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Home My WebLink About201-147MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-03A PRUDHOE BAY UNIT M-03A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 M-03A 50-029-20102-01-00 201-147-0 W SPT 7807 2011470 1952 396 402 399 395 29 111 110 111 4YRTST P Josh Hunt 6/21/2025 very solid test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT M-03A Inspection Date: Tubing OA Packer Depth 45 2269 2247 2242IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250622110322 BBL Pumped:5.3 BBL Returned:4 Thursday, July 24, 2025 Page 1 of 1           MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 TO: Jim Regg` P.1. Supervisor I �"III(z( SURJF.CT: Mechanical Integrity Tests Hilcorp North Slope, LLC M -03A FROM: Adam Earl PRUDHOE BAY UNIT M -03A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT M -03A API Well Number 50-029-20102-01-00 Inspector Name: Adam Earl Permit Number- 201-147-0 Inspection Date: 6/4/2021 Insp Num: milAGE210607112116 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well M -03A - Type Inj w TVD 7807 "' Tubing 648 - 653. 648. 647 . PTD 2011470 Type Test SPT Test psi 1952 - IA 334 2253 2230 - 2225 " BBL Pumped: 3.2 - BBL Returned: 3.3 OA 56 283 - 273 269 - Interval 4YRTST RN .__� Notes: MIT IA Tuesday, June 8, 2021 Page I of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,July 20,2017 TO: Pisor '\ T 26(I"] SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. M-03A FROM: Lou Laubenstein PRUDHOE BAY UNIT M-03A Petroleum Inspector Sre: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT M-03A API Well Number 50-029-20102-01-00 Inspector Name: Lou Laubenstein Permit Number: 201-147-0 Inspection Date: 7/19/2017 ✓ Insp Num: mitLOL170719121951 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well M-03A ` Type Inj W ''TVD 7807 Tubing 1059 ' 1056 - 1055 - 1056 PTD 2011470 " Type Test SPT Test psi 1952 IA 289 2305 " 2285 - 2282 - BBL Pumped: 6.3 BBL Returned: 3.1 ' OA 13 53 • 53 - 52 - Interval 4YRTST P/F P V Notes: Thursday,July 20,2017 Page 1 of 1 STATE OF ALASKA • •LASKA OIL AND GAS CONSERVATION COMM( • REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed Abandon 0 Plug Perforations EZf Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other: I--VI G'I z3F i 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 201-147 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20102-01-00 7. Property Designation(Lease Number): ADL 0028260 8. Well Name and Number: PRUDHOE BAY UNIT M-03A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL �� 11.Present Well Condition Summary: Total Depth: measured 12600 feet Plugs measured 12337 feet MAR 0 2 2017 true vertical 8669 feet Junk measured feet Effective Depth: measured 12337 feet Packer measured 9613 feet AOCC true vertical 8716 feet Packer true vertical 7807.58 feet ,,/ �/ Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 100 30"Conductor 18-118 18-118 Surface 2272 18-5/8"96.5#K-55 17-2289 17-2289 930 870 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 12100-12130 feet 12257-12287 feet 12370-12400 feet 12420-12470 feet 12510-12560 feet True vertical depth: 8750-8747 feet feet 8729-8724 feet 8711-8707 feet 8704-8696 feet 8689-8678 feet Tubing(size,grade,measured and true vertical depth) 7"26#L-80 12-9716 12-7892 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SINNED APR 1 " 201, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 3039 120 919 Subsequent to operation: Shut-In 0 685 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG I I GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-548 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ✓„►l! Phone +19075644424 Date 3/2/17 Form 10-404 Revised 5/2015_ 1 rTL Jf n/ ^c^ Submit Original Only • • a) N Cn oCCOCD C)OLOCCOCCVV COO O 0 O V �r p 0 0 0 0 CD O O cy, co co 0 N CD M CD OD C- CANCDC'r) NCDC) N 00 CO 0) O co 0) co co 0) N N 0/ C`') Cl) CD CD CO N N N CO CO OD CO N- CD CC) T- CD CO C- CC) Cn O00 N CON T Cr T- T- ) CO M CD T- CV C` OD OD Q w6.1 coCD o cD COel el CI C) ' T• N N N O O N r 2CD 5 Z N- MM = OO CC) C.D CDO ON N C7 C O � � N d7 co LLI Lc) a)= U -J ZOpoco : d1:1V) *to04* z4* 4J N p I's 4t CI) 0 O Of E N O 00 0000 N QO CO • 00 a1 0) C' = O NNN00) u) 0C)) N- N N N N- a". J W W W i- 0)0 QQQ yowwww Z ct W W W W W Wap O I— ZZZj o fnZ Z Z J J :_-1 i- • • Packers and SSV's Attachment PRUDHOE BAY UNIT M-03A SW Name Type MD TVD Depscription M-03A PACKER 2286.97 2286.9 9-5/8"TIW PIN Packer M-03A TBG PACKER 9612.93 7807.58 7" Baker SABL-3 Packer M-03A PACKER 9745.3 7915.75 7"TIW Packer M-03A PACKER 10243.33 8320.73 3-1/2" Baker Liner Top Packer 0 0 @/ k .k ��kCO [ � c ® q � o — co _ N- o t 2 = i- if ƒ « Ef21 a o_ 4- \ B0 � 60� E - kcNi / E / % 13 2 k ° 0 • c Q• o ( .� ■ @ % .7 C) D - m k ƒ / 5 G .c ° \ » w - 21 C & O + c f o CI £ 5 2 R S o E t / 7� , = E ■ 2 = - 8 2 _ * _ al U o 3 [ $ 2 / ilh1 _ I T o � k cc) \ o 2 / U � 0 W E £ \ 0 co % 0 E � Rr, _ � - k a1 2 N 2I' Rte \ . Ce p o g 2 o q 0 _N o >. m $ _/ 0_ ' a2Q / � \ 3 co ® G • 2 \ p / O E % 2 0 2 2 2 �% e % $ 3 ; co � � k f , C/) - �2 � � %_ 002 gm \ $ 2 N f e o E ® _ 5 o w 6 -a) C � , ¥ , t - 07 / 2 \ f / / U 0 - � $ kai « b � 3 ƒ � -0o _o 2 / a = � .> » 7e = k70 � q2Ut2 k7og t $ cn � I-- Rego 04- I- 9w0 / a � £ U -3 2 : Q -, O O co : _ :O -, 2 : o c n L \ ® ¥ � d d / 2 � � % 5 � 2nm � , _ R / TREE= 6-3/8"CNV SAF SIR= 5M M,DEvoY M -03A H2S'ADINGS AVERAGE 125NOTES: WELL ( ppm WHEN ON MI. ACTUATOR= BAKER C CMCB ��_ *** WELL REQUIRES A SSSV WHEN ON MI*** BF.ELEV= 27.