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Home My WebLink About200-174 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIllntegrityCoordinator@bp.com> Sent: Saturday, April 11, 2015 9:11 AM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators; AK, OPS GC3 Field OTL;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; Wallace, Chris D (DOA);AK, OPS Well Pad AB; Glasheen, Brian P Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA) Subject: OPERABLE: Producer A-09A (PTD#2001740) Outer Annulus Repressurization Test Passed Attachments: image001jpg; image002.png;A-09A Wellbore Schematic.pdf; Producer A-09A TIO Plot 03-31-15.docx All, Producer A-09 (PTD#2001740) underwent a passing outer annulus repressurization test completed on 04/10/2015. A PPPOT-IC passed on 04/05/15.The outer annulus pressure buildup rate was determined to be 63 psi per day which is considered manageable by bleeds. The well is reclassified as Operable. A copy of the TIO plot is included for reference. Thank you, Kevin Parks SCANNED APR 2 3 2U15 (Alte)nate Laid ie Clmiei) BP Alaska-Well Integrity Coordinator G VV Global Wells �/ Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D& -II Integrity Coordinator Sent: Tuesday, March , 015 7:07 PM To: AK, OPS GC3 Facility OTL; A', •• C3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services :5- ations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells 0• - Is r; AK, OPS Prod Controllers; 'chris.wallace@alaska.gov'; AK, OPS Well Pad AB; Glasheen, Brian P; 'Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integri sv -••ineer; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer A-09A (PTD #2001740) OAP exceede• !:.SP All, 1 Producer A-09A(PTD#2001740) 90 day TIO Plot March 31, 2015 • 31X1 • tIA 2.000 0A 00 . y-0000 A .a • • • • ow O3I 15 01.105 012115 .,12E'S @a'?. 03n1S 0301,15 031115 0311-15 031515 TREE= 4"M:EVOY A 0 9 A SAFE /TES:RAD10 TRANSMIT IN WEATHER WBJJEAD= ItB/OY MOMTORING MUST BE TURNED OFF BEFORE ANY WELL ACTUATORAXaSON WORK INVOLVING NON RATIO SAFE EXPLOSIVES- OKB.I3EV= 82 55' CONTACT PAD OPER HIGH-ANGLE SDTRK ORIG:7",29#, BF.B El/= 54.49' L-80,LNR ABANDONED W/CMT 12/12/00-PBTD-10042',TD- KOP= 330(7 10098';BAKER WS TOP WAS 9232',3.80"WINDOW CUT Max Angle= 79"Q 9729 9234'-9240'. NOTE 4-1/2"TBG FELL OFF PKR DURING Datum MD= 983WWINDOW MILLING OPS/LANDED ON TOP OF 7"LNR TOP @ 8658'(BEDatum ND= 8800'SS HIND 3-3/16"LNR). ' ' 2015' —14 1/2"HES X LANDND NP,D=3.813" 13-3/8"CSG,72#,L-80,I)=12.715" H I 2681' GAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2979 2896 0 CA-MMG RK 5 3982 3894 11 CA-MMG RK 4 5981 5656 34 CA-MAG RK 3 6992 6503 32 CA-!AVG RK TOP OF 3-3/16'LNR,D=2.78' —1 8570' I I 2 7496 6940 29 CA-MMG RK 1 8533 7881 22 CA-MMG RK Minimum ID =2.37" @ 9,300' XO TO 2-7/8"LINER I I 8599' H4-1/2"HES X LANDING NIP,13=3.813" 8612' —19-5/8"BKR S-3 PKR TOP OF 7"LNR H 8658' S • • Behind CT LNR -�4 1/2"HES X LANDING NP,D=3.813" • • Behind CT LNR--14 1/2'HES XN LANDING NP,D=3.80' 4 1/2'TBG,12.6#,13-CR .01522 bpf,D=3.958" —1 FELL 9 5/8"CSG,47#,L-80,D=8.681" —I 9180' PERFORATION SUMMARY REF LOG:SINS CNJGR ON 01/12/01 ANGLE AT TOP PERP 72 DEG @ 9588' Note:Refer to Production DB for historical perf data 9300' —Ixo TO 2-7/8",STL LNR,13=2.37" SIZE SPF MS?VAL Opr>/Sgz SHOT SOZ 2" 6 9588-9613 0 02/11/02 2 2' 6 9618-9650 0 08/03/01 rv."9". 11* 2" 4 9662-9728 0 01/13/01 11 111 2" 6 9750-9760 0 07/13/02 111111111 111111111111 2" 6 9770-9790 0 07/13/02 111111111 PBTD —1 9,861' 13-3/16'/2-7/8"LNR 6.2#/6.16#,L-80,ID=2.37" 1H 9926' I DATE REV BY COMENTS DATE REV BY COPI&NTS PRUDHOE BAY UNIT 5/2/1981 ORIGINAL COMPLETION 03/12/14 TAQ/JMD ADDED SAFETY NOTE WELL A-09A 8/3/2000 L.M ROW-TBG 8 PKR CHANGE PERMT No:"2001740 01/14/01 RRW CTD I-IOI ZONTAL SDTRCK AR No: 50-029-20552-01 03/20/01 RNrrP CORRECTIONS SEC 35,T11 N,R13E, 1446'FM 8 921'FEL 08/13/01 ?!TP ADD PERF 11/05/05 LJUTLH D 8 ANGLE CORRECTION BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> Sent: Tuesday, March 31, 2015 7:07 PM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; 'chris.wallace@alaska.gov'; AK, OPS Well Pad AB; Glasheen, Brian P; Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R;AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer A-09A (PTD#2001740) OAP exceeded MOASP Attachments: image001jpg;A-09A Wellbore Schematic.pdf; Producer A-09A TIO Plot 03-31-15.docx All, Producer A-09A(PTD#2001740)outer annulus exceeded MOASP on March 27, 2015 with T/I/0= 280/1560/1040 psi. The well has known slow IAxOA communication; diagnostics will be ran to confirm no changes to the well characteristics. It has been reclassified as Under Evaluation for additional testing. Plan Forward: 1. DHD: Obtain gas sample off the annuli 2. Cameron: Perform PPPOT-IC 3. DHD: Run OART to establish BUR 4. WIE: Additional diagnostics as needed A copy of the TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Laurie Climer (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator GVVOr aal Wells �( Organrzaton WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 TREE= 4"McEVOY A 0 9 A SAFETY NOTES:RAM)TRANSMIT IN WEATI$2 WB_JfAD= AtEVOY MONITORING MUST BE TURNED OFF BEFORE ANY WELL ACTUATOR. AXELSON WORK INVOLVING NON RADIO SAFE EXPLOSIVES- OKB.T3EN= 82.55' H CONTACT PAD OPER. GH-ANGLE SDTRK ORIG:7",29#, ELEV_ 49 L-80,LNR ABANDONED W/CMT 12/12/00-PBTD-10042',TD- KOP= � 10098';BAKER WS TOP WAS 9232',3.80"WINDOW CUT 33Max Angle= 79"@ 9729' 9234'-9240'. NOTE 4-1/2"TBG FELL OFF PKR DURING WINDOW MILLING OOPS/LAMED ON TOP OF 7"LNR TOP @ Datura MD= 9834' OatumND= 8800'SS 8658'(BENND3-3/16"LNR). I I 2015' —14 1/2"HES X LANDND NP,D=3.813" 13-3/8"CSG,72#,L-80,D=12.715" H 2681' J , GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT: DATE L 6 2979 2896 0 CA-MG RK 5 3982 3894 11 CA-MM3 RK 4 5981 5656 34 CA-MM3 RK 3 6992 6503 32 CA-MGRK TOP OF 3-3/16"LNR,D=2.78" — 8570' ] I 1 2 7496 6940 29 CA-MM3 RK 1 8533 7881 22 CA-MM3 RK Minimum ID =2.37" @ 9,300' XO TO 2-7/8"LINER I I 8599' —I4-112"FES X LANDING NIP,D=3.813' >< 8612' --19-5/8"BKR S-3 PKR TOP OF 7"LNR — 8658' J • • - Behind CT LNR —14 1/2"HES X LANDING NP,D=3.813" • • - Behind CT LNR—14 1/2'HES XN LANDING NP,D=3.80' 4 1/2"TBG, 12.6#,13-CR,.01522 bpf,D=3.958" —f FELL / \ 9 5/8"CSG,47#,L-80,D=8.681" H 9180' I—, ' PERFORATION SL*V?VIARY REF LOG:SWS C f IL/GR ON 01/12/01 ANGLE AT TOP PERF:72 DEG @ 9588' Note: Refer to Production DB for historical pert data 9300' --{XO TO 2-7/8",SIL LNR,D=2.37" SEE SPF INTERVAL Opn/Sqz SHOT SQZ ` 2" 6 9588-9613 0 02/11/02 -'°` . 2" 6 9618-9650 0 08/03/01 ►•• . ♦ •. ♦11111 ` 2" 4 9662-9728 0 01/13/01 111111 2" 6 9750 9760 0 07/13/02 11111111111 111111 2" 6 9770-9790 0 07/13/02 111111111 1111111 PBTD —I 9,861' 13-3/16"/2-7/8"LNR 6.2#/6.168,L-80,D=2.37"1-1 9926' J DATE REV BY COMMENTS ' DATE REV BY COMMENTS NITS PRLDHOE BAY UNIT 5/2/1981 ORIGINAL COMPLETION 03/12/14 TAQ/JMD ADDED SAFELY NOTE WELL: A-09A 8/3/2000 L.M ROW-TBG&PKR CHANGE PERMIT Nb:"2001740 01/14/01 RRW CTD HORIZONTAL SDTRCK AR Nb: 50-029-20552-01 03/20/01 RNYTP CORRECTIONS SEC 35,T11 N,R13E 1446'FN_&921'FEL 08/13/01 '/TP ADD FERE 11/05/05 LJUTLH D 8 ANGLE CORRECTION BP Exploration(Alaska) Producer A-09A(PTD#2001740) 90 day TIO Plot March 31, 2015 Well A 20 1cot y.a :% o aw 1 WC <•'<t5 '.:••' :•^E'S U." ..'S 02i8 15. "2'1515 P34'S t&'S I ~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. Organizing RESCAN Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BEVERLY ROBIN VINCENT SHERYL ~V~JlNDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY _ sca'nning Preparation OVERSIZED (Scannable) [] Maps: · [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BEVERL~~INCENT SHERYL MARIA WINDY IF NO IN STAGE 1, PAGE(S) DISCREP~IE~E II BEVERLY ROBIN VINCENT SHERYL MAR~.~_~.~ NO FOUND: YES NO DAT~~ ~ RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Isl Quality Checked 12110/02Rev3NOTScanned.wpd 1 bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg W AUG 1 7 2012 Alaska Oil and Gas Conservation Commission L 333 West 7 Avenue Q / © `7 Anchorage, Alaska 99501 ■ (� /I- °GO Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A 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, 4h tiLsr- Mehreen Vazir BPXA, Well Integrity Coordinator • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) A -Pad Date: 04/15/2012 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 gal A -01A 2012420 50029201080100 1.3 NA 1.3 NA _ 11.10 7/21/2009 A -02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A -03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A -04 1720060 50029201150000 0.0 NA NA NA NA NA A -05A 2061280 50029201160100 0.0 NA NA NA NA NA A -06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 • A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA _ NA NA ..--, A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -26L1 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA _ 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A -31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 OPERA.BLE: A-09A (PTD #2001740) Tubing Integrity Restored Page 1 af ~ ~ • 't'p~ Schwartz, Guy l (DOA) ~~ ,?~ __ _ _ _ '1 _ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, July 07, 2009 10:40 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA}; Schwartz, Guy L(DOA); GPB, Rrea Mgr Central (GC1/3/FS3); GPB, GC3 OTL; GPB, GC3 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Hibbert, Nancy; GPB, Well Pad AB Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Sala, Jaycen (CH2MHill) Subject: OPERABI.E: A-09A (PTD #2001740) Tubing Integrity Restored All, V'Vell A-09A (PTD #2001740) passed a MITIA on 7/6/09 after setting dummying gas tift valves proving tubing integrity has been restored. This well is a natural producer and should be able to kick-off without a live gas lift valve design. The well has been reclassified as Operable. Please let us know if you have any questions. Thank you, Anna ~u6e, 1'. E. Well lntegrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 .~w..'~.~~'sii~..~r t~,tJ~. ., .. t~~~~ From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 02, 2009 1:35 PM To: GPB, Area Mgr Central (GCl/3/FS3); GPB, GC3 OTL; GPB, GC3 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Qperatlons Supervisor; ~PB, Wells Opt Eng; GPB, Opdmization Engr; GPB, Prod Controllers; Hibbert, Nancy; GPB, Well Pad AB Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UND~R EVALUATION: A-09A (PTD #2001740) TuIA Communfcation All, Well A-09A (PTD #2001740) recently failed a TIFL after being shut-in for the facitity shut-down. The weilhead pressures were tubing/IA/OA equal to 2100/2300/1010 on 46/29/09. The well has been reclassified as Under Evaluation. The plan forwad is to attempt to wait for the shut-down to be completed, return the well to production, and re-TIFI. the well. This will hopefully reset the checks in the gas iift valves and restore integrity. If this appraach is not successful or if the shutdown continues past the current plan, gas lift valves will be changed out and another TIFL will be attempted. A 710 Plot and Wellbore Schemat+c have been inc{uded for reference. Please let us know if you have any questians. Thank you, Anna ~Dude, ~P. E. Well Integrity Caordinator GPB Wells Group 7/27l2009 FW: UNDER EVALUATION: ~9A (PTD #2001740) TxIA Communi~on Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, July 02, 2009 2:57 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA) Subject: FW: UIVDER EVALUATION: A-09A (PTD #2001740) TxIA Communication Attachments: A-09A TIO Plot.doc; A-09A.pdf Jim, Tom, and Guy, I apologize for missing you on the original distribution. Thank you, Anna ~Du6e, 2'. E. Well Integrity Coordinatar GPB Welis Group Phone: (907) 659-5'102 Pager: (907) 659-5100 x1154 . .