 14410.0 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 .liN Max frames Der record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DE?T FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 12460.5 14416 13438.3 3912 ROP 'MWD FT/H 1.16 3453.99 95.8846 3841 GR MWD API 20.22 1279.22 56.3211 3862 First Reading For Entire File .......... 12460.5 Last Reading For Entire File ........... 14416 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 12460.5 12496 12460.5 Last Reading 14416 14416 14391 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File T~e ................ LO Previous File Name ....... STSLIB.O01 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH ROP 12450.0 14416.0 GR 12489.0 14376.5 RPX 12501.5 14387.5 RPD 12501.5 14387.5 RPS 12501.5 14387.5 RPM 12501.5 14387.5 FET 12501.5 14387.5 $ MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 16 1 12450.5 14410.0 $ REMARKS: MERGED MAD PASS. $ 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 12450 14416 13433 3933 RAT MAD FT/H 3.41 3391.8 819.507 3933 GR MAD API 12.06 464.78 51.5897 3776 RPX MAD OHMM 0.44 2000 15.5332 3773 RPS MAD OHMM 0.22 2000 14.5263 3773 RPM MAD OHMM 0.39 2000 14.477 3773 RPD MAD OHMM 0.35 2000 18.5735 3773 FET MAD HR 35.4065 132.977 96.8122 3773 First Reading For Entire File .......... 12450 Last Reading For Entire File ........... 14416 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 First Reading 12450 12450 12489 12501.5 12501.5 12501.5 12501.5 12501.5 Last Reading 14416 14416 14376.5 14387.5 14387.5 14387.5 14387.5 14387.5 File T~e ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12461.0 ROP 12496.0 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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: STOP DEPTH 12857.0 12888.0 14-DEC-00 Insite 4.05.5 1.22 Memory 12888.0 44.4 91.5 TOOL NUMBER OO2 3.750 Aphron Flo Pr 8.70 .0 10.3 15000 4.4 .000 .0 .000 141.7 .000 .0 .000 .0 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block T~e ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDll0 FT/H 4 1 68 4 2 GR MWDll0 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 12461 12888 12674.5 855 ROP MWDll0 FT/H 8.05 243.16 83.6103 785 GR MWDll0 API 21.34 1279.22 107.259 793 First Reading For Entire File .......... 12461 Last Reading For Entire File ........... 12888 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 First Reading 12461 12496 12461 Last Reading 12888 12888 12857 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12857.5 14057.5 ROP 12888.5 14084.0 $ LOG HEADER DATA DATE LOGGED: 16-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 1.22 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14084.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BiT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 90.9 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER 035 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 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: Flo Pro/Aphro 8.70 .0 10.3 15000 4.2 .000 .0 .000 167.0 .000 .0 .000 .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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD120 FT/H 4 1 68 4 2 GR MWD120 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 12857.5 14084 13470.8 2454 ROP MWD120 FT/H 3.62 1327.36 104.757 2392 GR MWD120 API 20.22 144 38.3886 2401 First Reading For Entire File .......... 12857.5 Last Reading For Entire File ........... 14084 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 First Reading 12857.5 12888.5 12857.5 ,Last Reading 14084 14084 14057.5 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14058.0 ROP 14084.5 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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): STOP DEPTH 14222.5 14247.0 17-DEC-00 Insite 4.05.5 1.22 Memory 14247.0 80.2 93.3 TOOL NUMBER OO2 3.750 FLO PRO 8.66 .0 8.5 24000 5.8 .000 .000 .000 .000 .0 167.0 .0 .0 RE~R?fS: $ 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD130 FT/H 4 1 68 4 2 GR MWD130 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 14058 14247 14152.5 379 ROP MWD130 FT/H 10.65 3453.99 65.194 326 GR MWD130 API 26.4 181.82 85.0247 330 First Reading For Entire File .......... 14058 Last Reading For Entire File ........... 14247 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 First Reading 14058 14084.5 14058 Last Reading 14247 14247 14222.5 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14223.0 14356.0 ROP 14247.5 14383.0 $ LOG HEADER DATA DATE LOGGED: 18-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 1.22 DATA TYPE (MEMORY OR REAL-TIME): Memory 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAl, GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 14383.0 83.9 84 o TOOL NUMBER O35 3.750 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.75 MUD VISCOSITY (S): .0 MUD PH: 8.5 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD140 FT/H 4 1 68 4 2 GR MWD140 API 4 1 68 8 3 .0 167.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 14223 14383 14303 321 ROP MWD140 FT/H 4.14 279.55 100.991 272 GR MWD140 API 20.65 111.86 34.1156 267 First Reading For Entire File .......... 14223 Last Reading For Entire File ........... 14383 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 First Reading 14223 14247.5 14223 Last Reading 14383 14383 14356 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14356.5 14385.0 ROP 14383.5 14410.0 LOG HEADER DATA DATE LOGGED: 19-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 1.22 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14410.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.1 MAXIMUM ANGLE: 84.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 002 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S): .0 MUD PH: 9.5 MUD CHLORIDES (P?M): 24000 FLUID LOSS (C3): 87.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 167.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Ts~e .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD150 FT/H 4 1 68 4 2 GR MWD150 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 14356.5 14410 14383.3 108 ROP MWD150 FT/H 1.16 195.85 59.0305 54 GR MWD150 API 23.76 63.72 32.0729 58 First Reading For Entire File .......... 14356.5 Last Reading For Entire File ........... 