$4' I/1/4< I **K-55 BURST 3450 PSI** KOP= 3000' 13-3/8"(SG,68#, - 60' 2029' H 7"OTIS SSSV LANDING NP,D=5.962" Max Angle= 103°@ 12600' K-55 BTC. Datum ND= 11034' D=12.415" 2029' -1 NSb i w 14-1/2"NP,D=3.813"(XX/XX/XX?) Datum TVD= 8700'SS 2281' H 13-3/8"X 9-5/8"11W FIN FKR 13-3/8'CSG,72#,L-80,ID=12.347" -I 2283' \ --I 2287' -113-3/8"X 9-5/8"XO 18-5/8"CSG,96.5#,K-55,D=17.655" --I 2309' Minimum ID =2.372" @ 10693' 3-1/2" X 2-7/8" LNR XU 11 9612' I—9-5/8"X 7"BKR SABL PKR w/K-LATCH,ID=6.00" 9664' —�7"OTIS R NP,ID=5.963" 9710' --I TOP OF TMV PBM,D=7.375" 9715' -17"TM BTM SEAL ASSY W/O SEALS,D=6.187" 7"TBG,26#,NT-80-S,.0383 bpf,ID=6.276" H 9708' -}•- 9748' -I9-5/8"X 7"TM/LTP,ID=i" 9753' -I9-5/8"X 7"TNV LNR HGR,D= 10243' H5.59"BKR LTP,ID=2.39"(08/16/01) TOP OF 3-1/2"X 2-7/8"LNR -1 10249' 10249' --I5.90"BKR DEPLOY SLV,D=3.00" 9-5/8"CSG,47#,L-80,D=8.681" H 10265' IA 7"WHPSTOCK w/RA TAG @ 10570' H 10560' 7"LNR,29#,L-80,.0371 bpf,ID=6.184" { -10563 BKR CUP (SET ON 08/02/01) --I 10600' 011' MLLOUT WNDO'W(M-03A)10563'-10570' 710091C- • 3-1/2"LNR,8.8#,L-80 FL4S,.0087 bpf,D=2.992' -1 10692' \I 10693' -3-1/2"X 2-7/8"LNR XO,D=2.372" PERFORATION SUMMARY REF LOG: SWS-BI-KS ON 09/15/71 ANGLE AT TOP PERF: 97°@ 12100' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2" 6 12100-12130 0 09/24/14 12337 -12-7/8"BKR CBP(01/31/17) 2" 6 12257-12287 0 09/24/14 2" 6 12370- 12400 C 09/24/14 2" 4 12420- 12470 C 08/17/01 2" 4 12510-12560 C 08/17/01 PBTD -1 12566' 404 2-7/8"LNR,6.4#,L-80 FL4S,.0058 bpf,D=2.372" -F-12600" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/19/77 N1 ES ORIGINAL COMPLETION 09/30/14 JTC/JMD ADFERFS(09/24/14) WELL: M-03A 12/31/90 N1 ES RWO 01/04/17 JUJMD ADDED CSG XO&SAFETY NOTE PERMIT No: 2011470 08/18/01 NORDIC 1 CTD SIDETRACK 02/08/17 M Z/JMD SET C1BP(01/31/17) API No: 50-029-20102-01 03/06/12 TBD/PJC PULL PLUGS(03/05/12) SEC 1,T11N,R12E,2401'FSL&605'FEL 09/14/14 DLW/PJC SET INSERT W/NP(DATE?) 09/15/14 PJC REFORMAT-CLEANUP WBS BP Exploration(Alaska) .V OF 7 j,, • • g4•!\��\��j,�s� THE STATE Alaska Oil and Gas m• � -'7----> •.•• ..,. ...1-. 7�► of ti_ —�� /` LASKA Conservation Commission ft "i-t �� _.- - 333 West Seventh Avenue l ?" *47,;74 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF Main: 907.279.1433 ALA5l‘ Fax: 907.276.7542 www.aogcc.alaska.gov Matthew Bergene r Production Engineer Challenger ANNED FEB 2 1.L01 , BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-03A Permit to Drill Number: 201-147 Sundry Number: 316-548 Dear Mr. Bergene: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, & PLL Cathy P. Foerster Chair to- DATED this 3) day of October, 2016. RBDMS L' N"'' - 1 7^4i STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMON • APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ® . Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate o Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other 5 c f C l 0/.) lE 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 201-147 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development El 99519-6612 Stratigraphic 0 Service 0. 6. API Number: 50-029-20102-01-00 - 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No IJ PBU M-03A • RCOlt D 9. Property Designation(Lease Number): 10. Field/Pools: '�'` ADL 0028260 • 07 5 t(0 13/ /b PRUDHOEBAY,PRUDHOEOIL. LW 9,4 2015 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): 12600' 8669 • 12566 8676 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2272 18-5/8"96.5#K-55 19-2290 19-2290 930 870 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 7"26#L-80 L-80 14-9713 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program g BOP Sketch ❑ Exploratory 0 Stratigraphic El Development 0 Service Ed 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ❑ WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG Ef GSTOR El SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Bergene,Matthew be deviated from without prior written approval. Email Matthew.Bergene@bp.com Printed Name Bergene,Matthew Title Production Engineer Challenger Signature --"...6.044--l S(; Phone +1 9075644849 Date 20 0c4, I G COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes❑ NoUt j Spacing Exception Req fired? Yes❑ No Subsequent Form Required: /0 — 4 0 4-' SP %"c,13. I,(o Approved by:ak /'' d.,...._47 COMMISSIONER APPROVED COMMISSION Date: Date:/0-3 1„ VTL- to/ 5/ 6� 44, 0 k i L'' i ii 1 ' k RBDMS t NOV - 1 2016 /o Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachmtsn Duplicate 7 4)..m 6 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: M-03A Well Type: WAG Injection Well API Number: 50-029-20102-01 Well Activity Conventional 4 Classification: Activity Description: CIBP Set and WAG swap Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory requirements? Sundry Form 10-403 SSSV required when on MI iniectior Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Matt Bergene Contact numbers: (907)564-4849 (307)630-9653 Well Intervention Engineer: Josh Allely Contact numbers: (907)564-5732 (907)350-7362 Lead Engineer: Ryan Rupert Contact numbers: (907)564-4238 (907)301-1736 Date Created: September 27,2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate Date Choke SettinFTP or Injection g Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 9/24/2016 821 0 294 Current Status: Operable Flowing Inclination>70°at Depth(ft) 10,750' MD Recent H2S (date,ppm) NA 0 ppm Maximum Deviation(Angle and Depth) 103° 12,600' MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 23° 11,275' MD Reservoir pressure(date, psig) 7/25/2011 3,358 psi Minimum ID and Depth 2.372" 10,693' MD Reservoir Temp,F 150°F Shut-in Wellhead Pressure 200 psi Known mech.integrity problems(specifics) None Last downhole operation(date, operation) 9/24/2016 CTU add perfs Most recent TD tag(date,depth, PDS memory logging tools inside 2.2"carrier w/2.25"DJN, toolstring OD) 9/24/2016 12,445' MD OAL= 12.45' If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Kit