~'t.: ~.'~;,,~.,:~~ 5 i= ' ` ~ ; ~ ,.. . ~~~~ From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 02, 2009 1:35 PM To: GPB, Area Mgr Central (GCl/3/FS3); GPB, GC3 OTL; GPB, GC3 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Welis Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Hibbert, Nancy; GPB, Well Pad AB Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: A-09A (PTD #2001740) TxIA Communication All, Well A-09A (PTD #2001740) recently failed a TIFL after being shut-in for the facility shut-down. The wellhead pressures were tubing/IA/OA equal to 2100/2300/1010 on 06/29/09. The well has been reciassified as Under Evaluation. The plan forwad is to attempt to wait for the shut-down to be completed, return the weil to production, and re-TIFL the well. This will hopefully reset the checks in the gas lift valves and restore integrity. If this approach is not successful or if the shutdown continues past the current plan, gas lift valves will be changed out and another TIFL will be attempted. A TIO Plot and Wellbore Schematic have been included for reference. «A-09A TIO Plot.doc» «A-09A.pdf» Please let us know if you have any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coardinator GPB Wells Group Phane: (907) 659-5102 Pager: (807) 659-510Q x1154 8/31 /2009 PBU A-09A PTD #2001740 7/2/2009 TIO Pressures a ~ao~ ~,ooo 2000 1 000 -~-- Tbg -~ IA -~- OA OOA ~ OOOA ~ On u • TREE = 4" Mc EV OY ' WEL~HEAD = McEVOY 'AC7UATOR= AXELSON ' KB. E~EV = 82.55' ' BF. EI.EV = 54.49' ' KOP = 3300' I~ Max Rngle = ~ Datum MD = 79 @ 9729' 9834' Datum ND = 8$00' SS 13-3/8" CSG, 72#, 1-80, ID = 12.715" ~ TOP OF 3-3/16" LNR, tD = 2.78" ~ $570~ Minimum ID = 2.37" @ 9,300' XO TO 2-7/8"LINER TOP OF 7" LNR 8658' a-a~ SAFEfY~: RADIOTRANSMIT IN WEATHER M ONITO M UST BE TURNEA OFF BEFORE ANY WELL WORK INVO~VING IXPLOSIVES- CQNTACT PAD QPER. HIGH-ANGIE SDTRK. ORIG: 7", 29#, L-80, LNR ABANDONED W1CMT 12112/6Q-PBTD-10042', TQ-10098'; BAKER WS TOP WAS 9232`, 3.80" WINDOW CUT 9234'- 9240'. NOTE: 4-1/2" TBG FELL OFF PKR DURING WINDOW M ILLING OPS(LAND~ ON TOP OF 7" ~.NR TOP @ 8fi58' (BEHtND 3-3/16" LNR). ~-~4 1/2" NES X LANDIND NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DA7E 6 2978 2896 0 CA-MMG RK 5 3982 389A 11 CA-MMG RK 4 5981 5656 34 CA-MMG RK 3 6992 65Q3 32 CA-MMG RK 2 7496 6940 29 CA-MMG RK 1 8533 7881 22 CA-MMG RK $5gg' --~4-1J2" HES X LANDING NIP, ID= 3.813" $612° -"~ 9-518" BKR S-3 PKR, CT LNR~-~4 1/2" HES X LANDING NIP, ID = 3.813" Behind CT LNR~-~4 U2" HES XN LANDING NIP, ID = 3.80" ~ 4 112" TBG, 12.6#, 13-CR, .01522 bpf, fD = 3.958" ~-~ FELL 9 5/8" CSG, 47#, L-80, ID = 8.681" ~-~ 91$0~ PERFORATION SUMMARY REF LOG: SWS CNL/GR QN 01/12/01 ANG~E AT TOP PERF: 72 DEG @ 9588' Note: Refer to Production DB for historica! perf data SIZE SPF INTERVAL ppn/Sqz DATE Z" 6 3588 - 9613 t} d2/11i02 2" 6 9618 - 9650 O 08(03/01 2" 4 9662 - 9728 O 01/13l01 2" 6 9750 - 9760 O 07l13l02 2" 6 9770 - 9790 O 07l13/Q2 g3pp" (-{ XO TO 2-7/8", STL LNR, ID = 2.37" PBTD 9,861' 3-3/16" l 2-718" LNR, 6.2# / 6.16#, L-80, ID = 2.37" ( 9925' I QATE REV BY COMMENTS DATE REV BY COMMENT5 5/2t1981 ORIGtNA~ COMP~EfION 07/13/02 CJS/KK ADD PERF 8t3/2000 ~.M ROW-TBG & PKR CHANGE 09/30/02 BNUTP WANER SAFEfY NOTE 01/14/01 RRW CTDHORIZONTAL SDTRCK 02/20/03 (TLH WANERSAFEfY NOTE 03/20/01 RN/TP CORRECTIONS 11/05/05 LJUTLH ID & ANGLE CORRECTION 08l13/01 ?iTP ADD PERF 01/16(06 COM/PAG WANER SFTY NOTE DE1EfED 02114/02 P~NE/TLH ADD PERF PF2UDHOE BAY UNff WELL: A-09A PERMff No: ~2001740 API No: 50-029-20552-01 SEC 36, T11 N, R13E BP F~cploraYion (Alaska) 08/30/07 Schlumberger t~/", j\Mt..\ED S£? 1 ß '2.0G7 \}'",I1'\II ,'" NO. 4396 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 L ATTN: Beth . ~ \d'" vl~eÔ' ~' Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay End'cott /~ I Job# Loa Description Date BL Color CD I. MPC-08 / N/A RSTIWFL 08110/07 1 IVIl~I" 11767136 MEM INJ PROFILE I JÏ"(\ ,e; ,Gj-1A--:} 08112107 1 P2-16 11856185 INJECTION PROFILE (JTf' Ie. " - L.:l~ 08102107 1 07 -02A 11649983 MEM PROD PROFILE ¡Clt_ - f"6 $( 08107107 1 R-13 11856186 INJECTION PROFILE / I -r" ¡" ~ - f"I.I~ 08102107 1 D-11A 11649982 MEM PROD PROFILE /ei," - !"S<'~ 07126107 1 S-42 11686773 LDL I q &, - ('..-')i..j 08102107 1 S-43 11855804 LDL Jq4-^~:' 08/02107 1 16-07 11855806 STATIC PRESSURE SURVEY /"'1(~-::J.o4 08/04/07 1 16-21 11855805 STATIC PRESSURE SURVEY I '1i~ _.~/~ 08/04107 1 1-09A1L-21 11849930 SBHP SURVEY Jq~ - I'I!)Q 08104107 1 2-681S-17 11630491 LDL t1Ó(- C'A~ r 07127/07 1 1-2310-15 11846802 STATIC PRESSURE SURVEY U:r:(\. ,qq - J~ 'X' 08/11107 1 Z-46 11057080 CH EDIT PDC GR (USIT)~/'),4) -Ikl "It t:J:::"-I::Ji:J. 12/14105 1 A-09A 11216203 MCNL .Q(1D-I~U" 1~{¡t;}4.1 06129106 1 1 L3-11 11801065 RST ì"7l"t) - ~'::ll .,.. M::r¿j~< 05131107 1 1 PLEASE ACKNOWLEDGE RECEIPt,laY,ID"yNING AND RETURNING ONE COPY EACH TO: 1j1\ I' . " '('~"!' F"'" ~" r ~-~ BP Exploration (Alaska) Inc. ¡t'\~ BL'""'!I 'N-·' 11 \~\ll¡''"' Petrotechnical Data Center LR2-1 . ", !"".,/' ,i.,.". ,j +, li.'o," 900 E. Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 """'''''. AK "'50~_ ATTN: Beth Received bYC,,- -'-"~ EP if 2007 Date Delivered: '1:1:.'1"1;..,, 'iI <I {' . [' ", " I ,'f-..' 'Y,'Hot'",/,_., ('<-::¡~'X~ ,:(lfJ;:::L ~,n~THTW3~?'~,Orn . . ~ RECEIVED . STATE OF ALASKA A ~~O;1 ALA OIL AND GAS CONSERVATION COM~ON APR 262007 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull TubinG Change Approved Program D Opera!. Shutdowr(] 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Class: Development P' Stratigraphic StimulateQ WaiverD Time Ex1ensionD Re-enter Suspended Well D 5. Permit to Drill Number: 200-1740 - ion Exploratory Service 6. API Number: 50-029-20552-01-00 ;' 9. Well Name and Number: 82.55 KB' PBU A-09A ' 8. Property Designation: ADLO-028286 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool· 11. Present Well Condition Summary: Total Depth measured true vertical 9925 ( 8903 ( feet feet Plugs (measured) Junk (measured) 9850' None Effective Depth measured 9861 ' feet true vertical 8889 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 28' - 138' 28' - 138' Surface 2667' 13-3/8" 72# L-80 SURFACE - 2695' SURFACE - 2695' 5380 2670 Production 9152' 9-5/8" 47# L-80 SURFACE - 9180' SURFACE - 8572' 6870 4760 Liner 576' 7" 29# L-80 8658' - 9234' 8081' - 8623' 8160 7020 Sidetrack Liner 1355' 2-7/8" 6.16# L-80 9300' - 9861' 8983' - 8889' 13450 13890 Sidetrack Liner 730' 3-3/16" 6.2# L-80 8570 - 9300 7999' - 8683' 0/2 2007 Perforation depth: Measured depth: 9660 - 9726 SCANNED MAY - - - - True Vertical depth: 8846.28 - 8860.31 - - - - Packers and SSSV (type and measured depth) 4-1/2" 12.6# 13-CrTBG 0 SURFACE-8612' Tubing tail fell off pkr & top of tailpipe landed on top 7" liner 9-5/8"X4-1/2" BKR S-3 8612' o 0 o 0 o 0 Tubing: (size, grade, and measured depth) 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 Oil-Bbl 280 278 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 2886 777 0 3394 869 0 15. Well Class after proposed work: Exploratory Development P' 16. Well Status after proposed work: Oil P' Gas WAG Tubing pressure 208 202 13. Service x Contact Gary Preble WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature Title Data Management Engineer Printed Name Phone 564-4944 Date 4/23/2007 RBDMS BFl MAYO 2 2007 ~';(ð- Submit Original Only .... . . A-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/16/2007 MIRU CTU #9. Perform weekly BOP test. Depressure IA to 400 psi. wellbore fluid pack w/2% KCL. Continued on 04/17/04 WSR. 4/17/2007 Continued from 04/16/07 WSR. Complete fluid packing wellbore w/ 210 bbls 2% KCL while RIH w/ 2" JSN. Load 110 bbl diesel down backside. Drift clear to 9844'. Jet 65 bbls of 50:50 diesel/xylene from 9844'-9538'. Pull to 9439', let it soak. Pump 50 bbls 12%9:1 DAD acid while recipricating across perfs from 9538 to 9740 - Over displace acid with 100 bbls 2%KCL -. Did not see any significant breaks in WHP - Conduct injectivity test during overdisplacement- 1 bpm /500 psi - 2 bpm /750 psi - 3 bpm / 1010 psi - 4 bpm / 1315 psi - 4.6 bpm 1475 psi final injection rate at end oh 100 bbls 4.6 bpm / 1425 psi. FP backside and lines to ASRC test sep. **** RDMO **** Notify PCC/PO well ready to POP to ASRC T Sep .Depart location. Drive to W pad. Return for N2 lift. Rig in for N2 Lift. Continued on 8/07 WRS. 4 operations, try to flow well, for N2 lift. 4/18/2007 CTU MIRU, N2 lift well, flow back acid 4/18/2007 CTU #9 w/1.75" N2 Lift Post Acid. Continued from 04/17/07 MU 2" JSN. Begin N2 from surface @ 400 scf/m w/ stops @ 1000',2000',3000'. PUH to 2400 and start back down again ultimately lifting from 7500'. Getting good returns but no formation gas. RIH to 8400', Continue N2 @ 500 scf, Shut down N2, *** Job in Progress***, Continue on 04/19/07 4/1 unit #4 continue 48 hour stabilization 4/1 #9 w/1.75" Lift Post Acid. Continued from 04/18/07 WSR. Well flowing to Plant @ 2500 bpd fluid, 700,000 scfd gas. TOOH. Rates & Pressures 2,100,00 scf/d gas, fluid rate 2800 bpm, -400 bpd oil, WHT 139 degrees, Rig off well and secure. Leave mast up do to wind. ** Job Complete*** Go on Weather Standby at 06:00. FLUIDS PUMPED BBLS I 52 METHNV A TER 52 . TOTAL ----........ FW: A-09A Cancel Waiver e e PrD~ 2iJo - I r-¡ 4- Subject: FW: ;\-09A Cancel Waiver From: "NSU, ADW WëUfutëgrjty Engineer"<NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 15 .Tân 200616:16:30 .,.0900 ',' "'> , TO:"\Rossberg, R Stevert',I'<SteveILRos§þerg. .... "'Jiìn Jegg@admiri.state.aïG\fS, wintqn-,-aubert@admin.stâtê.ak.us~)iNS~t;.A ". .... ,":þerations Supervisor" 'l," " . <NSÙADWWellOperationsSupe' ",~;Jl'C? .'GPB,WEi:Us Opt ~n?"'>\;,l.",./;· '" <GPBWellsOpt~g@BP.com>, II .', Op~mlzâtIon Engr" <GPBOptIm!~atl0nEngr@BP;com>, .. "GPB, GC~reiMgr" <GPBGC3: " BPJ,tom>, "GPB,' GC3 W ellpad ~adl1 .]i·:2:' <GPBGC3Wellfidtêad@BP.com~·Well Pads BAX" <GPBWellÞadsBAX;", P.com>, ,. "Engel, Harry R~:<Harry.Engel@B: > 'Kurz, John"'<john.kurz@BP.com>,T .... Ison, Bri~.fI"; ~~:7Å~:rlson~J;}~~So~;ersíf@B~.CO ,ÄûJtGt"På~IA" <Paul. A' ~~. .'·:;'riP.coCí~'·"DUb~~il"j> AnnäT'" . ube@BP.com>, "F:rilzier,Nicholas B"'/fNicholas. efrP~'øonp It, RYan:g; (Y~ÇO)" <Ryan.Holt@BP.com>, "Hl.lghes,:Andr&~·(V~ßO)" <hugha4@BP.com>, "J ..... .~, Roland': I\..