14410 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 First Reading 14356.5 14383.5 14356.5 Last Reading 14410 14410 14385 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Qurves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 16 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH RAT 12450.5 GR 12489.0 RPD 12502.0 RPM 12502.0 FET 12502.0 RPS 12502.0 RPX 12502.0 $ STOP DEPTH 14410.0 14370.5 14381.5 14381.5 14381.5 14381.5 14381.5 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 (OHM_M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT M3%X 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order 19- DEC- 0~: Insite 4.05.5 4.27 Memory 14410.0 .0 .0 TOOL NUMBER PB01743RF3 PB01743RF3 3.750 FloPro 8.70 .0 8.5 26000 6.4 Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 RAT MAD161 FT/H 4 1 68 GR MAD161 API 4 1 68 RPX MAD161 OHMM 4 1 68 RPS MAD161 OHMM 4 1 68 RPM MAD161 OHMM 4 1 68 RPD MAD161 OHMM 4 1 68 FET MAD161 HR 4 1 68 .140 70.0 .063 164.0 .140 70.0 .180 70.0 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max Mean Nsam First Reading Last Reading DEPT FT 12450.5 14410 RAT ~tAD161 FT/H 3.41 3391.8 GR ,.MAD161 API 12.06 464.78 RPX MAD161 OHMM 0.44 2000 RPS MAD161 OHMM 0.22 2000 RP~'I ~bAD161 OH~I 0.39 2000 RPD MAD161 OHMM 0.35 2000 FET MAD161 HR 35.4065 132.977 13430.3 817. 971 51.2486 15.0489 14.5479 14.5491 19.1484 97.0189 First Reading For Entire File .......... 12450.5 Last Reading For Entire File ........... 14410 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 3920 12450.5 14410 3920 12450.5 14410 3764 12489 14370.5 3760 12502 14381.5 3760 12502 14381.5 3760 12502 14381.5 3760 12502 14381.5 3760 12502 14381.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/06/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/06/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 0~ Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Jun 24 09:13:04 2002 Reel Header Service name ............. LISTPE Date ..................... 02/06/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/06/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit 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 MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD P-02APB1 500292237670 BP Exploration (Alaska), Inc. Sperry Sun 24-JUN-02 MWD RUN 4 MWD RUN 5 AK-MW-00283 AK-MW-00283 B. JAHN B. JAHN MASKELL/WHIT MASKELL/WHIT 31 liN 13E 2624 2039 87.90 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 10.750 3263.0 2ND STRING 7.630 12405.0 3RD STRING 5.500 12852.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 - 3 ARE USED FOR'DRESSING CEMENT AND DRILLING WINDOW AND ARE NOT PRESENTED. i 11 3. MWD RUNS 6 & 7 COULD NOT GET THROUGH WINDOW AND ARE NOT PRESENTED. 4. MWD RUNS 4 & 5 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 5. GAMMA RAY (SGRD) LOGGED BEHIND CASING FROM 12440' MD, 8799' SSTVD TO 12454' MD, 8811' SSTVD. 6. DIGITAL DATA ONLY IS TIED INTO THE PDC LOG OF 8/17/93 WITH A KBE OF 87.9' AMSL. WELL P-02A IS TIED INTO P-02 AT THE KICK OFF POINT. THIS WELL KICKS OFF FROM P-02 AT 12454' MD, 8811' SSTVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 4 & 5 REPRESENT WELL P-02A WITH API ~ 50-029-22376-70. THIS WELL REACHED A TOTAL DEPTH OF 12906' MD, 8811' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12442.0 12875.5 ROP 12474.0 12906.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH MERGE TOP MERGE BASE 12440.5 12742.0 12742.5 12906.0 BASELINE DEPTH GR 12442.0 12440.5 12443.0 12441.5 12445.5 12444.5 12449.0 12449.0 12906.0 12906.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 4 MWD 5 $ REMARKS: MERGED MAIN PASS. $ 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 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 Name Service Unit Min Max Mean Nsam DEPT FT 12442 12906 12674 929 ROP MWD FT/H 1.11 160.23 49.9584 865 GR MWD API 19.16 1359.97 110.425 868 First Reading For Entire File .......... 12442 Last Reading For Entire File ........... 12906 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 12442 12474 12442 Last Reading 12906 12906 12875.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12440.5 ROP 12474,0 $ 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 BOTTOM) STOP DEPTH 12710.5 12742.0 09-DEC-00 In$ite 4.05.5 1.22 Memory 12742.0 38.4 72.0 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 035 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.800 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): .0 MUD PH: 10.1 MUD CHLORIDES (PPM): 14000 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 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 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 .0 145.9 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 12440.5 12742 12591.3 604 ROP MWD040 FT/H 1.11 160.23 48.4126 537 GR MWD040 API 19.58 1359.97 137.746 541 First Reading For Entire File .......... 12440.5 Last Reading For Entire File ........... 12742 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 12440.5 12474 12440.5 Last Reading 12742 12742 12710.5 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/24 Maximu~n Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12711.0 12875.5 ROP 12742.5 12906.0 $ LOG HEADER DATA DATE LOGGED: il-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 1.22 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12906.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.4 MAXIMUM ANGLE: 96.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE 035 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.800 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: F10 Pro MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): .0 MUD PH: 10.2 MUD CHLORIDES (PPM): 6800 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 133.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 12711 12906 12808.5 391 ROP MWD050 FT/H 1.6 108.18 52.4892 328 GR MWD050 API 19.16 130.14 65.7572 330 First Reading For Entire File .......... 12711 Last Reading For Entire File ........... 12906 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/24 Maximum Physical Record,.65535 File Type ................ LO Next File Name ........... STSLIB.004 First Last Reading Reading 12711 12906 12742.5 12906 12711 12875.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/06/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LIST?E Date ..................... 02/06/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