Fit-for-Service? YES If No,Why? Surface Equipment Checklist. Comments,well history, Background: M-03Ai was coil sidetracked in 2001. It was perforated in the toe which is high structurally background information, (45P perhaps lower 46P also,a fault at-11,860' MD complicates this interpretation). Prior to adding etc: perforations in the 43 and 44,the well had 4 MI slugs with little benefit seen by the surrounding producers. This is unsuprising as the two toe perforations are structurally higher than many of the surrounding producers. In 2014 additional perforations were added in an effort to improve conformance and sweep. However,as evident on the hall and injectivity plots(attached)there has been little to no change in the performance of this injector. The lack of a change in injectivity indicates that most of the water is exiting • S the two toe intervals,which had previously had water injected. Cement Quality:While drilling the well there were two loss circulation zones at 10670'and 10980-11003'. After fixing the LCZs drilling continued with between 50-100% returns. Once TD was reached,the liner was run. Once landed,static losses were established to be 0.3-0.4bpm. This loss rate continued during cementing and remained constant even after cement was pumped. 34 bbls of 15.8ppg cement was pumped,and during the final clean out 30 bbls of 9-9.6ppg cement mixture was returned to surface. Due to the lack of incremental losses in the area where we are currently perforated,as well as the cement returns at surface,we are confident that we have cement islolation,and will maintain injection in the intended zone. Plan:The purpose of this work is to set a CIBP between the two perforated intervals in the 44. The goal is to isolate the toe perfs in an effort to force MI into a structurally lower area to increase the area contacted by MI and improve the sweep when on water. • • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Poor patern conformance Specific Intervention or Well Objectives: 1 Set a CIBP at 12326' 2 3 Key risks,critical issues: Mitigation plan: The CIBP will be set in the 83'gap between the two perforated intervals in the 44. This is being done to 1 Cement isolation and channels minimize the chances that we are or end up being connected on the back side to the more established sets of perforations in the toe of the well. This well has been on PWI for a while,so some schmoo 2 Schmoo is expected. While drifting,jet diesel from the LTP to 12400'(CIBP will be set at 12326). 3 Summary Step# Service Line Activity 1 CT Set CIBP at 12326'MD 2 SL Set SSSV for gas injection 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1) Drift and tag TD with GR/CCL,jetting diesel from the LTP to 12400'. 2) Flag pipe for CIBP tie into PDS Coil Flag UMT-GR-CCL dated 9/23/14. 1 CT Reference log is MWD NGP Natural Gamma Ray, EWR Electromagnetic Wave Resistivity Log dated 08/06- 08/15/06 1' need to be added to the tie in log to be on depth with the reference log. 3)Set CIBP with the top at 12326' 2 SL 1)Set 4-1/2"RS valve in the insert in the SSSV nipple at 2029' 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: POI with 7 mmscfd Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc . M-03A SWI PMT PMT/ ITmyry variable BESTGR U gA% 150 H CALL WURD.SWf 0 CALC WURD.PMIT i 1 vry o1 vry D Empty ra/JRO/a O CALL.WURp.KGE080 CALC.WURD.SWN ti. col MD 10000 1 VA, 0 LI Empty ramMble • RESOURCE • J CALC WURDUHIT CALL W RDKGE050 01 0 OWN J CALC WORD.BVWT 1 0 OAPI 140 *..f,. was,D55 31 0 WV 0.3 0 001 MD 10000 110 3, I 0 CALC WUURRD00ANDFtAG (FEET) (FEET) t CALC W000.PMI CALC_WURDKGE020 CALCWURD.S01A Inc.,ND55 j •I IUII0R1I.Sf� 1:1200 1:1200 0 C 0.01 MD 10000 1_—_—VN __-'0 "."ssnemxrc CALL,MAIL 10500 R'4D e g 0 ON _ 10540 85"14 10580 8556 c L 10620 85788598 " 1066.0 861.8 ' #1 10700 � 'ii _ lad °; 10988 Rims !-gym -+0 :`�� 11020 8700 11060 8700 11100 11140 11180 - 8700 11220 8704 11260 8708 ' 8712 11..,.....,„,.., 8716 11340 8720 11380 8724 11420 8726 } 8728 11460 11500 11540 .. 8728 11580 8726 11620 11660 8724 11700 11740 8724 11780 11-1-1-820- i-1-i860 I, 1111111 MI 11900 IN'119.4,0. 111- - 12020 immi 8714 ' 12060 8710 12100 8706 12140 8702 • ....A.••• 12180 - 1. 1iv _ 12220 8690 ±`` - 12260 8682 11M-1.±—,MI—Al 12300 8676 I moan . • 8670 1111r{ 12380 8666 �'o 8662 a ----- E___, 12420 8658 - m- - �� 12460 8652 12500 8646 � . � 12540 864igi 12580 86340 • 41) TREE= 6-3/8-OW i WELLI-EAD- 5M NCEVOY M-03A SAFIFTY NOTES:WEI l ANC*E>70*rg 10750'••• H2S READINGS AVERAGE 125 ppm WHEN ON All ACTUATOR- BAKBR C *I OKB. EV 44.54 WELL REQUIRES A SSSV WHEN ON MI"ELr ' BBEV- 27 84 I 1.Kopr„ 3000 4 2029' -,-.7'uns sssv LArtiNG NAP,ID=5.982- 1 ,Mu Angle 103"@ 1 :i i -..CONDUCTOR - ..1- . 1 Datum MD=- 11034 N, , H 2029 H MEAT w14-vr NP,ID=3 1313"(xxrxx1xr7d !blur°1V13= 8/00'S.'S Ii= ' .---------• 2281' '-413-3/er X 9-5/8'TPA Ft4PKR --- I 13-3/8'CSG,72*,,_-80.El.-..12.34r --I 2283' I----- /*4: --1 2287" H 13-318'X 9-518'XO F18-5/8"CSG,90.5*,K-55,D=17.655' 1 2309' 1-411 II\ I Minimum ID mc 2.372"(til 10693' li 3-1/2"X 2-718"LNR X0 i x-- I est 2' H0-5/8"X 7'DKR SA BL PKR w/K-LATCH,ID,.6 0_9•J I i--I 968* 9710 f-{,,o.of IIA/MR,1)-7 371," _, ......„.„.„4- 971s• --r•TIN IIITM SEAL ASSY WO SEALS,C=6-187'] 7'TBG,2600,NT-80-S,.0383 bpf,ID=6.276' I-1 9708' 748' 1-1 8-5/8"X 7'TW_IP,ID= .1 I 9753. i---0-5/a-x r Thtv 1.NR NCR,13= • 1 10243' 15.59'SKR LIR U.2.39-(08/10101) TOFF-.OF 3-1/2"X2-718'U,R I- 10249' F102---4.9' H s 90-TvcR ota.LoY sot,o=3 00- ___ 9-518"CSG,47#,L-80,U=8.681-1 102e6. FA ii 17"Wi 117.1TOCK w i RA TAG@ 19570' -I 10580' I 7'LNR.298 L-80,.0371 bpf,(1=6 184' -1 -10563 r0i' &113-7:,;S-Cirt3-1404/02/0iii_r-46300, 1 /ALL OUT IAMEIOVV(11.03A)10563-10570' It. trd I lompi' a 13-1/7 LIP,P,888 1 80 rt4s, 0087 bpf,o-2 997 1.1 10892' I....,....1, I 10629' 1 13-1/7 X 2-718"I NR XO,ILI=7 172' I , PIRI ORA RON SIMIAN KY , REF LOC,: SWS-OICS ON 09/13,71 ANGLE AT TOP PERE 97 @ 12100' I Note:Refer 8i Productkin ER for histoncal pert data SIZE SRF INTERVAL Opn/Sqz SHOT sty ' I 2" 6 12100-12130 0 09124/14 2" 6 !12257-12287 0 09124/14 I I 2' 6 '12370-12400 0 09124/14 2' 4 12420-12470 0 08/17/01 r, I 2' 4 12510-12560 0 0I3I1701 N.