Ú\ŒCQ)" <JohnsRD2@BP.com>, "Luckett, E1Y:'Z. (vtCO)" <luck¢@BP.com>, "MCOLLUM, qgpy ggv-E '," <Cody.McCollum@BP.com>, "Morse, Kenny (V. );;¡:¡~MorseKI@BP.com>, "Parks, K~vin .' ECO)" <ParksKD@¡BP.c ,>.."Pinkston, Bruce M' CÒJ!' <PinkstBM@BP.com>, "Winslow, Jact::L." " " sW@BP.com> Hello all. The waiver for well A-09 has been canceled and the well reclassified as a Normal well. Review of the TIO plot indicates no recent history of IAxOA communication. Wellhead MAASP's are revised to IAlOA:::: 2000/1000 psi. lead Operator: Would you please ensure any waiver related sígnage is removed from the wellhouse. Please call if you have any questions. Joe 659-5102 ,II From: NSU, ADW WI Tech Sent: Sunday, January 15, 20062:56 PM To: NSU, ADW Well Integrity Engineer Subject: A-09A Recommend Cancel Waiver Hello, I have reviewed the TIO and events history of well A-09A. The IAxOA communication appears to have been mitigated, and has subsequently passed TIFl and MIT-OA. I recommend that we cancel the waiver and return to normal. lof2 1/18/20064:35 PM FW: A-09A Cancel Waiver e Please contact me with any concerns. e Thanks, Cody McCollum Well Integrity Tech Office: 659-5524 Pager: 659-4326 # 786 20f2 1/18/20064:35 PM Permit to Drill 2001740 MD 9925 ~ ']'VD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. PRUDHOE BAY UNIT A-09A Operator BP EXPLORATION (ALASKA) INC 8903. ~ Completion Dat 1/13/2001 -'"' Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20552-01-00 UIC N REQUIRED INFORMATION Mud Log No Sample N__~_o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Media Digital Fmt Cn,,~eeNo~s (data taken from Logs Portion of Master Well Data Maint Name Log Log Scale Media Interval Run OH I No Start Stop CH 9021 9921 Case Dataset Received Number Comments 3/2/2001 09938 4~31~'~ 1-99L;t-1---'''~ Directional Survey Directional Survey 9941--~'~- -L-'f~Verification R P~nsated Neu Log 2 P/GR 2/5 --~D ROP/GR 2/5 9225 9867 Case FINAL FINAL FINAL 9225 9867 CH FINAL CH FINAL 9021 9921 CH FINAL 9021 9921 CH FINAL 9240 9922 oh FINAL 9240 9922 oh 1 9754 9817 Case 3/7/2001 2/27/2001 2/27/2001 3/7/2001 3/7/2001 3/2/2001 3/2/2001 3/16/2001 3/16/2001 7/22/2002 09941 ~'2'~5-9867 ~'"""~- ~ Dir Survey Digital Data ', Dir Survey Paper Copy ~, _ t-IS Verification paper Copy ~ 9938 ~00~1-9921 Digital Data ~ 9021-9921 BL, Sepia 0240-0022 Bt., Sepia 92~3-9922 BL, Sepia 11214~oil Flag Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received?~'' Analysis ~ "' ' :.' _ Rnn~.iv~.rl? Daily History Received? ~)/N Formation Tops ~ N Comments: Permit to Drill 2001740 MD 9925 TVD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. PRUDHOE BAY UNIT A-09A Operator BP EXPLORATION (ALASKA) INC 8903 Completion Dat 1/13/2001 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20552-01-00 UIC N Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFS Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development _X Exploratory_ Stratigraphic__ Service_ 4. Location of well at surface 1446' FNL, 920' FEL, Sec. 35, T11N, R13E, UM At top of productive interval 1081' FNL, 3724' FEL, Sec. 36, T11N, R13E, UM At effective depth 1288' FNL, 3298' FEL, Sec. 36, T11N, R13E, UM At total depth 1310' FNL, 3239' FEL, Sec. 36, T11 N, R13E, UM .(asp's 654454, 5949001) (asp's 656921, 5949417) (asp°s 657352, 5949219) (asp's 657411, 5949198) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2667' Production 9152' Liner 576' Sidetrack Liner 1355' 9925 feet Plugs (measured) 8903 feet 9861 feet Junk (measured) 8889 feet 6. Datum elevation (DF or KB feet) RKB 83 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-09A 9. Permit number / approval number 200-174 10. APl number 50-029-20552-01 11. Field / Pool Prudhoe Bay Oil Pool Tagged TD @ 9850' (07/13/2002) Size Cemented Measured Depth True Vertical Depth 20" x 30" 72 c.f. 138' 138' 13-3/8" 3906 c.f. Arcticset II 2695' 2695' 9-5/8" 1270 c.f. Class 'G'; 130 9180' 8572' c.f. Acrtic I 7" 403 c.f. Class 'G' 8658' - 9234' 8081' - 8623' 2-7/8x3-3/16" 135 c..f. Class 'G' 8570' - 9925' 7999' - 8904' Perforation depth: measured Open Perfs 9588'- 9613', 9618'- 9650', 9660'- 9726', 9750'- 9760', 9770'- 9790' true vertical Open Perfs 8828' - 8835', 8836' - 8844', 8846' - 8860', 8865' - 8867', 8869' - 8879' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-Cr TBG@ 8612'. Tubing Tail fell off PKR &~.t~p~f~z~i~il~e~la~p~[, on top of 7" liner. Now behind 3-3/16" liner. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" BKR S-3 Packer @ 8612'. 4-1/2" HES X Landing Nipple @ 2015'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 06/26/2002 Subsequent to operation 07/15/2002 JUL 1 ¢ 2002 Alaslca Oil & Gas Cons. C0mmissior, Anchorage Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 546 6767 906 282 1010 5228 1518 283 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _X Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing_is tr~i~ and correct to the best of my knowledge. DeWa},ne R. Scl~norr Form 10-404 Rev 06/15/88 · ORIGINAL Date July 16, 2002 Prepared by DeWayne R, Schnorr 564-5174 SUBMIT IN DUPLICATE 06/12/2002 06/28/2002 06/29/2002 07/07/2002 07/08/20O2 07/10/2O02 07/11/2002 07/1 2/2002 07/13/2002 06/12/02 06/28/02 A-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERFORATING: PERFORATING: PERFORATING: PERFORATING: PERFORATING: PERFORATING: PERFORATING: DRIFT/TAG PERFORATI'NG M]:LL; PERFORAT]:NG MILL; PERFORATING MILL; PERFORATING DRIFT/TAG JEWELRY LOG--DEPTH CONTROL; MILL; PERFORATING PERFORATING: MILL; PERFORATING PERFORATING: PERFORATING EVENT SUMMARY 2.0" DUMMY GUN TO 9525' SLM. RD. SECURED WELL. NOTIFIED DSO OF WELL STATUS. <<< WELL LEFT SHUT-IN. DSO TO POP >>> <<< AD PERF PROGRAM IN ZONE 4A >>> RIH WITH SWS MEMORY LOGGING TOOLS FOR TIE IN LOG. UNABLE TO PASS THROUGH LINER @ 8587' CTM (8570' SCHEMATIC DEPTH). POOH. MU BOW CENTRALIZER ON TOOL STRING. RIH. UNABLE TO PUSH THROUGH LINER @ 8592' CTM. POOH. MU ADDITIONAL KNUCKLE JOINT AND HYD CENTRALIZER ABOVE LOGGING TOOL. RIH, THROUGH LINER TOP. TAG OBSTRUCTION @ 9642', UNABLE TO PUSH DEEPER. LOG TIE-IN, PAINT FLAG @ 9500'. POOH (LOGGED FROM 9642' - 8200' FOR LINER JEWELRY PASS.) PU JSN TO HOT OIL LINER. RIH. 06/29/02 07/07/02 O7/O8/O2 WASHED TBG / PERFS, PUMPED 20 BBLS DIESEL / XYLENE, 2 BBLS ACROSS PERFS. RIH WITH PERF GUN #1 TO PERF INTERVAL 9770'- 9790'. SET DOWN AT 9632', UNABLE TO GO DEEPER. POOH RDMO. <<< RETURNED WELL TO PAD OPERATOR TO POP >>> MIRU DS CTU #8, PERFORMED BOP TEST. KNOCK DOWN WHP. RIH WITH WEATHERFORD 2-1/8" MOTOR WITH 2.26" JUNK MILL. SAT DOWN @ 9636' CTMD. ATTEMPTED TO MILL, BUT CANNOT SEE MOTOR WORKING. LOAD WELL WITH DEAD CRUDE. RIH MILLING @ 9636' CTMD. SEEING SOME MOTOR WORK. WHP SUDDENLY INCREASED. RIH MILLING, TAKING RETURNS TO TANK. STALLS @ 9636' CTMD ACT LIKE BIT IS STICKING IN TAR / ASPHALTINES. PUH ABOVE LINER TO FLOW WELL. FLOWED 10 BBLS TO TANK. RBIH MILLING 9633'. SAME STICKY STALLS (SUSPECT ASPHALTINES). POOH TO INSPECT TOOLS. NO WEAR FOUND ON MILL. ASPHALTINES FOUND ON CONNECTOR SHOULDER. CALL FOR HOT OIL. PUMPED 80 BBLS OF 90/10 DIESEL/XYLENE WITH NO GAIN IN DEPTH (9653'). CALLED OUT FOR 15 BBLS 15% 90/10 DAD ACID. HAS A 300PSI DROP IN INJECTION PRESSURE (-900 PSI Page 1 (' A-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/08/02 (continued) TO 600 PSI) POST ACID OVERDISPLACED 20 BBLS. COULD NOT GET PAST 9653'. DECIDED TO PULL PLUG AND TRY AND RUN A LIB ON SL. 07/10/02 DRIFT AND TAG W/2.1" LIB. SIT DOWN AT 9622' SLM, CO MAN HAS LIB EVALUATING IMPRESSION. RIH W/5' X 2" PUMP BAILER, GET NO RETURNS. <<< LEFT WELL SHUT-IN & NOTIFIED PAD OPERATOR >>> 07/11/02 MIRU UNIT #8. OBTAIN HOT WORK PERMIT, AND WELDED ON CONNECTOR FOR 1-11/16" MOTOR AND 1.85" DIAMOND SPEED MILL (OAL = 10.36"). PRESSURE TESTED ALL SURFACE LINES AND FUNCTION TESTED BOP's. RIH W/BHA #1. TAGGED @ 9646', STARTED MILLING @ 0.8 BPM WITH WELL FLOWING. MILLED TO 9680' CTMD, BROKE THROUGH SCALE?? CONTINUE RIH TO 9820' CTMD. POOH. NO MARKS ON MILL. RIH W/BHA #2 (1-11/16" MHA, 1-11/16" MOTOR, 2.22" MILL). 07/12/02 RIH W/2.22" MILL. SAT DOWN AND BEGAN MILLING @ 9632' CTMD. MILLED TO 9649' CTMD AND RAN INTO SLOW MILLING. POOH. CHANGED OVER TO A 2.3" DIAMOND SPEED MILL (NOTICED A SMALL AMOUNT OF SCALE ON JUNK MILL 99% CARBONATE AS PER DS LAB. TAG OBSTRUCTION @ 9645' SLOW MILL MILLING TO 9680'. INTERMITTENT SCALE BETWEEN 9680' AND 9750'. FREE SPIN FROM 9750' TO 9820'. PUMPED 15 BBLS 12% HCL ACROSS INTERVAL TO CLEAN ANY SCALE SHEATH. POOH. 07/13/02 RIH WITH MEMORY GR/CCL. LOGGED INTERVAL 9850' CTMD UP TO 9350' CTMD. FLAGGED PIPE @ 9790' CTMD. POOH W/LOGGING TOOLS. RIH WITH GUN #1 (20'- 2" PJ2006 HMX, 6 SPF, 60 DEG). SHOT FROM 9770'- 9790'. POOH. RIH W/GUN #2 (10' SAME AS PREVIOUS). SHOT FROM 9750' - 9760'. POOH. ALL SHOTS FIRED ON BOTH GUNS. RDMO. PERF SUMMARY: 9750' TO 9760' AND 9770' TO 9790'. NOTE: HEAVY CARBONATE SCALED MILLED FROM 9630' TO 9680' CTMD. <<< JOB COMPLETED >>> FLUIDS PUMPED BBLS 1 DIESEL FOR PRESSURE TESTING SURFACE PRESSURE CONTROL EQUIP 2O METHANOL 70 50/50 METHANOL WATER 262 DIESEL 489 CRUDE 170 KCL WATER 75 1% KCL WATER 1252 1% EXTRA SLICK KCL 71 XYLENE 10 1.5# BIOZAN 15 15% 90/10 DAD ACID 15 12% HCL ACID 2450 TOTAL Page 2 A-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/13/2002 ADD PERFS THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2" POWERJET, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 9750'-9760' 977O'-9790' Page 3 TREE= 4" McEV OY WELLHEAD= McEVOY ACTUATOR= AXELSON KB. B. EV = 82.55' BF. REV = 54.49' iKOP= 3300' j Max Angle = 34 @ 5600' Datum IVD = 9834' DatumTVD = 8800' SS 13-3/8"CSG, 72#,L-80, ID= 12.715" H 2681' IMinimum ID = 2.37" @ 9,300' I XO TO 2 7/8". 6.16#, STL LINER ITOP OF 3-3116" LNR, ID = 2.78" H 8570' ITOP OF 7" LINER H 8658' A-09A SAFEW NOTES: RADIOTRANSMIT IN WEATI-ER MONITORING MUST BE 'tURNED OFF BEFOREA NY WELL WORK INVOLV lNG E)(PLOSIV ES- CONTACT PA D OPERATOR. HIGH-ANGLESDTRK. ORIG: 7", 29#, L-80, LIaR ABA M3ONED W/CMT, 12112/00; PBTD WAS 10,042'; TD WAS 10,098; BAKER WHIP. TOP WAS 9,232', 3.80' WNDOW CUT 9234'-9240'. NOTE: 4-112" TBG FELL OFF PKR DURNG WINDOW MLMNG OPERATIONS A ND LA NDED ONTOP OF 7" LIaR TOP@ 8658' (BEI-IND 3-3/16" LI~). 2015' ~--~4 112"HESXLANDINDklP, ID=3.813" I GAS LIFT MANDRELS ISTI MD ITVDIDEVl WPE IVLVILATCHIPORTI DATE I i 6 12979128961 0 ICA-tvfvlGI IRI( I I I 4 1598~ 158561 34I CA-~GI I"<I I I 3 169~2165031 32ICA-~GI I"~I I I 2 174~168~01 29ICA-$GI I"~I I I 118533178841 22ICA-~GI IREI I I 8599' H4-112" HES X LANDING NIP, ID= 3.813" I ~612' H9-~i~, BK. S-3PERI 4 1/2" 'rBG, 12.6#, 13-Cr, .01522 bpf, ID= 3.958" H FELL CT Liner H4 ~/2" HES XLANaNG N,P. ,D= 3.8~3" I Behind CT LinerH4 1/2" I-ES XN LANDNG NIP, ID = 3.80" 9 5/8" CSG, 47#, L-80, D = 8.681" H 9180' Behind CT Lin er H ELMD TT NOT LOGGED 9300' HXOT02-7/8", S'11. LNR, MINID= 2.37" PERFORATION SUMMARY REF LOG: SWS CI~LIGR ON 01112/01 ANGLEATTOP PERF.' 76 DEG @ 9662' Note: Refer to Production DB for historical 3erf data SIZE SPF INTERVAL OpnlSqz DATE 2" 6 9588 - 9613 O 02/11/02 2" 6 9618 - 9650 O 08/03/01 2" 4 9652 - 9728 O 0111 3/01 2" 6 9750 - 9760 O 0711 3/02 2" 6 9770 - 9790 O 0711 3/02 ~ 9,861' I 9~25' 3-3116" / 2-7/8" LNI~ 6.2# / 6.16#, L-80, ID = 6.80" DATE ~ BY COMIVENTS DATE REV BY COlVlVIENTS 5/2/1981 ORIGINAL COIVPLErlON 0811 2/01 DRSIKAK CORRECTED PERMIT NO. 8/3/2000 L.M ROW-TBG & PKR CHANGE 08113/01 ?/TP ADD PERF 114/2001 SIS-CS REDLINE 02114/02 PWE/tlh ADDPERF 01114/01 RRVV CrD HORtZONTAL SD'rRCK 07113/02 CJS/KK ADD PERF 03120101 RN/TP CORRECTIONS PRUDHOE BAY UNIT WELL: A-09A PERIVEI' No: 2001740 APl No: 50-029-20552-01 Sec. 36, 11N, 13E BP Exploration (Alaska) {. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1446' FNL, 920' FEL, Sec. 35, T11 N, R13E, UM At top of productive interval 1081' FNL, 3724' FEL, Sec. 36, T11N, R13E, UM At effective depth 1288' FNL, 3298' FEL, Sec. 36, T11 N, R13E, UM At total depth 1310' FNL, 3239' FEL, Sec. 36, T11N, R13E, UM 5. Type of Well: Development _X Exploratory_ Stratigraphic_ Service._ (asp's 654454, 5949001) (asp's 656921, 5949417) (asp's 657352, 5949219) (asp°s 657411, 5949198) 6. Datum elevation (DF or KB feet) RKB 83 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-09A 9. Permitnumber/approvalnumber 200-1740 10. APInumber 50-029-20552-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2667' Production 9152' Liner 578' Sidetrack Liner 1355' 9925 feet Plugs (measured) 8903 feet 9861' feet Junk (measured) 8889 feet Size Cemented Measured Depth True ,Vertical Depth 20" x 30" 72 c.f. 138' 138' 13-3/8" 3906 c.f. Arcticset II 2695' 2695' 9-5/8" 1270 c.f. Class 'G'; 130 9180' 8572' c.f. Acrtic I 7" 403 c.f. Class 'G' 8658' - 9234' 8081' - 8623' 2-7/8x3-3/16" 135 c.f. Class 'G' 8570' - 9925' 7999' - 8904' Perforation depth: measured Open Perfs 9588'- 9613', 9618'- 9650', 9660'- 9726' RECEIVED true vertical Open Perfs 8828' - 8835', 8836' - 8844', 8846' - 8860' FEB ? 2002 Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, 13-Cr TBG @ 8612'. Tubing Tail fell off PKR & top on top of 7" liner. Now behind 3-3/16" liner. 9-5/8" x 4-1/2" BKR S-3 Packer @ 8612'. 4-1/2" HES X Landing Nipple @ 2015'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well opera 2/9/2002 Subsequent to ope 2/14/2002 OiI-Bbl 447 Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 3280 1109 850 8047 682 Casing Pressure Tubing Pressure 245 271 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~,,a~~--a.~33~~ Title: Technical Assistant Form 10-404 Rev 06/1§/88 · ORIGINAL Date February 18, 2002 Prepared by DeWayne R, Schnorr 564-5174 ,~11 . SUBMIT IN DUPLICA~ A-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/23/2002 02/10/2002 02/11/2002 PERF(ADD-PERF): DR]:FT/TAG PERF(ADD-PERF): JEWELRY LOG--DEPTH CONTROL; PERFORAT]:NG PERF(ADD-PERF): JEWELRY LOG--DEPTH CONTROL; PERFORAT:[NG EVENT SUMMARY 01/23/02 ( WELL FLOWING ON ARRIVAL ) DRIFT W/KJ 2" DUMMY GUN SB 157" OAL STOP @ 9570' SLM DUE TO DEV. RDMO ( PAD OP. WILL POP WELL ) 02/10/02 MIRU. PU MEM CCL/GR AND RIH. LOG DOWN/UP CCL-GR FROM 9359' - 9800'. POH. MU PERF BHA. 02/11/02 RIH W/25' X 2" 6 SPF POWER JET PERF GUN. MAKE DEPTH CORRECTION AT FLAG. SHOOT 9588' - 9613' WITH WELL FLOWING ON AL TO SYSTEM. POH. ON SURFACE. ALL GUNS FIRED. FLUIDS PUMPED BBLS 1 DIESEL FOR PRESSURE TESTING SURFACE PRESSURE CONTROL EQUIP 128 METHANOL WATER 2% KCL WATER TOTAL 02/11/2002 ADD PERFS THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2" POWERJET, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 9588' - 9613' Page 1 ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __X Exploratory__ Stratigraphic_ Service_ 4. Location of well at surface 1446' FNL, 920' FEL, Sec. 35, T11N, R13E, UM At top of productive interval 1082' FNL, 1555' FWL, Sec. 36, T11N, R13E, UM At effective depth 1288' FNL, 1981' FWL, Sec. 36, T11N, R13E, UM At total depth 1310' FNL, 2040' FWL, Sec. 36, T11N, R13E, UM (asp°s 654454, 5949001) (asp's n/a) (asp's 657352, 5949219) (asp's 674755, 5981642) 12. Present well condition summary Total depth: measured true vertical 9925 feet Plugs (measured) 8903 feet 6. Datum elevation (DF or KB feet) RKB 83 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-09A 9. Permit number / approval number 200-174 10. APl number 50-029-20552-01 11. Field / Pool Prudhoe Bay Oil Pool Window cut @ 9234' - 9240'. Abandoned 7" csg below 9234'. Effective depth: measured true vertical 9861 feet Junk (measured) 8889 feet Casing Length Conductor 110' Surface 2667' Production 9152' Liner 576' Sidetrack Liner 1355' Size Cemented Measured Depth True Vertical Depth 20" x 30" 72 c.f. 138' 138' 13-3/8" 3906 c.f. Arcticset II 2695' 2695' 9-5/8" 1270 c.f. Class 'G'; 130 9180' 8572' c.f. Acrtic I 7" 403 c.f. Class 'G' 8658' - 9234' 8081' - 8623' 2-7/8x3-3/16" 135 c.f. Class 'G' 8570' - 9925' 7999' - 8904' Perforation depth: measured Open Perfs 9618'- 9650', 9660' - 9726' true vertical Open Perfs 8836' - 8844', 8846' - 8860' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) R£¢EIYED AUO 2001 Alaska 0ii & Gas C(/ns. C0mmissi0r 4-1/2", 12.6#, 13-Cr TBG @ 8612'. Tubing Tail fell off PKR & top of ta~il~13N]aed on top of 7" liner. Now behind 3-3/16" liner. 9-5/8" x 4-1/2" BKR S-3 Packer @ 8612'. 4-1/2" HES X Landing Nipple @ 2015'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well opera Subsequent to ope Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 7/20/2001 254 1152 1308 986 8/4/2001 1343 296 1164 1145 Tubing Pressure 225 1119 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~X Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,~~,t~.~ ~~____,.~~~,~ Title: Technical Assistant y e R. Schnorr Date August 10, 2001 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL, SUBMIT IN DUPLICATE A-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/25/2001 08/02/2001 08/03/2001 PERF(ADD-PERF): DRIFT (PRE CTU ADD PERFS) PERF(ADD-PERF): ADD PERF PERF(ADD-PERF): ADPERF / HOT OIL EVENT SUMMARY 07/25/01 08/02/01 DRIFTED INTO 2 7/8" LINER W 2" DUMMY GUN STOPPED TOOLS @ 9350' SLM PER CO-MAN'S INSTRUCTIONS. WELL RELEASED TO PAD OPER FOR PRODUCTION. MIRU DS CTU #5. SHUT IN LIFT GAS. WITH WING OPEN, RIH WITH MEMORY GR/CCL. SAT DOWN AT 9707' CTMD. LOGGED FROM 9707' TO 9300'. FLAGGED PIPE AT 9547.5' AND POH. HEAVY ASPHALTINES ON TOOLS. CORRECTION OF (-0.75') PLACES EOP FLAG AT 9531.5' CORRECTED CTD. FROM TAG AT 9706' CORRECTED, 22' OF PERFS COVERED. TALK WITH WELLS SUPERVISOR, DECIDE TO HOT OIL FCO PRIOR TO ADPERF. ***CONTINUE ON 08-03-01 WSR*** 08/03/01 ***CONTINUED FROM 08-02-01 WSR *** RIH WITH BAKER 2.125" BHA, 2" STINGER, 2" JSN, JET HOT OIL TO TAG AT 9707' CORRECTED CTD. DIFFICULT JETTING ASPHALTINES, USE 5 BBL DIE/ZYL PILLS TO BREAK THROUGH. HOT OIL TO 9860' CCTD, (PBTD), POOH. RIH WITH GUN #1 (20' SWS 2" PJ LOADED 6 SPF). TIE-IN TO FLAG AND PERF 9630' TO 9650'. POOH. WELL ON VAC. AT SURFACE, ALL SHOTS FIRED. RIH WITH GUN #2 (12' SWS 2" PJ LOADED 6 SPF). TIE-IN TO FLAG AND PERF 9618' TO 9630'. POOH. ALL SHOTS FIRED. OPEN LIFT GAS. WELL LEFT ON PRODUCTION. *** JOB COMPLETE *** FLUIDS PUMPED BBLS 447 DEAD CRUDE 20 DIESEL/ZYL @ 50/50 175 2% KCL WATER 642 TOTAL ADD PERFS 08/03/2001 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2" POWERJET, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 9618' - 9650' Page I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other CTU - Post Work 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1446' SNL, 921' WEL, Sec 35, T11N, R13E, UM At top of productive interval 1082' SNL, 1555' EWL, Sec 36, T11N, R13E, UM At effective depth N/A At total depth 1310' SNL, 2040' EWL, Sec 36, T11N, R13E, UM Type of well: IX] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 82.55 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A-09A 9. Permit Number / Approval No. 200-174 10. APl Number 50-029-20552-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9925 feet true vertical BKB 8903 feet Effective depth: measured 9862 feet true vertical BKB 8889 feet · Casing Length Structural Conductor 110' Surface 2681' Intermediate 9181' Production 578' Uner 1440' Plugs (measured) Junk (measured) Size Cemented 20"X30" 72 cu ft 13-3/8" 3906 cu ft Actric Set II 9-5/8" 1270 cu ft Class 'G'; 130 cu ft Actric I 7" 403 cu ft Class 'G' 2-7/8X3-3/16" 135 cu ft Class 'G' MD TVD BKB 135' 135' 2695' 2695' 9145' 8538' 8658'-9236' 8080'-8623' 8570'-9925' 7999'-8903' Perforation depth: measured 9662' - 9728' true vertical 8847' - 8861' Tubing (size, grade, and measured depth).. 4-1/2" 13Cr to 8671' Packers and SSSV (type and measured depth) , RECE/VED 9-5/8" BKR S-3 PKR @ 8612'; SSSV @ 2015' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Pdor to well operation: Subsequent to operation: Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended [] Daily Report of Well Operations 17. I hereby c~t the~3re!~ing is truce an, d ~correct to the best of my knowledge Signe~"~~ __~'.,~.~ / I~l(ohael-W'~i[~YeY~/ [/'~ Title Technical Assistant - v - v - Prepared By Name/Number: Service Date .'~~f74~ DeWayne Schnorr 564-51 :orm 10-404 Rev. 06/15/88 ORIGINAL Submit In Duplicat~ A-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/30/2001 CTD-POST WORK: SET GENERIC GLV DESIGN SUMMARY SET CATCHER SUB @ 4171' SLM AND PULL STA # 5 DUMMY GLV @ 3977' SLM PULL STA # 5 DGLV AND SET RK LATCH W/DOME VALVE ( 1/4 PORT--1500 TRO ) @ 3979' SLM AND SET RK LATCH W/S/O ( 5/16 PORT ) IN STA # 6 @ 2976' SLM. PULLED CATCHER SUB. LEFT WELL SHUT IN PAD OPERATOR TO POP Fluids Pumped BBLS.22 IDescriPti°n TOTAL DIESEL 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 March 14, 2001 MWD Formation Evaluation Logs · A-09A, AK-MW-00344 A-09A: 2" x 5" MD Gamma Ray Logs · 50-029-20552-01 2" x 5" TVD Gamma Ray Logs · 50-029-20552-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY TRANSMITTAL LETYER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 RECEIVED Date~anr~ a g Alaska Oil & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. Petro-teclmical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed!~ OF WELL LOG TRANSMITTAL To: RE: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7a' Avenue, Suite 100 Anchorage, Alaska MWD Formation Evaluation Logs A-09A, March 02, 2001 AK-MW-00344 1 LDWG formatted Disc with verification listing. API#: 50-029-20552-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED ,"001 Nas~ 0ii & Gas Oons. Commission Anchorage 2/23/01 Scblmberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1021 Company: Field: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Color Well Job # Log Description Date Blueline Sepia Prints CD A-09A 21030 MCNL 011101 1 / 1 / 1" D.S. 4-07 21056 CNTG 012501 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 _. Anchora.se Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Al-tN: Sherrie Receiv~~~O./"~. ~ ! 27-Feb-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well A-09A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,100.00' MD 9,232.00' MD 9,920.00' MD · (if applicable Please call me at 273-3545 if you. have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Kt STATE OF ALASKA ~".. ALAS . .~IL AND GAS CONSERVATION COM .,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-174 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20552-01 4. Location of well at surface .................... ~~ 9. Unit or Lease Name 1446' SNL, 921' WEL, SEC. 35, T11N, R13E, UM ~ At top of productive interval ~.- .. I ¥~Ii Prudhoe Bay Unit 1082' SNL, 1555' EWL, SEC. 36, T11N, R13E, UM ._1' .i ~....'~".~. At total depth ~'~f !i~i.~.ii,.__.:. ~.i;...~2.~..~~i 10. WellNumber ~rt 1310'SNL, 2040'W,E.L, SEC. 36, T11N, R13E, UM i ...... ..: · A-09A 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 82.55' ADL 028286 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. ND. of Completions 1/6/2001 1/11/2001 1/13/2001 N/A MSLI One .17. Total Depth (MD+TVD) 1 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 9925 8903 ETI 9862 8889 FTI [] Yes [] NoI (Nipple) 2015' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, ROP, RES, Memory CNL ,,, .23. CASING, LINER AND CEMENTII~G RECORD ........ CASING ' . . SETTING DEPTH HOLE .... SIZE WT. PER FT. GRADE TOP BOTTOM SiZE CEMENTING RECORD AMOUNT PUl ~ rO 20" X 30" Insulated Conductor Surface 110' 36" 8 cu yds concrete 13-3/8" 72# L-80 Surface 2681' 17-1/2" 3906 cuft Arcticset II 9-5/8" 47# L-80 Surface 9181' 12-1/4" 1270 cuft Class 'G', 130 cu ft AS I 7" 29# L-80 8658' 9236' 8-1/2" 403 cuff Class 'G' 2-7/8. x 3-3/16' 6.16# / 6.2# L-80 8570' 9925' 3-3/4" 135 CU ft Class 'G' 24. Perforations. open to. Production (MD+.TVD of Top and 25. TUBING RECORD ~ottom and interval, size and number~ SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr 8671' 8612' MD TVD MD TVD 9662' - 9728' 8847' - 8861' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 25 Bbls of MeOH '.' 27. ' .... PRODUCTION TEST ..... Date First Production Method (~f Operation (Flowing, gas lift, etc.) ...... February 11, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing ~asing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (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. RECEIVED FEB 3 7_001 · Alaska Oil & Gas Cons. Commission Form 10-407 Rev. 07-01-80 Ancn~rua~it In Duplicate 29. 30. Geologic Markers 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. Sag River 9224' 8613' Shublik A 9257' 8645' Shublik B 9292' 8676' Shublik C 9315' 8695' Sadlerochit / Zone 4B 9350' 8723' RECE""' FEB Alaska Oil & Gas Cons. Commissior} Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Sun/eys (submitted by Vendor) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble..~j~~~~.. Title TechnicalAssistant Date A-09A 200-174 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. ITEM 16 AN[~ 24.' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage 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 (' (' RECEIVED BP AMOCO FEB ~, 3 ~.l~a~le 1 of 5 Operations Summary Report Alaska 0il & Gas Cons. Commission Anchorage Legal Well Name: A-09 Common Well Name: A-09A Spud Date: Event Name: REENTER+COMPLETE Start: 1/5/2001 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 1/5/2001 01:00 - 15:00 14.00 RIGU PRE On location at A Pad. Raise derrick, windwalls. Remove DS TOT BOP's for inspection. Install replacements. Move DS/N #1 over tree. 15:00 - 18:00 3.00 BOPSUF DECOMP ND tree cap. NU BOPE. Berm crew RU berm and set green tank. Spot gen #3, heaters. Pull injector out of box. 18:00 - 21:00 3.00 RIGU PRE ACCEPT RIG for operation at 1800 hrs on 01/05/2001. Install gooseneck, stab CT. Fill pits w/SW. 21:00 - 23:30 2.50 BOPSUF DECOMP RU & test BOPE to 300/3500 psi. Witness of test waived by Chuck Scheve - AOGCC. Could not get test against swab valve. Call grease crew - still no test. Try against master and wing after greasing - OK. 23:30- 00:00 0.50 BOPSUF DECOMP Continue with BOP test. 1/6/2001 00:00 - 00:45 0.75 BOPSUF DECOMP Continue testing BOPE to 300/3500 psi. Got 2 tests and then tree valves started leaking by again. 00:45 - 03:00 2.25 BOPSUF:TEST DECOMP Heat up xmas tree to improve seal effectiveness of valves. No success. Call grease crew and grease tree again. Install gooseneck. Stab CT 03:00 - 07:00 4.00 BOPSUF DECOMP Continue with BOP test. No failures. DSM pull TWC 07:00 - 09:00 2.00 CLEAN DECOMP Install DS CTC. PT @ 35k. Fill CT w/SW and pump dart. Dart hit at 59.2 bbls. PT CTC and inner reel valve @ 3500 psi 09:00 - 10:00 1.00 CLEAN DECOMP Chk well for press, none. IA 640. MU milling BHA 10:00 - 11:45 1.75 CLEAN DECOMP RIH BHA #1 (3.80" window mill, 3.80" string reamer) 11:45 - 12:10 0.42 CLEAN DECOMP Tag something at rain rate, fell thru at 9223' CTD. Corr to 9235'. PUH 35K. Start motor 2.6 @ 2400. Motor work at 9238'. Drill what acts like formation at 9242' 12:10 - 12:40 0.50 CLEAN DECOMP Drill formation from 9242-52' 12:40- 13:25 0.75 CLEAN DECOMP Ream window clean ' 13:25 - 14:00 0.58 CLEAN DECOMP PUH to 8500'. Install new depth encoder and check reentry thru packer lwhile wo broken mud truck to offioad to another. 10k overpull at 8690' ~ mill depth (BHA length 86.7') 14:00 - 14:30 0.50 CLEAN DECOMP RIH and displace to used FIo Pro mud 14:30 - 15:00 0.50 CLEAN DECOMP Ream window area, clean 15:00 - 16:45 1.75 CLEAN DECOMP' POOH. Had overpull at 8690'. Chk injector chains at 8500' 16:45- 17:15 0.50 CLEAN DECOMP LD milling BHA 17:15 - 18:00 0.75 DRILL PROD1 'MU drilling BHA 18:00 - 19:45 1.75 DRILL PROD1 F~IH w/BHA #2 (2.3 deg motor). Tag up on XO from bottom of packer at 8645' CTM. Would not go inside. PU & get orientation - 106R. 19:45 - 20:00 0.25 DRILL PROD1 Orient 2 clicks at a time and attempt to work into top of XO. Went thru OK at 63L orientation - 10 clicks. 20:00 - 21:00 1.00 DRILL PROD1 RIH to 9090'. Log down for tie in to GR on orig sonic log. Correction (+4'). ;21:00 - 21:15 0.25 DRILL ; PROD1 RIH. Orient & go thru window - OK. Tag bottom at 9252'. 21:15 - 22:15 1.00 DRILL PROD1 Orient for 30R and drill ahead to 9268'. ROP 15-25 fph. 22:15 - 22:30 0.25 DRILL PROD1 Orient around. 22:30 - 00:00 1.50 DRILL PROD1 Drill ahead probably in top Shublik. ROP slow initially but improved below 9275' MD. 9300': 2.5/2.5 bpm. 3750 psi. 07L. 40 fph. MWD impeller speed Iow - trash in tool? Getting surveys most of the. time so will keep drilling. 1/7/2001 00:00 - 05:45 5.75 DRILL PROD1 Continue drilling ahead in Shublik - slow. 9375': 2.5/2.5 bpm. 3750 psi. 20 fph. 07L ROP incr at 9390' to 60-70 fph. .Drill to 9444'. 05:45 - 06:15 0.50 DRILL PROD1 Wiper trip to window and try to get some clicks. Hole condition looks good. Printed: 1/26/'2001 4:34:59PM ( H CEiV D BP AMOCO Page 2 of 5 Operations Summary Report FEB g :3 Z001 ...... & Gas .... Legal Well Name: A-09 Anchorage Common Well Name: A-09A Spud Date: Event Name: REENTER+COMPLETE Start: 1/5/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Group: COIL Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Sub Phase Description of Operations Code 1/7/2001 06:15 - 07:30 1.25 DRILL PROD1 Decided we have enough build to POH for lower bend motor. Having difficulty holding orientation with this motor. POH. 07:30 - 09:50 2.33 DRILL ;PROD1 Change bit, add Sperry resistivity tool. Upload (1 hr) 09:50 - 11:40 1.83 DRILL I PROD1 RIH w/BHA #3. Plugged 'out' MM twice with hair balls from milling and workover operations. Bypass until it cleans up. Phz I (-26F/-76CF) 11:40 - 11:55 0.25 DRILL PROD1 Tag at 9232' CTD. ChkTF @ 151L. Orient to right 11:55 - 12:25 0.50 DRILL PROD1 RIH thru window, clean at 1R. Log tie-in from 9250', add 1.5'. 12:25 - 12:45 0.33 DRILL PROD1 MAD pass to corr TD @ 9453' 2.6/3450/98L 12:45 - 13:30 0.75 DRILL PROD1 Orient to right. Orientor didn't get one click. POOH thru window. Get 1/3 in liner. RIH 13:30 - 14:35 1.08 DRILL PROD1 Drilling 2.5/3400/54R ~ 9455'. Can't get any clicks. Drill to 9497'. Phz 2 (-25F/-86CF) i 14:35 - 15:10 0.58 DRILL PROD1 Wiper to window to get clicks '15:10 - 16:45 1.58 DRILL PROD1 Drill 2.5/3440/66R (wi occasional trys to get a click) to 9546' 16:45 - 18:30 1.75 DRILL ORNT PROD1 POOH to change orientor-22F, 37-50 mph. Try again in liner and 0/2 Start zero rate downtime at 1645 hrs. 18:30 - 18:45 0.25 DRILL ORNT PROD1 Stop at 300' for Phase 2 convoy changeout. Cont POH. 18:45 - 19:15 0.50 DRILL ORNT PROD1 OOH. Stand back injector. CO orienter and equaliser & MU same. 19:15 - 19:30 0.25 DRILL PROD1 Safety meeting and risk assessment for continuing operations in phase 2 weather. Will continue as long as it remains phz 2 but re-evaluate if phz 3 is called. 19:30 - 19:45 0.25 DRILL ORNT PROD1 MU coil conn and injector. 19:45 - 21:15 1.50 DRILL ORNT PROD1 RIH with BHA #4. Phz 3 announced at 2100 hrs. After evaluating risks and current inventory of mud, water, fuel will drill 'ahead as long as wellbore conditions remain stable. At present, no requirement for outside support and human/machine interface on rig is Iow, which mitigates risk of injury to personnel. 21:15 - 21:30 0.25 DRILL ORNT PROD1 Tag up on XO/TP sitting on top of liner at 8645' CTM. Orient to highside and went in on third attempt. 21:30 - 22:15 0.75 DRILL ORNT PROD1 Stop at 9256'. Start logging down for GR tie in. Corr'n = 0'. 22:15 - 22:30 0.25 DRILL ORNT PROD1 'RIH to bottom. Orient for RH turn. Freespin -- 3250 psi ~ 2.3 bpm. End rig zero rate downtime at 2230 hrs. 22:30 - 23:30 1.00 DRILL PROD1 Drill ahead in Z4 to 9588'. ROP 60-70 fph. 23:30 - 23:45 0.25 DRILL PROD1 Orient all the way around. 23:45 - 00:00 0.25 DRILL PROD1 Drill ahead 9604': 2.3~2.3 bpm. 3350 psi. 37R. 50-60 fph. 1/812001 00:00 - 01:00 1.00 DRILL PROD1 Phase 3 weather conditions still in effect. Cont drilling ahead in Z4 to 9648'. 01:00 - 01:15 0.25 DRILL PROD1 Orient around for 80L. 01:15 - 02:30 1.25 DRILL PROD1 Drill ahead to 9715'. 9656': 2.4~2.4 bpm. 3600 psi. 95L. 60-70 fph. 9700': 2.2~2.2 bpm. 3225 psi. 69L. 60-80 fph. 02:30 - 02:45 0.25 DRILL PROD1 Orient around part way. 02:45 - 03:30 0.75 DRILL PROD1 Wiper trip to window and finish orienting for 100L. 03:30 - 04:30 1.00 DRILL PROD1 Drill ahead to 9758'. Getting more stalls and weight stack out. 9750': 2.4/2.4 bpm. 3675 psi. 98L. 50-70 fph. 04:30 - 04:45 0.25 DRILL PROD1 Orient around for 110L. 04:45 - 06:00 1.25 DRILL PROD1 Drill ahead to 9774'. 06:00 - 06:30 0.50 DRILL PROD1 Lost #2 generator. POH to window to troubleshoot problem. 06:30 - 12:00 5.50 DRILL WTHR PROD1 Gen set may have got snow in it from blow and shorted out. Will have to wait for crew change for electrician to give better evaluation of problem with generator. Circ inside window at min rate while wo crew Printed: 1/26/2001 4:34:59 PM (" ti"RECFIVFD BP AMOCO FEB [ 3 ~_0~ge 3 of 5 Operations Summa Report Alaska Oil & Gas Cons. Commission Legal Well Name: A-09 Common Well Name: A-09A Spud Date: Event Name: REENTER+COMPLETE Start: 1/5/2001 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 1/8/2001 06:30- 12:00 5.50 DRILL WTHR PROD1 change in phz 3. 12:00 - 23:00 11.00 DRILL WTHR PROD1 XO crews. Safety mtg. Determine gen #2 needs to be replaced. Circ at window and wait for phz improvement to get backup generator from Price Pad. Phz 2 weather on Spine at 2000 hrs. Pads & access roads still Phz 3. Crew change at 2230 hrs. 23:00 - 23:30 0.50 DRILL PROD1 Hold PJSM and hazard analysis for preparation of damaged generator for swap out when weather improves further. Back-up unit is at Price Pad. Discuss proper energy isolation and working to avoid hazards - heavy loads, pinchpoints, caught between. 23:30 - 00:00 0.50 DRILL WTHR PROD1 Cont WOW for Phz 2 to be declared on pads and access roads. Circ at rain rate to prevent freeze-up. Expect to get fuel and water before morning. 1/9/2001 00:00 - 05:30 5.50 DRILL VVTHR PROD1 Cont WOW to drop to Phz 2 on pads and access roads to begin replacement of damaged generator. Move coil 10' up hole. Cont circ at rain rate to prevent freeze-up. Receive fuel/water 05:30 - 12:00 6.50 DRILL POWR PROD1 Phz 2 pads & access roads. Phz 1 spine at 0530 hrs. Start of zero rate downtime for repairs to #2 generator unit. 0630 crew change by convoy without heavy equipment escort. Find backup gen, dig out. Get stinger from TS 12:00 - 19:00 7.00 DRILL POWR PROD1 Gen on location. Remove used one and pull drive shaft and coupling 19:00 - 19:30 0.50 DRILL PROD1 Hold safety meeting to identify and discuss hazards associated with installing new generator. Heavy loads, pinch points, cramped work area, congestion. 