% PBTO li 12588' e o •• 12:7/8-UsR,8.48,L-80 FL4S,_0058 bpf,ID=2.372' IH 12600' F-TiCTE Rev sr' CCANENTS LATE I REV EY GOAAINTS PRLO-10€BAY UNIT i 10.19/77 N1ES !ORIGINAL COMPLETION 09/39714 JIMM1DIACEERFS(09/24/14) WELL: 1403A i ; ---—- 1231790 NIES Imo FERmiN>:2011470 08.18101 NOREICACTD SIDETRACK API N3 50-029-20102-01 i 03.0E/12 TB!)P PULL PLUGS(037)5/12) , ; SEC 1,TI IN,R12E,2401'FSL 6605'FR 09.14114UW RK SET HSERT VAMP(DATE?) i 09:15/14 PJC 1REFORP.44T-CLEANUP ABS . BP exploration(Alaska) • • rrmWO Awrm_I_i -i ��70 C a1 .Z7 5N (D O.Q �K O1W�TZ70 Ti 5 o 3 a.N al a O O S m a•s = .o z tv 0 0 x 0 = o o4 Wa company BP Exploration (Alaska), Inc. ; Eur j.2A 2 m m 3 m a n _ 3 oo= Well M-03A o ��F . ., m a aa� �� - oom�oo�Q `a n 03.T. o w N m i6`� Field Prudhoe Bay �' ��e; a i:::04 Borough North Slope T L o g z State Alaska - a D1- v 1! � �'Ai m fD lD O 0 wo �i a al (n N O Q = 3 7-4:3 N ".. wcnCC!03 CO @- To 2 cFr; 3. m (fl to, `�y 3 S a m oO i All Q T r ~ 0 V 1 2 m o W � 11, 3 a -' N 5 Z -0 K W ^4 S151� . W�, _ w o C 1-ry 0 p x�?(')QJ W 2e' 2- - NOm 0 111 a.W V I 1 N I V y Q D CO N NASI 11:1-; N N oe cNta T a)0)(0 7 (.71 X -I m 1 T tii 1 1 W Np W O 1 N Wt-� v 1 07 N _ ao r 1 O CD "11 Z D _� W o D A m - 0 cn m cn cn 0)C.^o I .g Z 0 < m x m O wC O cccc 1 4„-,,,,,,c° D m m f EU' Z . —i r aaimmw� 0Q8-nag m m �v m (p ^ (n 0 0 0 0 "ate r o a• 6 G7 S C2 � = D D m qa Nm O nl r > nn) o m r0 GO C TI CO U^ 4' 0 Q1NmOo. 3 C WW D D NNO co r W oO O m — `N W Z ZZ 2 � Z0241,O3 NOOK OWw ja a < 'm m co „ ®iagivosrr o" �- �� Composite Main Up Pass ^N Start Pass @ 16:22 PROAc.jvr Oiagrvosric SCRvicc,, Database File: d:\warrior\data\m-03a_coilflag\main_3.db Dataset Pathname: pass1.1 Presentation Format: coilflg1 Dataset Creation: Tue Sep 23 20:24:50 2014 by Calc Warrior 8.0 STD Cas Charted by: Depth in Feet scaled 1:240 28000 CCL -2965 0 Gamma Ray(GAPI) 2000 0 Gamma Ray(GAPI) 100 0 Coil Speed(ft/min) -200 12200 • • Perfs-12257'-12287' • 12300 EOP @ Flag Depth ( 12,326.45') CIBP Top at 12326' CCL MP @ Flag Depth(12,336.05') CCL—+ • Gamma Ray Perfs-12370'-12400' —Coil Speed 12400 • • Cum WHP vs.Cum Water M-03A 4000000 3500000 3000000 2500000 ' 2000000 1500000 1000000 500000 0 .,,,Z7'...". ./.....#°°°*°..."#° 7 0 2000000 4000000 6000000 8000000 10000000 12000000 turn Warar The Hall plot indicates no change in the slope. The red points indicate injection after 9/24/2014,when the 44 and 43 were perforated. The lack of a change in the slope indicates little has changed with respect to injectivity. • • Water Rate vs.WELLHEAD PRES 5500 00 M03A 6000.00 • • _ 5500 00 ...• t • • 500000 • 4500 00 y 40 • •• 111:e®• Se 6000 00 • • • • ♦ 350000 •. 1 $, • • 3000.00 � , • • 1 • 3 ••• • • 250000 ss• •• • y :::: 0 • •�4 i •• Z• ••• ti• •to•• • k i411/14 • •• • 1000 00 ••• • ••••• • • •• 50000 m • • • • 0 00 • • • • 0 00 100 00 200 00 300 00 400 00 500 00 000 00 ?00 00 000 00 600 00 1000.00 1700 00 1200 00 1:,-0 WELLHEAD PRES - The red points indicate injectivity data after the addition of perforations in the 44 and 43. The time range on the blue dots are from 9/24/2012- 9/24/2014 • • Eo e:M-03A y Zone Depth 0912412014 092412014 03105/2012 0811712081 08/17/2001 12060 __..__._:.__ 12090_._._............._..................._......._._.....'..__............_.............._.._.........__.._.....i._._...........___.......-.._.........__.._.._....'............__............. 12120..:___......._..._.._........_._.._._.._.... 1830Ywar ... .. ..__.i_..._..__..._...__...__.._.......... ..._....._........_._.. ...._._.._____ ...__.........._.._...........__.........._.i 12150...__..._.......___.......__...__.._.......__...._........._.._......_. 12180..._............._...__...._...._._......._..._}...._....._....._........._.._..........._.........I-.._..._.-..._._...._._.._........__...._.....fi_......_._.._.......-.._......._._..._. ; ......___..........._...__..._._.....__ 12210__............_....__......__..—..._.._..._. 1 ._._.._._.. __.._._..._....__...__................ 12240 - ..... .i.._.._...___........._...._. ' ; i 1 12270..___.............-.._........... ..._..__.... .8 ._....__.............._.._.. en..__.._..._.._.._.....__..__.._;.__.. -..._...__....__ ...._...._..._....__..._.._............... I 12300_._....__..._..._._.....__..__..._...__.;.._.........._._...._..._._..._:._.;._. =-__.. _._._. ----- CIBP set between peforations in the 44p --'---- c12330..._..............—..__...—__....._.._.....:......_. I I._ 12360...- i I .._.;._ tI i 12390.. ........._-_..._._.........._...—.._._.... 8.30Y_..........._...�..._.. t2r.!..__._._......._...__._—. 12420 SB=1. -....__.._...__......._ ._._..._.............._._. ' ' 12450..._.__.............._.._..........._____.__.... .._...__..._............_....__._.... Irr PER 12480 ....._....._..._.._.__..........__..._.._.....:....___..........._............._.__.__....J-.._._........___..._._.__.....__-_i-......_.__.._..._..................._.._......._. I78.184 i ioo .....__..__..............._..._...._......._..............._._... : 12510. ......._........_.._.......____......_..__.. .._._. 1 1 i12540� .....___...___.__........_._.____.._.... err I ..._........._.._........__.........IPEPI 12570:. ......_................................_......._.........r........_....._......._...—..__........._._.....i.. .._.._._...-...._..__...�....._._.__......._.... L_....._..__.___....-....__.........._.. 12600 -- • The CIBP will be set between existing perforations with in the 44P sand. This will provide assurance that there will be enough cement to provide isolation between the older perforatations and where we intend injection to go. • S cL 00000 `n0 CO (n O N szr U p000o C° o L N- LO N- CO (0 V 3 M 00 d' CO c- m (A (O M (fl CO O O C)) CO N (.o O (A 6) O O (fl C)) CO (O CO N M M (() CO O CO N N N CO CO CO CO N- I0111111111 00 r- co f-- (n (fl O O CO N CO r CO CO CO CO N N- CO CO c CD OOco Li, MMO NN (•r) N (() (fl co 1 N N O O Co N p r r � vCU . 111111111 Q Q M co p co co f� (� (fl co O r- V (5)0 T- M CO C c 2CV 0 n • co EL LO (n 0LC) 0 co O O Y 00 i 00 p , 0o p 'N N c O r 0o *k cn O O _ (A Cb (fl (O U 60 co 0\O N - Eo N CO O O) A N L CO r- C (N 00 (N CO cr)l cO O O N N N CA O aL)J N N c\1 r- 00 C3) W W W c)0 Q Q Q Ci) • U U W L W U• 0 W C ct Z Z W W W W W W � = Z Z Z Z _Z Z_ (/) — — _ J J J • 0 o 0 o co c0 N (� CO = O C,') Is-- N- p, O V COO r- a7 V N O O N- o O cc CO cc O c0 I- o. 0 I— co L[) co c0 (3) = N 0 0 0 O O. O 6) — � CO 0 CD O N N— O CO W 0 r- I,- r,- r- O > 0 CO CO CO CO CO 0 > 2 WcL 0 W 0 0 U Z LU LUW o U a LU UO N o CO OO Um I H 12 2 co on 0 N- Ua a Z2 N 'CQ Q < Wa C O N N N N N U U U OJ J W E E O 2 Z Z Z 2 0 0 a lt1 a N m 0 0 0 w ca Q Z Hp Z Z co 2 2 2 O ) c~n ccnn cJn u) CV ++ O a Q Q o e- = Or- 000 O a m• Otf) NN(,- N CO V O 1175 < O N N N N N y co O 9 E cC v) Y = U o cn cc w M 2 2 o c) ) couu)i co a a) a 0 0 c 2 u_ LL LL ct ct I., O d O W W `m Q Q Q 0_ d O. 0 t a) a a> H m V V VO :5 0 O O 0 O c 0 0 0 O O WZ O N N N N N Z - 1 1 < W W V N- N o Ill 11 o ii J N U N N N -_ Z Cl_ 7 J 0 0 o W a W O. 0) o) cb co < 0 _ H _1 _1 -I D a O m U r m Y W —I —1 Q O W W < < T] a S] cn if. IL LL cn a a' co E m z Q Q Q Q Q co co co co co N cO cO cO CO CO W a u) O u_ N CL lL G c C c GJ Q Q m m 0 it 0 0 a a' WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital infonnation available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ,;?o/ If¡ Well History File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Maps # Yes No Yes No Yes No Mud Logs # Other # General Notes or Comments about this file. If any of the infonnation 1isted above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg 11 12. 5tAMED AUG 2 1 -- Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 � - 1 ` //i�1 7 Subject: Corrosion Inhibitor Treatments of GPB M -Pad 0 3 a_ Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-.off Report of Sundry Operations (10 -404) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA `> M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 01 -AUG -2011 Schhnherger No. 5774 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD R -28 BJGT -00051 SBHPS 23-Jul-11 1 _ 1 MPB -23 BJCR -00099 LEAK DETECTION LOG 22-Jul-11 1 1 06 -01 BBSK -00080 PPROF W/ DEFT & GHOST 23-Jul-11 1 1 U -06B BJGT -00053 SBHPS 25- Jul -11 1 1 �� M -03A BJGT -00052 SBHPS 24- Jul -11 1 1 01 -20 BBSK -00054 LDWG EDIT OF RST 5- Mar -11 1 1 P2 -52 BJGT -00021 LDWG EDIT OF RST 6- Mar -11 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • ..,... 14` .' ' RECEIVED . °SP;2`!' AUG 5 2011 .. • MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~ ~~~"~~~ FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 22, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC M-03A PRUDHOE BAY UNIT M-03A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~~ Comm Well Name: PRUDHOE BAY LJNIT M-03A Insp Num: mitCS090718113233 Rel Insp Num: API Well Number: 50-029-20102-01-00 Permit Number: 201-147-0 , Inspector Name: Chuck Scheve Inspection Date: ~~16/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~ M-03A Type Inj. W 1'~ 7g~7 -~ IE~ 420 2500 / 2500 2500 ~ P.T.D 20ll470 TypeTest SPT Test psi 1951.75 ~ QA 240 480 480 480 Interval a~TST p~ r ~ Tubing ~ooo iooo iooo iooo Notes: t ;~ ~1(`t? , ~~ik r ~'. 7 ; ~ : 1 ~ Wednesday, July 22, 2009 Page 1 of 1 Re: M-pad temperature logs . . Subject: Re: M-pad temperature logs From: Tom Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 20 Nov 2001 09:43:56 -0900 To: "McLellan, Bryan J" <McLeIlBJ@BP.com> Brian, Thanks for the info. I'd like to get together as well. When is the key?? Performing the same procedure on M-13Ai is appropriate. For the present time, on the other wells, I suggest you send us the log copies and include a letter describing the why and then the what was determined. How does that sound? Also, is the reporting by Joe just until we have a chance to pass approval on the temperature logs?? Tom "McLellan, Bryan J" wrote: Tom, I would like to set up a time to get together to discuss the M-03Ai and M-38Ai temperature logs. Both logs would suggest that we have cement isolation uphole from the perfs. I can either come to your office when have time, or send copies of the logs to you, whichever you prefer. ~ ~Q\-\,-\~ you I have also asked Joe Anders (BP Well Integrity Engineer) to add these wells to his monthly monitoring list and he should begin reporting injection rate and pressure to you each month. Also, we just finished drilling well M-13Ai and would like to use the same method to confirm cement integrity as we did with M-03Ai and M-38Ai. If you agree, we will run a baseline temperature log and follow up with a temp warmback after 1 month of injection in M-13Ai. Thank you, Bryan McLellan Bryan McLellan BP Exploration, Alaska Production Engineer (907) 564-5516 ""..