19:30 - 00:00 4.50 DRILL POWR PROD1 Pick generator from second level and set in motor room with loader using long fork. Try to install and couple up to prime mover. Coupling butts up fully against diesel flywheel but gen housing will not mate fully with motor housing as if coupling not fully inserted onto shaft. 1/10/2001 00:00 - 08:00 8.00 DRILL POWR PROD1 Wait on NC Cat mechanic to evaluate problems with install of replacement generator. 08:00 - 12:00 4.00 DRILL POWR PROD1 Baker Machinist on location to measure and sweat-on coupling to crankshaft. Circulate at 0.3 BPM, pull bit up to 9120 ft. 12:00 - 15:00 3.00 DRILL POWR PROD1 Make up Generator coupling and engine crankshaft' OK. 15:00 - 18:00 3.00 DRILL POWR PROD1 Test generator #2, no voltage. Regulator board appears bad. 18:00 - 19:45 1.75 DRILL POWR PROD1 Change regulator board. Got voltage but now cannot regulate voltage down to correct level. 19:45 - 22:45 3.00 DRILL POWR PROD1 Continue troubleshooting and order another component from Nordic 3. Replace damaged part in SCR system. 22:45 - 23:15 0.50 DRILL POWR PROD1 Break circ. RIH & chk orientation - OK. Go thru window. RIH circ to bottom. Tag bottom. Rig off zero rate downtime at 2315 hrs. 23:15 - 00:00 0.75 DRILL PROD1 POH to window for tie in. Hole condition looks good. Log down for tie in. Corr'n (+2'). 1/11/2001 00:00 - 00:15 0.25 DRILL PROD1 RIH after tie in. 00:15 - 00:45 0.50 DRILL PROD1 Orient to 110L 00:45 - 02:45 2.00 DRILL PROD1 Drill from 9775'. 32K up, 16k# dn wt. 3600 psi@2.4 bpm. 150 Dpsi. Weight transfer deteriorating. Order out 300 bbls replacement mud. 02:45 - 03:00 0.25 DRILL PROD1 Orient around to 92R. 03:00 - 04:00 1.00 DRILL PROD1 Drill to 9895'. Stacking weight - new mud on the way. Printed: 1/26/2001 4:34:59 PM · (' ,(, .... RECEIVED BP AMOCO FEB 2 3 Z001 Page 4 of 5 Operations Summary Report Alaska Oil & Gas Cons. Commission Anchorage Legal Well Name: A-09 Common Well Name: A-09A Spud Date: Event Name: REENTER+COMPLETE Start: 1/5/2001 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 1/11/2001 04:00 - 04:45 0.75 DRILL PROD1 Wiper trip up to window. Hole smooth. 04:45 - 05:30 0.75 DRILL PROD1 Drilling ahead. TF:92R, Geologist called TD at 9,920 ft. 05:30 - 07:10 1.67 DRILL PROD1 Wiper trip to window, log tie-in. Added 3 ft to CTD. RIH. Hole clean. 07:10 - 08:45 1.58 DRILL PROD1 Tag TD at 9,922 f. POOH. 08:45 - 10:30 1.75 DRILL PROD1 Lay out drilling BHA at 0900 hrs. Download Sperry Resistivity tool. 10:30 - 10:45 0.25 EVAL PROD1 Safety Meeting. 10:45 - 12:15 1.50 EVAL PROD1 M/U SWS Memory CNI_/GR inside open hole carrier. M/U XO and 1 jt 2.38" tbg. M/U DS BHA. 12:15 - 13:45 1.50 EVAL PROD1 RIH with Memory logging BHA to 9000 f. 13:45 - 14:45 1.00 EVAL PROD1 Log down at 30 FPM with CNIJGR. Tag TD at 9,896' CTD. Log up at 30 FPM to 9000 ft. Circ at 0.8 BPM at 1800 psi. 14:45 - 17:20 2.58 EV^L PROD1 POOH. Flagged CT at 7100 ft. EOP. Cont. POOH. 17:20 - 18:00 0.67 EVAL PROD1 Lay out SWS CNL/GR. Download memory data. 18:00 - 19:00 1.00 CASE PROD1 Prep to run liner. 19:00 - 19:15 0.25 CASE PROD1 Safety Meeting. 19:15 - 21:30 2.25 CASE PROD1 RIH with 20 jts 2 7/8" 6.16~STL liner. 21:30 - 00:00 2.50 CASE PROD1 Switch elevator inserts and run 3 3/16" TCII liner. MU deployment tools. 1/12/2001 00:00- 01:00 1.00 CASE PROD1 MU injector. RIH with liner. 01:00 - 02:45 1.75 CASE REEL PROD1 Inspect and repair level wind. 02:45 - 04:15 1.50 CASE PROD1 Cont RIH with liner. Correct depth at flag (-26'). Wt chk at 9200'. 34K up, 19K dn. Tag bottom at 9895' and correct to CNL TD of 9925'. Correction (+30'). Final corrected TD for well is 9,925 ft BKB. 04:15 - 05:15 1.00 CASE PROD1 Load 5/8" aluminium ball in ball drop and pump to CT. SD and verify ball left - OK. Displace ball at 2.0 bpm/2900 psi to 40 bbl away. Slow to 0.4 bpm/1700 psi to 50 bbl away 0.3 bpm/1600 psi to land ball on seat at 52.2 bbl away. Pressure up to 3900 psi and shear release off deployment sleeve. PU at 28 klbs - released off liner OK. 05:15 - 07:45 2.50 CEMT PROD1 ~ Displace well to 2% KCI at 2.8 bpm/3200 psi. Full returns. 07:45 - 08:00 0.25 CEMT PROD1 'Safety Meeting, review cementing procedure. 08:00 - 08:15 0.25 CEMT PROD1 Mix cement. Cement at 15.8 ppg wt at 08:15 hrs. 08:15 - 08:25 0.17 CEMT PROD1 Stg 3 bbl water. Press test cement lines to 3000 psi. OK. 08:25 - 08:50 0.42 CEMT PROD1 Stg 24.0 BBL, 15.8 PPG, G cement with latex, 1.7 BPM, 1500 psi. Stop pump, clean cement line, insert dart. 08:50 - 09:15 0.42 CEMT PROD1 Displace dartJcmt with 2 % KCL water using rig pump. Pump 3.2 BPM, 2600 psi. Full returns. 30 bbl displ, 3.3 bpm, 2600 psi, full returns. 44 bbl displ, cement at liner shoe, 3.3 bpm, 2400 psi, full returns, 56 bbl displ, 3.2 bpm, 3000 psi, slow pump to 1.0 bpm to see dart latch w/liner wiper plug Dart on seat at 58.7 bbls. sheared at 2600 psi. displace at 3.1 bpm. 3100 psi 65 bbl displ, 3.1 bpm, 3200 psi, slow to 1 bpm. Liner wiper landed at 67.6 bbls, [0.1 bbl late]. Bump plug with 1900 psi, )ress held. 09:15 - 09:30 0.25 CEMT PROD1 Sting out, circ at top of liner at 2.5 BPM. Full returns throughout job. Should have cement to top of liner at 8,570 ft BKB. 09:30 - 11:30 2.00 CEMT PROD1 POOH while chasing cement to surface with KCL water. Dispose of contaminated returns. 11:30 - 11:45 0.25 CEMT PROD1 Lay out Baker CTLRT. 11:45 - 12:45 1.00 CEMT PROD1 RI H with 46 jts, CSH workstring with 2.25" jet nozzle. M/U DS BHA and Printed: 1/26/2001 4:34:59PM RECEIVED F BP AMOCO 1~a~ 5 of 5 Operations Summary Report Alaska 0il & Gas Cons. Commission Anchorage Legal Well Name: A-09 Common Well Name: A-09A Spud Date: Event Name: REENTER+COMPLETE Start: 1/5/2001 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 1112/2001 .11:45 - 12:45 1.00 CEMT PROD1 injector head. BHA total length = 1438 ft. 12:45 - 13:00 0.25 CEMT PROD1 RIH with CT. Level wind jamming. Stop RIH at 3285 ft. Circ. at 0.5 bpm, 210 psi. 13:00 - 17:00 4.00 CEMT OTHR PROD1 Repair level wind. 17:00 - 18:15 1.25 CEMT PROD1 RIH with CT. Level wind working OK. No wt. loss at top of liner, RIH at 50 FPM, 1.7 BPM, 1620 psi. Jet liner clean to PBTD of 9,861 ft BKB. 18:15 - 18:45 0.50 CEMT PROD1 Lay in New FIoPro pen' pill, 12 BBLS. [150,000 cp, 2% LT.] inside 2.88" liner. 18:45 - 20:15 1.50~ CEMT COMP Circ out of hole. 20:15 - 21:45 1.50' CEMT COMP Off well. PJSM. Stand back 23 jts CSH. DS lab confirms UC^ test at 2000 psi after 9.5 hrs. 21:45 - 22:45 1.00 CASE COMP Pressure test liner lap to 2100 psi for 30 minutes. 22:45 - 23:15 0.50 PERF COMP Hold PJSM regarding pen' ops & procedures. 23:15 - 23:59 0.73 PERF COMP MU SWS pen' guns, 2", P J2006 HMX charge, 6.5 gm guns, 60 deg, 4 spf. 1/13/2001 00:00 - 00:30 0.50 PERF COMP Continue to MU pen' BHA. 00:30 - 02:00 1.50 PERF COMP RIH with pen' guns. Circ at min rate. 02:00 - 02:15 0.25 PERF COMP Tag PBTD at 9861. (corrected from 9845 actual tag) 32K# up, 21k# dn wt. 02:15 - 02:30 0.25 PERF COMP Pump 10 bbls 150K flopro. Launch 0.625 ball 02:30 - 03:15 0.75 PERF COMP Ball on seat with 58 bbls pumped (60.5 calced). Pressure to 3000 psi. Firing head sheared. 03:15 - 04:30 1.25 PERF COMP POOH. Circ across top of well. Lost maybe 1 bbl mud/fluid. 04:30 - 05:00 0.50 PERF COMP Monitor hole for 25 min. Fluid level stable. 05:00 - 05:15 0.25 PERF COMP PU off well. Break off MHA. 05:15 - 06:30 1.25 PERF COMP LD CSH work string. 06:30 - 06:45 0.25 PERF COMP Safety Meeting, review hazards for handling fired pen' guns. 06:45 - 07:30 0.75 PERF COMP Lay out fired 2" SWS pen' guns,, all shots fired. 07:30 - 09:00 1.50 RIGD COMP RIH and freeze protect 4.5" tubing with MEOH to 2000 ft. Circ. 100% MEOH from 100 ft up. Close swab valve. 09:00 - 11:00 2.00 RIGD COMP Displace CT with N2, pump 1500 CFM for 10 min. 920 psi, 2.5 bpm out rate. Bleed down CT press. 11:00 - 13:00 2.00 RIGD COMP Pull CT out of injector head, remove guide arch, set injector head in pipe bay. 13:00 - 14:00 1.00 RIGD COMP Install tree cap. Press test tree cap, OK. Well secured. Master and swab closed. Clean rig pits. RELEASED RIG AT 14:00 HRS, 01/13/01. TOTAL TIME ON WELL-- 7 DAYS, 20 HRS. Derrick Down Rig move to J-24^. Presently waiting on wind to lower wind walls. Printed: 1126/2001 4:34:59 PM North Slope Alaska Alaska Drilling & Wells PBU_WOA A Pad, Slot A-09 A-O9A Surveyed: ~ ~ January, 2001 SURVEY REPORT 27 February, 200~ Your Ref: AP1 500292055201 - Surface Coordinates: 59490Of. fl N, 654453.65 E (70° 16' 03.~205" N, Kelly Bushing: 82.55ft above Mean Sea Level f48° 45' 03.6370" W) D~RIL Li I~I-G SE RVI !: E 5~ Survey Ref: svy'i07'27 A Halliburton Company North Slope Alaska Measured Depth (ft) Incl. Azim. Sperry-Sun Drilling Services Survey Report for A.O9A Your Ref: AP! $00292055201 Surveyed: Il January, Sub-Sea Vertical . Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 9100.00 18.949 87.908 8413.08 8495.63 9200.00 17.870 89.300 8507.96 8590.51 9232.00 17.480 88.880 '8538.45 8621.00 9263.40 23.380 92.960 8567.87 8650.42 9294.40 30.500 93.530 8595.48 8678.03 9324.80 36.390 104.430 8620.86 8703.41 9357.40 43.330 109.000 8645.88 8728.43 9392.60 52.210 109.350 8669.51 8752.06 9430.00 61.790 108.470 8689.86 8772.41 9460.87 66.700 106.910 8703.27 8785.82 9490.27 68.810 109.560 8714.40 8796.95 9521.87 71.540 113.260 8725.12 8807.67 9551.07 72.690 115.550 8734.09 8816.64 9580.07 72.470 119.830 8742.77 8825.32 9610.47 74.450 123.650 8751.43 8833.98 9640.67 76.040 125.770 8759.12 8841.67 9669.27 76.480 125.590 8765.91 8848.46 9698.27 78.150 122.420 8772.28 8854.83 9729.47 79.160 120.840 8778.42 8860.97 9763.67 78.590 116.780 8785.02 8867.57 9800.27 77.000 114.840 8792.76 8875.31 9834.27 76.650 111.490 8800.51 8883.06 9868.89 77.110 108.760 8808.37 8890.92 9894.87 77.270 111.140 8814.13 8896.68 9920.00 77.270 111.140 8819.67 8902.22 PBU WOA A Pad Global Coordinates Northings Eastings (ft) (ft) 371.68 N 2378.51 E 5949421.51 N 656824.04 E 372.46 N 2410.08 E 5949422.94 N 656855.58 E 372.61 N 2419.80 E 5949423.29 N 656865.29 E 372.38 N 2430.74 E 5949423.29 N 656876.24 E 371.58 N 2444.76 E 5949422.77 N 656890.27 E Dogleg Vertical Rate Section (o/toort) 1986.80 1.17 2014.96 1.28 2023.66 19.32 2033.64 22.98 2046.63 Comment Tie On Point MWD Magnetic KOP Interpolated AZ 368.85 N 2461.22 E 5949420.38 N 656906.78 E 362.79 N 2481.19 E 5949414.73 N 656926.87 E 354.23 N 2505.78 E 5949406.68 N 656951.63 E 344.09 N 2535.42 E 5949397.15 N 656981.48 E 335.65 N 2561.90 E 5949389.26 N 657008.13 E 327.14 N 2587.74 E 5949381.27 N 657034.14 E 316.28 N 2615.41E 5949370.99 N 657062.02 E 304.80 N 2640.71 E 5949360.03 N 657087.55 E 291.94 N 2665.21 E 5949347.68 N 657112.30 E 276.61N 2689.98 E 5949332.86 N 657137.39 E 27.61 2062.67 23.09 2083.30 25.24 2109.18 25.69 2140.30 16.54 2167.83 11.00 2194.82 14.00 2224.47 8.44 2252.25 14.10 2279.89 13.69 2308.85 259.98 N 2713.98 E 5949316.72 N 657161.73 E 243.78 N 2736.55 E 5949300.99 N 657184.62 E 227.96 N 2760.00 E 5949285.65 N 657208.39 E 211.92 N 2786.05 E 5949270.15 N 657234.76 E 195.75 N 2815.44 E 5949254.59 N 657264.48 E 8.59 2337.68 1.66 2365.02 12.12 2393.00 5.93 2423.41 11.77 2456.90 180.18 N 2847.64 E 5949239.68 N 657297.00 E 167.16 N 2878.07 E 5949227.28 N 657327.69 E 155.56 N 2909.73 E 5949216.34 N 657359.58 E 146.91 N 2933.54 E 5949208.18 N- 657383.56 E 138.07 N 2956.40 E 5949199.81 N 657406.60 E 6.76 2492.67 9.65 2525.75 7.79 2559.31 8.95 2584.52 0.00 2608.96 Projected Survey 27 February, 2001, 9:36 Page 2 of 4 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for A-OgA Your Reft AP1 500292055201 Surveyed: fl January, 2001 North Slope Alaska Alaska Drilling & Wells PBU_WOA A Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True Nodh. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.735° (06-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 115.500° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9920.00ft., The Bottom Hole Displacement is 2959.63ft., in the Direction of 87.326" (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) Comment 9100.00 8495.63 371.68 N 2378.51 E Tie On Point 9232.00 8621.00 372.61 N 2419.80 E KOP 9263.40 8650.42 372.38 N 2430.74 E Interpolated AZ 9920.00 8902.22 138.07 N 2956.40 E Projected Survey 27 February, 2001. 9:36 Page 3 of 4 DrillQuest 2.00.06 'Sperry. Sun Drilling Services Survey Report for A-OgA Your Ref: AP1 500292055201 Surveyed: f f January, 200f North Slope Alaska Alaska Drilling & Wells PBU WOA A Pad Survey tool program for A.O9A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 9100.00 8495.63 9100.00 8495.63 9920.00 8902.22 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (A-09) MWD Magnetic (A-09A) 27 February, 200f - 9:36 Page 4 of 4 DriilQuest 2.00.06 ALASKA OIL AND GAS CONSERVATION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 JeffHupp CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 1996612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit A-09A BP Exploration (Alaska), Inc. Permit No: 200-174 Sur Loc: 1'446' SNL, 921' WEL, Sec. 35, T1 IN, R13E, UM Btmhole Loc. 3856' NSL, 3088' WEL, Sec. 36, T1 IN, R13E, UM Dear Mr. Hupp: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~':~ day of November, 2000 .lit/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA . ALASI~ ,)IL AND GAS CONSERVATION COry{' 3SION PERMIT TO DRILL 20 AAC 25.005 I a. Type of work B Drill [] Redrill 1 lb. Type of well Re-Entry [] Deepen [] Service [][] DevelopmentEXpl°rat°ry Gas [][] StratigraphiCsingle Zone Test [][] MultipleDeVel°pmentzone Oil I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 82.55' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028286 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1446' SNL, 921' WEL, SEC. 35, T11 N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1072' SNL, 1529' EWL, SEC. 36, T11N, R13E, UM A-09A Number 2S100302630-277 At total depth ~ ,~) 9. Approximate spud date 3856' NSL, 3088' WEL, SEC~ ,T1 1N, R13E, UM 11/15/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028285, 1422' MDI No Close Approach 2560 10133' MD / 8864' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9240' MD Maximum Hole Angle 77 ° Maximum surface 2500 psig, At total depth (TVD) 8800' / 3380 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casin(3 Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include sta,qe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 1484' 8649' 8072' 10133' 8864 ! 12 cu ft Class 'G' -,,,-- 77 2C, O UL. I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Total depth: measured 10i00 feet Plugs (measured) Cement cap at 9516'; Sand plug at~§~',:~!!::'? true vertical 9464 feet Effective depth: measured 9516 feet Junk (measured) Three wireline tool strings left in hole. true vertical 8894 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds conrete 110' 110' Surface 2653' 13-3/8" 3906 cu ft Arcticset II 2681' 2681' Intermediate 9128' 9-5/8" 1270 cu fi Class 'G', 130 cu fi AS I 9181' 8572' Production Liner 1440' 7" 403 cu fi Class 'G' 8658' - 10098' 8081' - 9462' true vertical Open: 8813' - 8827', 8840' - 8800' Sqzd: 8827' - 8834', 8008' - 8047' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Nurnbec Jeff Hupp, 564-5344 Prepared By Name/Number'. Terde Hubble, 564-4628 21.1 hereby certify that the f..or~geipjF'[~ tru~ and cor.,r,e~t to the best of my knowledge /~/, Signed Jeff Hupp ~/Zf""/~~ Title CT Drilling Engineer Date ~ ~/~ ~:3/I ~,.) .... ~.~:~..~ ....... II ....... ~...~. ~ .~ ,,~.,I.~ ..... ~,, . ~ ,,~ ...~,~ ~...~:;t I!~.,,~ ...... ~ ~ ~,...~ .~.; Permit Number APl Number Approyal Date See cover letter - 50-029-20552-01 I~/~ / O-t'3 for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes I~ No Hydrogen Sulfide Measures ~ Yes [] No Directional Survey Required [] Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~,,.3.5K psi for CTU Other: ORIGINAL SIGNED BY by order of Approved By D Taylor Seamount Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX A-09a Sidetrack Summaw of Operations: A-09 production has declined due to junk across the original perforations. The sidetrack, A-09a, will kick off in Shublik and target Zone 4 as a replacement for the original A-09 well. Phase 1- Set Whipstock and Downsqueeze cement. Planned for Oct 31, 2000. · E-Line will set the whipstock at approx. 9230' MD. · Service coil will downsqueeze approx. 20 bbls cement to shut off existing perfs. Phase 2: Mill window, drill and Complete sidetrack: Planned for November 15, 2000. Drilling coil will be used to mill the 3.80" window, drill and complete the directional hole as per attached plan. The sidetrack will be completed with a cemented liner. The window depth will be f/ 9240-50' md. Top of 2 7/8" to be approx. 8649' MD (8072' ss) with top of liner cement approx 200 ft above the window. Approx. 20 bbls cement will be used for this liner cement job. Mud Program: · Phase 1' Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. -- -- ~ i 1,1 · '-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 cemented liner will be run from TD to approx. 8649' MD (8072'ss)..' Top of liner cement will be at the top of the liner. Well Controli · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventor 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 · An MWD Gamma Ray log will be run over all of the open hole section. · A real time Resistivity or a Memory Induction Log will be run in open hole. Hazards Production from A-09 has been measured at less than 10 ppm H2S. Lost circulation risk is Iow. The well is a twin sidetrack to the original A-09 well. The highest reading for A-09 was 20 ppm on 10/11/98. The well has been shut in since then due to holes in the tubing. The highest recorded H2S level on A Pad was 200 ppm on 06/06/00 (Well A-43). Reservoir Pressure Res. press, is estimated to be 3380 psi at 8800ss. Max. surface pressure with gas (0.10 psi/ft) to surface is 2500 psi. A 09 TREE: 4" McEvoy . __ .EV = 82.55 WELLHEAD: McEvoy ~ GL. ELEV = 54.49 ACTUATOR: AXELSON X LANDING NIPPLE (HES)(3.813" ID) I 2015' L-80, BTRS I 2681' I ,~ ~ I~ 4.5" MMG (CAMCO GLM 1.5" ~'~ W / RK LATCH) NC) MD(BKB TVI').~.~ DFV I KOP:3300' MAX ANGLE:35 @ 5600' 6 2979 2896' 5 3982 3894' 1 /2 2.6 # / ft, 13 CR, TBG ! 4 5981 5656' 1 TUBING ID: 3.958" 3 6992 6503' CAPACITY: .O1522 BBL$/FT 2 7496 6940' I 8533 7881 · ~ HES X LANDING 3.813" ID X l'X 9-5~/8" BAKER S-3 PACKER 7" I (HES) ( 3.813 "ID)I8539 -" ""XN" NIPPLE I RRR.CI' LINER '~ ( HES ) (3.7 5'" ID) I 9-5/8", 47#/ft, I ~ 2" TBG TAIL [ 8=~71' l L-80, BTRS 9180' ~ (ELMD) I WARNING PERFORATION SUMMARY REF: LOG: BHCS 4-23-81 RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST BE Size SPF Interval Open/Sqz TURNED OFF BEFORE ANYWELL 3 3/8 4 9446 - 9454' SQZ'D WORK INVOLVING EXPLOSIVES. 3 3/8 4 9458 - 9478' OPEN/9-9-92 CONTACT PAD OPERATOR 3 3/8 4 9478 -9498' OPEN/9-9-92 3 3/8 4 9498 - 9518' OPEN/9-9-92 3 3/8 4 9530 - 9570' SQZ'D Caution FISH-THREE WL TOOL STRINGS @ PBTD, NOT RECOVERED DURING R__WO CMT CAP @ 9516' SAND PLUG @ 9535' I IBP & FISHING TOOL @ 9931' I PBTD 1 7', 29 #/ft, L-80, I lO.O98 I BTRS DATE REV. BY COMMENTS PRUDHOE BAY UNITWELL: 5/1/81 IN ITIAL COMPLETION A-09 (21-36-11-13) 8/03/00 L.M RWO -TBG & PKR CHANGE APl NO:50-029-20552 SEC 36: TN 11N:RGE 13F BP Exploration (Alaska) 4.5" MMG (CAMCO GLM 1.5" W / RK LATCH) NC) MD{BKB TVD~ 6 2979 2896' 5 3982 3894' 4 5981 5656' 3 6992 6503' 2 7496 6940' I 8533 7881 A-09a Proposed Completion TREE: 4" McEvoy WELLHEAD: McEvoy ACTUATOR: AXELSON 13-3/8', 72 #/ft, L-80, BTRS 12681' I IKOP:3300' MAX ANGLE:35 @ 5600' -4 1/2" 12.6 #/ft, 13 CR, TBG TUBING ID: 3.958' CAPACITY: .O1522 BBLS/FT KB. ELEV = 82.55 GL. ELEV = 54.49 X LANDING NIPPLE (HES)(3.813' ID) I 2015' I 4.5" MMG (CAMCO GLM 1.5" W / RK LATCH) NO MD(BKB TVDss DEV 6 2979 2896' 5 3982 3894' 4 5981 5656' 3 6992 6503' 2 7496 6940' 1 8533 7881 HES X LANDING 3.813" ID 8599' J TOPOF [ 8658' [ 7" LINER 9-5/8", 47#/ft, [ 9180' L-80, BTRS J Top whipstock to be set at approx. 9,230'. PERFORATION SUMMARY REF: LOG: BHCS 4-23-81 I Size ISPF I Interval 3 ~/81 4 I 9440' 9454' a ~81 4 I 9458' 9478' 3 3/8[ 4 [ 9478 '9498' 33/8J 4 [ 9498-9518' 33/8l 4 I 9530-9570' WARNING RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY WELL WORK INVOLVING EXPLOSIVES. CONTACT PAD OPERATOR Open/Sqz SQZ'D OPEN/9-9-92 OPEN/9-9-92 OPEN/9-9-92 SQZ'D PBTD 1 ln:n,~::, 7", 29 #/ft, L-80, BTRS [ 10.098 III 9-5~" BAKER S-3 PACKER [ 8612' (HES) ( 3.813 'ID) 8539' .... XN' NIPPLE I 8659' ( HES ) (3.725'" ID) 'TBGTAIL [ 8671' (ELMD)I 2 7/8" liner fully cemented in 3.75" open hole Cement to be downsqueezed past the whipstock Caution FISH-THREE WL TOOL STRINGS @ PBTD, NOT RECOVERED DURING RWO CMT CAP @ 9516' · SAND PLUG @ 9535' IBP & FISHING TOOL @ 9931' Vertical Section 0 8500 8550 86O0 865O A-09 Path Distance (Feet) 500 1,000 1,500 I I Angle @ K,O.= 17 deli MD:9240 -TSGP. -TSAD,~ ,ETZ3,8850~--- A-09a Case 102 Oct. 9, 2000 Tot Drld:893 ft 10133 TD rel M5 Marker Depths ~)rig Wellbore IKick Off I 8,546Jft 1VD 9,~01ft MD IDeprtr @KO 2,465 fl I MD KO Pt 9,240I MD New Hole 893I I Total MD 10,133I TVD 'I'D 8,ss41 DLS deg/! O0 Tool Face Length Curve 1 6 0 30 Curve 2 28 25 225 Curve 3 12 -90 260 Curve 4 12 90 379 894 Drawn: ######### 13:33 Plan Name: Case122 A-09 A-09a Case 102 Oct. 9, 2000 I 1,500 I I I 2,000 2,500 3,000 X distance from Sfc Loc 3,500 2,000 1,500 1,000 5OO 4,000 JWell Name A-09 J CLOSURE JDistance 3,112 ft Az 88 deg NEW HOLE E/W (X) N/S (Y) Kick Off 2,414 423 TD 3,111~ 88 State Plane 657,564 5,949,089 Surface Loc 654,454 5,949,001 DLS deg/100 Tool Face Length re. Curve ! 6 0 30 Curve 2 28 25 225 Curve 3 12 -90 260 Curve 4 12 90 379 894 Drawn: ######### 13:33 Plan Name: Case 122 ~,;. ..-~- ~'_ ...:. .. A-09a CT Drilling & Completion BOP 23/8" CT ~1 I I I I 10,000 psi Pack-Off Lubricator~ I Ill 0 · 12" 36" 7 1116" Annular Blind/Shear 71/16" 22.5" Pipe/Slip ~ 2 3/8" ' ~,0.