-> SCANNEt~ JUN 2 5 2007 ~'ð ~~ ~~\t'- ~LO~J lof1 6/25/200712:33 PM Re: M-38Ai Temp wannback. . . Subject: Re: M-38Ai Temp wannback. From: Tom Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 03 Oct 2001 09:08:34 -0800 To: "McLellan, Bryan J" <McLellBJ@BP.com> Sounds good Bryan. I will look forward to your update. Tom "McLellan, Bryan J" wrote: Tom, FYI All the injectors at M-pad were shut in for the GC-2 shutdown for 9 days in September, so I am going to delay the Temp warmback on M-38Ai until mid October. M-38Ai started injecting on 9/5/01. M-03Ai has still not come on line yet. I plan to get the SRT on M-03Ai 1 month after first injection. I'll keep you updated. Thanks, Bryan McLellan Bryan McLellan BP Exploration, Alaska Production Engineer (907) 564-5516 scANNED JUN 2 6 Z007 . lofl 6/25/200712:07 PM e ~1T~1TŒ [ffi~ ~~~~~~ e AI/ASIiA OILAlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR ¡ 333 W. T'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Don Brown Pad Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 /v:v1 ;)v 0 \ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, M -03A Sundry Number: 306-207 SCA..~NED JUN 1 42005 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisJ1 day of June, 2006 Encl. · 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U Waiver U v Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development 0 Exploratory 0 201-1470 3. Address: P.O. Box 196612 Stratigraphic 0 Service ø 6. API Number: Anchorage, AK 99519-6612 50-029-20102-01-00 7. KB Elevation (ft): 9. Well Name and Number: 44.54 KB M-03A 8. Property Designation: 10. Field/Pools(s): ADL-028260 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): IPlugs (measured): IJUnk (measured): 12600 8668.9 12566 8676.45 None None Casing Length Size MD TVD Burst Collapse Conductor 80 30" Conductor 22 102 22 102 Surface 2288 18-5/8" 96.5# K-55 21 2309 21 2309 930 870 Intermediate 2262 13-3/8" 72# L -80 21 2283 21 2283 5380 2670 Production 10245 9-5/8" 47# L-80 20 10265 20 8339 6870 4760 Liner 810 7" 29# L-80 9753 10563 7921.96 8592 8160 7020 Liner 438 3-1/2" 8.8# L-80 10255 10693 8330.6 8686 8640 7870 Liner 1907 2-7/8" 6.4# L-80 10693 12600 8685.91 8669 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12420 - 12470 8704.08 - 8696.3 7" 26# NT-80S 17-9710 12510 - 12560 8688.59 - 8677. 78 - - Packers and SSSV Type: 9-5/8" TIW PIN Packer Packers and SSSV MD (ft): 2281 7" Baker SABL-3 Packer 9612 7" Top Packer 9748 5.59" Baker Top Packer 10243 12. Attachments: Descriptive Summary of Proposal ø 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service ø 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/20/2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG...8' GINJ 0 WINJ œr' jlJ61t" WDSPL 0 Commission Representative: Prepared by Sharmaine Vestal 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Don Brown Printed Name Don Brown Title Pad Engineer Signature () l'Hî d ('v { "A1 1Y'\ Phone 564-4323 Date 6/6/2006 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ISUndry Number: ~-ótO~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: ã)I~ RBDMS 8FL JUN 1 3 2006 Subsequent Form Required: APPROVED BY t--ß ,t'b Approved by: C~ISSIONER THE COMMISSION Date: V - '-"'" --- #G {] /;2/ q:;;' _ STATE OF ALASKA _ AL~ OIL AND GAS CONSERVATION COMM~N APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 I ,\a..;.l"a..;.1 V a..;,U JUN 0 9 2006 Alaska Oil & Gas Cons. Convnission Form 10-403 Revised 7/2005 OR\G\NAL Submit in Duplicate e Wire line Work Request Alaska Wells Group .4.512/14/0 I M-03A I Distribution Wireline (2) 1- - - - - - - - ~~: pL:;~_I_:_ - - - - - - -1 Well: M-03A Date: 06/01/06 lOR 0 AWGRS Job Scope: AFE: PBMPDWL03A-C Engineer: Don Brown WBL Cat. lOR DRIFT/TAG (RATE) Beware of the potential fo Problem Description H2S in the returns This well has been on MI injection from 6/25/05 to 3/31/06. In attempting to swap back to PWI from MI and the recent GC2 shut-down, the well will not take fluid. Initial Problem Review 04/01/06; OBP for WAG swap to water. Well POI 16:00, needs checked 04/02/06; UWP for breakover well locked up with seawater and switched to meth. And now on 50/50 pump but it kept shutting down. 04/02/06; Tried to break it over with the Skip pump but it kept shutting down. So the pump truck will need to be sent out there ASAP first thing this morning. 04/03/06; 1550 psi on tbg and pump crew may be there tonight. 04/04/06; Pump crew unable to break over OS/23/06: Injectivity Test; 0.5 bpm @ 3000 psi Remedial Plan - WIRELlNE ACTION Obj: Obtain injectivity in the well 1. WL: Drift to TO to ensure that no obstruction exists in the wellbore nor any fill is across the perforations. (Minimum ID = 2.372" @ 10693' 3-1/2" x 2-7/8" LNR XO) 2. C: FCO (pending 0 & T) 3. C: Spot 20 bbls 7.5% HCI acid across perfs located at 12420' to 12470' MD and 12510' to 12560' MD. Do not circulate acid to surface. 4. EL: Run IPROF 5. POI TREE - 7-1/16" 5M CIW WELLHEAO - 5M fvCEVOY A C1UA TOR = OTIS KB, ELBI = 44,54' BF. ELBI = 27.84' KOP = 3000' Max Anale = 103 [a) 12600' Oatum M) = 11034' Oatum lV 0 = 8700' SS 113-318" CSG, 72#, L-80, 10 = 12.347" 1-1 118-518" CSG, 00.5#, K-55, 10 = 17.655" I e 2283' 2309' µ Minimum ID = 2,372" @ 10693' I 3-1/2" X 2-7/8" LNR XO 19-518" X 7" TIW LNR H3R I 13-1/2" LNR, 8.8#, L-80, .0087 bpf, 10 = 2.992" I 19-518" CSG, 47#, L-80, 10 = 8.681" I BKRClBP (SETON 08102/01) 9753' I 10255' I 10265' I 10600' PERFORATION SUrvfV1ARY REF LOG: SWS-BHCS ON 09/15171 ANGLE A T TOP PERF: 31 @ 10688' i'bte: Refer to A-oducijon DB for his10rical perf data SIZE SPF IN1ERIIAL OpnlSqz DATE 'l' 4 12420 -12470 0 08/17/01 'l' 4 12510-12560 0 08/17/01 ~-j I 7" Lt\R, 29#, L-80, .0371 bpf, 10 = 6.184" I @] DATE 10/19/77 12/31/90 08/17/01 04/22/01 08/13/01 08/07/04 REV BY OOrvfV1ENTS ORIGINAL COM PLETION JQ RWO C.....KAK CTDSIDETRACK Rl\Vtlh CORREeTONS ?fTLP AOOWHlffiTOCKAtÐ ClBP BMcLlTLP PERF OORRECTION 11227' I 11350' I 11362' I DATE 7" MILLOur WINOOW - 10563' -1 0570' .. TOP OF WHlffiTOCK - 10560' ~~TAG-10570' .~ ~ 10693' 3-1/2"X2-7/8"LNRXO,ID-2.372" '.... ~ '-----1 ""1--J I ~ ~-1 12566' I 12-7/8" LNR, 6.4#, L-80, .0058 bpf, 0 = 2.372" I 12600' 1 I 10877' -17" 1lW HBBP-R REf A<R, 10 - 4.00" I I 10896' -17" M6.RKER JOINT I M-03A ~ 1-, 18 I ~ f-r' ~ ~ .a. --, RBI BY e SAFETY NOTES: WELL> 700 @ 10750' AND> 900 @ 11065'. o 2029' 1-17" OTIS SSSV LAt-DING NIP, 10 = 5.oo'l' I 2281' 1-113-318" X 9-5/8" 1lW AN A<R I I 2287' H 13-318" X 9-5/8" XO I ~ ~ ¡.,...., 9612' 9-518" X 7" BKR SABL PKR I ¡.o I W/ K-LA TQ-I, 10 = 6.00" I 9664' -17" OTIS R NIP, ID = 5.003" I . I 9708' -17" 1BG, 26#, NT-80-S, ,0383 bpf, 10 - 6.276" I t--r--- 9710' 1- TOPOFTIW A3R,IO = 7.375" I ~I'- 9715' t- 7"1lW BTM SEAL ASSY W/O SEALS, 0 = 6.187" 9748' t- 9-518" X 7" TIW Lt\R TOP PKR I vV 10243' -15.59" BKR LNR TOP A<R. 10- 2,39" I I 10249' -15.90" BKR OEA...OY SL V, 10 = 3.00" I I" I 12< I ~ . . . II!..---- I I 10956' -17" 1lW HBBP ÆRM A<R, 10 - 4.00" I -14-1/2" PARKER SWS NIP, 10 = 3.813" I -14-1/2" PARKER SWN NIP, 10 - 3.725" I -14-1/2" TBG, 12.6#, L-80, ,0152 bpf, 10 = 3.958" -14.1/2" WLEG, 10 = 3.995" I H ELM) IT LOGGEO 06109/96 I I 10964' 10971' 10975' 10976' 10969' 11020' FISH - 1-1/16" X 3" FBS NOSE LOCK (4/13198) COrvfV1ENTS PRUD-iOE SAY UNIT WB...L: M-30A ÆRMTNo: 2011470 API No: 50-029-20102-01 SEe 1, T11N, R12E, 2878' SNL & 605' WB... BP EKploration (Alaska) . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc · STATE OF ALASKA I AlA~ Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS o D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 8. Property Designation: 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Intermediate Production Liner Liner Liner Perforation depth: 44.54 KB ADL-028260 measured 12600 true vertical 8668.9 measured 12566 true vertical 8676.45 Length 80 2288 2262 10246 853 450 1907 Size 30" Conductor 18-5/8" 96.5# K-55 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 3-1/2" 9.3# L-80 2-7/8" 6.16# L-80 Measured depth: 12420 - 12470 True Vertical depth: 8704.08 - 8696.3 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic feet feet feet feet MD 22 - 102 21 - 2309 21 - 2283 19 - 10265 9710 - 10563 10243 - 10693 10693 - 12600 12510- 12560 8688.59 - 8677.78 7" 26# ..--........--- 9-5/8" TIW PIN Packer 7" Baker SABL-3 Packer 7" Top Packer 5.59" Baker Top Packer SCANNEr) 13. Treatment descriptions including volumes used and final pressure: Oil-Bbl o o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Contact Sharmaine Vestal x Stimulate D ! '.Qt~W i.' Waiver D Time Extension D Re-enter Suspended Well D 5. PerIT1i.\,~pri~ Number: 2\f1::t1:Ði W' 6. API Number: 50-029-20102-01-00 9. Well Name and Number: Exploratory Service 10. Field/Pool(s): Field/ Pool Plugs (measured) Junk (measured) TVD 22 " 102 21 - 2308.93 21 - 2282.93 19 - 8339.08 7887.19 - 8592.13 8320.45 - 8685.91 8685.91 - 8668.9 NT-80S M-03A None None Burst Collapse 930 5380 6870 8160 10160 13450 870 2670 4760 7020 10530 13890 17-9710 2281 9612 9748 10243 9 2 ~ dJ RBDMS 8FL NOV 03 2005 Tubing pressure o 80 Service W Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 6725 0 15. Well Class after proposed work: Exploratory 0 Development 16. Well Status after proposed work: Oil 0 Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ W WDSPl 0 Signat Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 I ¡ ¡ t...- Date 10/28/2005 Submit Original Only N e e M-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I.C1l!lhWP.~" .cë ··.·"'k':~ 'it' .SII1MÑlÄAv f"~ii ". "'1i"" ',"1 10/6/2005 *** WELL SHUT IN ON ARRIVAL *** PULLED 7" BAKER WRP FROM 772' (SLM), PULLED 41/2" XX-PLUG FROM SSSV INSERT @ 2014' (SLM). *** WELL LEFT SHUT IN AND TURNED OVER TO DSO *** FLUIDS PUMPED BBLS I o TOTAL MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~~ fl\q~<6 DATE: Monday, October 24,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC M-03A PRUDHOE SAY UNIT M-03A ./' 'd.,O\ - \Lt FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: Pol. Suprv 3g.~ Comm Well Name: PRUDHOE BAY UNIT M-03A Insp Num: mitCS051015171222 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-20102-01-00 Permit Number: 201-147-0 Inspector Name: Chuck Scheve Inspection Date: 10/1512005 Well M-03A IType Inj. P.T. 2011470 iTypeTest Interval 4YRTST P/F Notes Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. N TVD 7806 I IA 1 -..-- 80 I 2500 2480 I 2480 I .-------+--. I SPT Test psi 1951.5 I OA o I 0 0 0 P Tubing 750 I 750 750 750 __..~'R ~CANNE[~ NO\} 1 ,. 2005 Monday, October 24,2005 Page 1 of 1 .. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONST 052004 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Name: 3. Address: 4. Current Well Class: Development 0 Stratigraphic 0 9. Well Name and Number: M-03A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory 0 Service ŒJ Alaska Oil ~~J1~ons. Commission T. E An rage Ime xtenslon Re-enter Suspended Well 0 5. Permit to Drill Number: . 