~,.000~1.... __ , '~ Slips ~ ' ~ 2 7/8" 71/16" ~ ~ 2 3/8" Pipe SWAB OR MASTER VALVE STATE OF ALASKA ALASI'~i" )IL AND GAS CONSERVATION COl~i .SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1446' SNL, 921' WEL, SEC. 35, T11 N, R13E, UM At top of productive interval 1072' SNL, 1529' EWL, SEC. 36, T11N, R13E, UM At effective depth 1070' SNL, 1576' EWL, SEC. 36, T11N, R13E, UM At total depth 1065' SNL, 1705' EWL, SEC. 36, T11N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service [] Perforate [] Other Plug Back for Sidetrack 6. Datum Elevation (DF or KB) KBE = 82.55' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A-09 9. Permit Number 181-007 10. APl Number 50-029-20552-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical 10100 feet 9464 feet' 9516 feet 8894 feet Length ' 110' 2653' 9128' Size 20" x 30" 13-3/8" 9-5/8" Plugs (measured) Cement cap at 9516'; Sand plug at 9535, Junk (measured) Three wireline tool strings left in hole. Cemented MD 'I'VD 8 cu yds concrete 110' 110' 3906 cu ft Arcticset II 2681' 2681' 1270 cu ft Class 'G', 130 cuft AS I 9181' 8572' 403 cu ft Class 'G' 8658' - 10098' 8081' - 9462' Perforation'depth: measured Open: 9432' - 9446', 9458' - 9518' Sqzd: 9446' - 9454', 9530' - 9570' true vertical Open: 8813' - 8827', 8840' - 8896' Sqzd: 8827' - 8834', 8908' - 8947' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr to' 8671' Packers and SSSV (type and measured depth) 9-5/8" Baker 'S-3' packer at 8612'; 4-1/2" SSSV 'X' Nipple at 2015' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation November 2, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Jeff Hupp, 564-5344 [] Detailed Operations Program I15. Status of well classifications as: [] Oil [] Gas [] Suspended Service [] BOP Sketch Prepared By Name/Number: Terrie Hubble, 564.4628 17. I hereby certify that the Signed .Jeff Hupp .ng is true and correct to the best of my knowledge Title CT Drilling Engineer. Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test' Location clearance Mechanical Integrity Test Subsequent form required 10- order of the Commission Approval No. Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~:'-~'~.~//~>'-~-~ INIT CLASS ~:/-'/ /~'~//-- GEOL AREA ~ UNIT# ~ ON/OFF SHORE A._DMINISTRATION 1. Permit fee attached ....................... APPR DATE __ _ENGINEERIN6 2. Lease number appropriate ................... 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 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 ........... N 14. Conductor string provided ............ . ....... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & 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 . . .. ............. DATE 26. BOPE press rating appropriate; test to ~.-~O O psig. /~ N zl[~ ~oo 271 Choke manifold complies w/APl RP-53 (May 84) ........ N . 28. Work will occur without operation shutdown ........... N . 29. Is presence of H2S gas probable ................. y ~ _GEOLOGY . _DATE Y N N ~N (~)N ~N 30. Permit can be issued wlo hydrogen sulfide measures ..... y 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones .......... '."... r J~""Y N 33. Seabed condition survey (if.off-shore) ....... ' .... ~ Y N 34. Contact name/phone for weekly progress reports [expl.~ory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; ....... y APPR DATE (B) will not contaminate freshwater; or cause drillin~te .... . to surface: . ./- ' / · (C) will not impair mechanical integ~y oft, j;~e~well use~for 'djsp~al; Y N (D) will not damage producing forn)dtio~r impair re--from a Y N · pool.; and ' ~ ' (E) will not circumvent 20 AAC 2 .252 or 20 AAC 25.412. ENGINEERING: UICIA;fnular,, Y N COMMISSION: Comments/Instructions: O Z --I "1- c:Vnsoffide~wordian~diana~checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the roadability of the Well History file and to simplify finding information, information of this nature is accumulated' at the end of the file under APPEN. DlXl ., No 'special'effort has been made to chronologically organize this category of information. ' Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Mar 02 11:05:58 2001 Reel Header Service name ............. LISTPE Date ..................... 01/03/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/03/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MW-00344 B JAHN SEVCIK/MASKE A-09A 500292055201 BP EXPLORATION (ALASKA), INC. Sperry Sun 27-FEB-01 MWD RUN 2 AK-MW-00344 B JAHN SEVCIK/MASKE MWD RUN 3 AK-MW- 00344 B JAHN SEVCIK/MASKE 35 lin 13E 1446 921 82.55 DERRICK FLOOR: .00 GROUND LEVEL: 54.49 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9232.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. RESISTIVITY DATA IN THE INTERVAL 9217'MD, 8524'TVDSS TO 9418'MD, 8684'TVDSS WAS OBTAINED ON A MEASUREMENT AFTER DRILLING (MAD) PASS OBTAINED WHILE TRIPPING IN THE HOLE FOR MWD RUN 2. 3. MWD RUNS 2-3 ARE DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DIGITAL DATA oNLY IS DEPTH SHIFTED/CORRECTED TO THE PDC GR LOG (SCHLUMBERGER MCNL 01/11/01). LOG AND HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 5. MWD RUNS 1-3 REPRESENT WELL A-09A WITH API~: 50-029-20552-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9922'MD, 8820'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 9216 5 RPD 9216 5 RPM 9216 5 RPS 9216 5 RPX 9216 5 GR 9225 5 SROP 9242 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9225.5 9229 0 9232 9235 9245 9248 9249 9250 9255 9258 9259 9261 9263 9265 9269 9271 9281 9286 9293 9298 9307 9308 9308 9312 9319 9321 9323 9325 9327 9330 9332 9338 9347 9355 9364 9365 9367 9370 9377 GR 9226.5 9230.0 9232.0 9235.0 9245 5 9248 0 9250 0 9251 5 9256 0 9259 5 9261 0 9263 0 9265 0 9266 5 9271 5 9273 0 9285 0 9289 5 9297 0 9303 0 9312 0 9313 5 9314 5 9319 5 9327 0 9329 0 9331 5 9333 5 9335 0 933,8 5 9340 0 9346 0 9355 5 9363 5 9372 0 9373 0 9374 5 9377 5 9385 5 STOP DEPTH 9878 0 9878 0 9878 0 9878 0 9878 0 9867 0 9913 0 EQUIVALENT UNSHIFTED DEPTH 9384 9402 9406 9414 9452 9456 9464 9484 9497 9533 9555 9561 9576 9595 9609 9621 9628 9641 9658 9661 9668 9701 9739 9757 9774 9813 9816 9828 9840 9843 9847 9862 9913 $ 0 0 0 5 0 5 5 0 5 5 5 5 5 5 0 5 0 5 5 0 0 5 0 5 5 5 0 5 0 5 0 .5 .0 MERGED DATA SOURCE. PBU TOOL CODE MWD MWD MWD $ REMARKS: 9392 0 9410 0 9413 5 9421 5 9458 5 9464 0 9473 5 9492.0 9505.5 9542 0 9563 5 9569 5 9586 0 9604 0 9618 5 9630 5 9636 5 9652 0 9667 0 9669 5 9676 0 9709 5 9747.0 9765.5 9783.0 9822 0 9824 5 9836 0 9848 5 9852 0 9855 5 9871 5 9922 0 BIT RUN NO MERGE TOP MERGE BASE 1 9217.5 9453.0 2 9453.0 9546.0 3 9546.0 9922.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size DEPT FT 4 ROP MWD FT/H 4 GR MWD API 4 RPX MWD OHMM 4 RPS MWD OHMM 4 RPM MWD OHMM 4 RPD MWD OHMM 4 FET MWD HOUR 4 Nsam Rep Code Offset Channel 1 68 0 1 1 68 4 2 1 68 8 3 1 68 12 4 1 68 16 5 1 68 20 6 1 68 24 7 1 68 28 8 Name Service Unit Min DEPT FT 9216.5 ROP MWD FT/H 0.74 GR MWD API 19.93 RPX MWD OHMM 0.18 RPS MWD OHMM 0.11 RPM MWD OHMM 0.1 RPD MWD OHMM 0.07 FET MWD HOUR 0.55 Max Mean Nsam 9913 9564.75 1394 1996.67 78.803 1343 734.6 59.4646 1284 1933.32 29.1698 1324 1893.82 32.5985 1324 2000 38.1078 1324 2000 43.057 1324 68.79 8.33228 1324 First Reading 9216.5 9242 9225.5 9216.5 9216.5 9216.5 9216.5 9216.5 Last Reading 9913 9913 9867 9878 9878 9878 9878 9878 First Reading For Entire File .......... 9216.5 Last Reading For Entire File ........... 9913 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation.., ..... 01/03/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/02 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX FET GR ROP $ 9217 5 9217 5 9217 5 9217 5 9217 5 9226 5 9242 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: STOP DEPTH 9417 5 9417 5 9417 5 9417 5 9453 0 9424 5 9453 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G):. MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 07-JAN-01 Insite 0.43 Memory 9453.0 17.5 61.8 TOOL NUMBER PB01755HWRG6 3.750 9232.0 FLO-PRO 8.60 8.5 26000 5.6 129.0 $ 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 per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 RPX MWD010 OHMM 4 1 68 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1' 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9217.5 9453 ROP MWD010 FT/H 0.74 1996.67 GR MWD010 API 22.08 734.6 RPX MWD010 OHMM 0.18 1933.32 RPS MWD010 OHMM 0.11 1893.82 RPM MWD010 OHMM 0.1 2000 RPD MWD010 OHMM 0.07 2000 FET MWD010 HOUR 7.63 15.31 Mean 9335.25 118.619 115.451 42.1099 44.0177 62.8942 73.435 10.9197 Nsam 472 423 397 401 401 401 401 472 First Reading 9217.5 9242 9226.5 9217.5 9217.5 9217.5 9217.5 9217.5 Last Reading 9453 9453 9424.5 9417.5 9417.5 9417.5 9417.5 9453 First Reading For Entire File .......... 9217.5 Last Reading For Entire File ........... 9453 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/02 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 NI/MBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9418.0 9511 5 RPD 9418.0 9511 5 RPM 9418.0 9511 5 RPS 9418.0 9511 5 FET 9418.0 9511 5 GR 9425.0 9499 5 ROP 9452.5 9546 0 $ LOG HEADER DATA DATE LOGGED: 07-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0.43 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : ~ 9546.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 66.7 MAXIMUM ANGLE: 71.5 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): TOOL NUMBER PBO1743RF3 PBO1743RF3 3.750 9232.0 FLO-PRO 8.60 8.5 26000 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 ,lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type,,,0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 . 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 132,4 Name Service Unit Min Max DEPT FT 9418 9546 ROP MWD020 FT/H 0 74,71 GR MWD020 API 25,02 62,86 RPX MWD020 OHMM 17.75 54.58 RPS MWD020 OHMM 20,56 90,51 RPM MWD020 OHMM 22.45 97,23 RPD MWD020 OHMM 27,02 88,28 FET MWD020 HOUR 0,92 8.47 Mean 9482 42,6478 36,2891 34.6934 42,1482 43,5784 45,74 4,04186 Nsam 257 188 150 188 188 188 188 188 First Reading 9418 9452,5 9425 9418 9418 9418 9418 9418 Last Reading 9546 9546 9499 5 9511 5 9511 5 9511 5 9511 5 9511 5 First Reading For Entire File .......... 9418 Last Reading For Entire File ........... 9546 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 R3IW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9500 0 9876.0 RPD 9512 0 9887.0 RPM 9512 0 9887.0 RPS 9512 0 9887.0 RPX 9512 0 9887.0 FET 9512 0 9922.0 ROP 9546 5 9922.0 $ LOG HEADER DATA DATE LOGGED: ll,-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0.43 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 9922.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 72.5 MAXIMUM ANGLE: 79.2 TOOL STRING (TOP TO BOTTOM) ' VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 $ DUAL GAMMA RAY 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 PBO1743RF3 PBO1743RF3 3.750 9232.0 FLO-PRO 8.80 8.5 25500 5.6 135.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 4 2 8 3 12 4 16 5 20 6 24 7 28 8 .First Last Name Service Unit Min Max DEPT FT 9500 9922 ROP MWD030 FT/H 0.97 1736.61 GR MWD030 API 19.93 120.3 RPX MWD030 OHMM 3.13 47.76 RPS MWD030 OHMM 3.06 112.53 RPM MWD030 OHMM 3.06 108.28 RPD MWD030 OHMM 3.81 56.77 FET MWD030 HOUR 0 68.79 Mean Nsam Reading Reading 9711 845 9500 9922 68.2822 752 9546.5 9922 37.2368 753 9500 9876 21.454 751 9512 9887 23.3637 751 9512 9887 24.0571 751 9512 9887 25.2182 751 9512 9887 7.77528 757 9512 9922 First Reading For Entire File .......... 9500 Last Reading For Entire File ........... 9922 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/03/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/03/02 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