201-1470 6. API Number 50-029-20102-01-00 Repair Well 0 Pluç PerforationsD Pull TubingD Perforate New Pool 0 Operation Shutdown 0 Perforate 0 Stimulate 00 WaiverD BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 44.54 8. Property Designation: ADL-0028260 11. Present Well Condition Summary: Total Depth measured 12600 feet true vertical 8668.9 feet Plugs (measured) Junk (measured) None Effective Depth measured 12566 feet true vertical 8676.5 feet None Casing Length Size MD TVD Burst Collapse Conductor 80 30" Conductor 22 - 102 22.0 - 102.0 Intermediate 2268 13-3/8" 72# L-80 19 - 2287 19.0 - 2286.9 4930 2670 Liner 853 7" 29# L-80 9710 - 10563 7887.2 - 8592.1 8160 7020 Liner 450 3-1/2" 9.3# L-80 10243 - 10693 8320.5 - 8685.9 10160 10530 Liner 1907 2-7/8" 6.16# L-80 10693 - 12600 8685.9 - 8668.9 13450 13890 Production 10246 9-5/8" 47# L-80 19 - 10265 19.0 - 8339.1 6870 4760 Surface 2288 18-5/8" 96.5# K-55 21 - 2309 21.0 - 2308.9 930 870 Perforation deDth: Measured depth: 12420 -12470,12510 -12560 True vertical depth: 8704.08 - 8696.3,8688.59 - 8677.78 Tubing ( size, grade, and measured depth): 7" 26# NT80S @ 17 9710 Packers & SSSV (type & measured depth): 5.59" Baker Liner Top Packer 7" Baker SABL-3 Packer 7" Liner Top Packer 9-5/8" TIW PIN Packer @ 10243 @ 9612 @ 9748 @ 2281 13 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12420 -12560 Treatment descriptions including volumes used and final pressure: 61 Bbls 7.5% HCL, 58 Bbls 9-1 Mud Acid @ 1160 psig ReDresentative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure -1 0 500 0 -3497 340 Prior to well operation: Subsequent to operation: Oil-Bbl 0 0 Tubing Pressure 2925 1272 14. Attachments: Copies of Logs and Surveys run - Daily Report of Well Operations - ! 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: OilD GasD Development 0 SeNiceŒJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature 1:f~ Co~ S~REÐROOëfd ~~iOO4 WAG ŒI GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 304-251 Title Production Technical Assistant hftel 564-4657 On, G" \ N/\ L ", .,:~,:,'1,V1(~¡Wrl ~ \ I r4~~)'AÂ@) c P - Date 9/30/04 m;~ ~j ij ~~:: M-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/06/04 CTU #5, FCO/ACID; CONT FROM WSR 8/05/04... THAW HYDRATES IN TREE. RIH WITH BAKER 4" HYD. GS SPEAR. LATCH AND POOH WITH ISSSV. RIH WITH 211 JSN CIRCULATING 50/50 METHANOL. TAGGED HARD BOTTOM AT 12535' CTMD WITH CLEAN PU AT 125291 CTMD. COULD NOT PENETRATE DEEPER. FLUID PACK WELL W/50/50 MEOH AND CIRC BOTTOMS UP W/ 1% KCL. PUMP ACID TREATMENT AS PER PROGRAM (60 BBLS 7.5% HCL / 58 BBLS 9-1 MUD ACID / 123 BBLS NH4CL OVERFLUSH). INITIAL TREATMENT PRESSURE = 2080 PSIG @ 1.0 BPM. FINAL TREATMENT PRESSURE = 165 PSIG @ 1.0 BPM. POOH. BBLS 417 25 212 383 149 61 58 1305 FLUIDS PUMPED 50/50 Methanal Neet Methanal 1 % XS KCL 1 % KCL NH4CL 7.5% HCL 9/1 Mud Acid TOTAL SCANNED OCT 0 9 2004 Page 1 TREE = 7-1/16" 5M CIW WELLI-EA D = 5M WCEVOY AClUATOR= OTIS KB. ELEV -;---------¡¡.54' BF. EL-EV ';_'____0__- 27.84' -", ------! KOP= ~-~- 3000', Max ~~Ie =, 1 O~-@ 12600~ Datum M)= 11034' Datum 1V 6'= . 8"700' S8 113-318" CSG, 72#, L-80, ID = 12.347" H 2283' I 118-518" CSG, 96.5#, K-55, ID = 17.655" H 2309' ~ Minimum ID = 2.372" @ 10693' 3-1/2" X 2-7/8" LN R XO 19-518" X 7" TIW LNR f-K3R H 9753' 1 13-1/2" LNR, 8.8#, L-80, .0087 bpf, ID = 2.992" H 19-518" CSG, 47#, L-80, ID = 8.681" H 1 BKR aBP (SET ON 08102/01) H 10255' I 10265' I 10600' PERFORATION SUI\tIv1A RY REF LOG: SWS-BHCS ON 09/15171 ANGLEATTOPPERF: 31 @ 10688' I\bte: Refer to A"oduetion DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA. TE 2:' 4 12420 -12470 0 08/17/01 2" 4 12510-12560 0 08/17/01 1 FBlD H 11227' 1 1 T' LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 11350' 1 ~ 11362' 1 DATE 10/19/77 12/31/90 08/17/01 04122/01 08113/01 08/07/04 co I\tIv1ENTS ORIGINAL COM PLETION JQ RWO CIi'KAK CTDSIDETRACK Rl\Vtlh CORREeTONS ?fTLP ADD WHIPSTOCK AND aBP BMeL/lLP PERF CORRECTION REV BY DA TE REV BY SCANNED OCT 0 9 2004 M-03A :8 "' :8: ~ . 8 ~ / ~ ~ . I 1 rl ~~ z ~ ~ I .-., . CO I\tIv18'JTS SAFETY NOTES: WELL> 70° @ 10750' AND> 90° @ 11065', 2029' H7" OTISSSSV LAI\ÐII\G I\QP,ID =5.962:' 1 2281' H13-3I8" X 9-5/8" 1lW RN R<R I 2287' H 13-318" X 9-5/8" XO 1 9612' H9-5I8" X 7" BKR SABL PKR I IWI K-LA Ta-t, ID = 6.00" H7" OTIS R NIP, ID = 5.963" I H7" TBG, 26#, NT-80-S, .0383 bpf, ID = 6.276" I HTOPOFTIW FBR,ID = 7.375" I H7" 1lW BTM SEAL ASSY W/O SEALS, D = 6.187" I H9-5I8" X 7" TIW LNR TOP PKR 1 H5.59" BKR LNR TOP R<R, ID= 2.39" I H5.90" BKRDER.OY SLV, ID =3.00" I 7" MILLOur WINDOW - 10563' -1 0570' TOP OF WHIPSTOCK - 10560' RA TAG -10570' 9664' 9708' 9710' 9715' 9748' 10243' H3-1/2:' X 2-7/8" LNRXO, ID=2.372" I I ~ ~ 1 PBlD H 12566' I 12-7/8" LNR, 6.4#, L-80, .0058 bpf, D = 2.372" H 12600' 1 1 10877 H7" llW HBBP-R REf R<R, ID = 4.00" I 1 10896' H7" rv\ð.RKERJOINT 1 I 10956' H7" 1lW HBBP ÆRM R<R, ID = 4.00" I 1 10964' 1 H4-1/2" PARKER SWS NIP, ID = 3.813" I H4-1/2" PARKER SWN NIP, ID= 3.725" I H4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I H4-1/2" WLEG, ID = 3.995" 1 HELM) TT LOGGED 06109/96 1 10971' . 10975' 1 10976' 1 10969' 1 11020' H FISH - 1-1/16" X 3" FBS NOSE LOa< (4/13/98) I PRUDHOE SAY UNIT We.L: M-30A ÆRMT No: 2011470 API No: 50-029-20102-01 SEe 1, T11 N, R12E, 2878' SNL & 605' We. BP Exploration (Alaska) \;--J L-¡ It- '7/ 2-/2.004- . ,- I/C/J 7(6/a ( STATE OF ALASKA ( l'- ALASKA OIL AND GAS CONSERVATION COMMISSION ~;~~=,(~E ~\/E~D APPLICATION FOR SUNDRY APPROVAL JUL 0 ,! '>004""""" 20 AAC 25.280 ' 1 L 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 44.54 KB 8. Property Designation: ADL-028260 11. Total Depth MD (ft): 12600 Casing Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: ", '" "I rìï! 0, ;'.,,:, f' -'-,' ~, "",.",:"(':,,, PerforateD !,. ¡ a~> 'W~¡JèfE;r--~ ~~~~~.~ ~i~p&säro ~ StimulateŒ) / Time ExtensionD'" .. "'-'" OtherD Re-enter Suspended WellD 5. Permit to Drill Number: 201-1470 _// Development 0 Exploratory 0 6. API Number ,,/ 50-029-20102-01-00 Stratigraphic 0 Service I]] / 9. Well Name and Number: M-03A .../ 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY IEffective Depth MD (ft): Effective Depth TVD (ft): 12566 8631.9 Size MD TVD Plugs (md): Junk (md): None None Burst Collapse I Total Depth TVD (ft): 8668.9 Length Conductor 80 Intermediate 2261 Liner 853 Liner 450 Lin~ 19~ Production 10239 Surface 2282 Perforation Depth MD (ft): 12420 - 12470 12510 - 12560 Packers and SSSV Type: 5.59" Baker Liner Top Packer 7" Baker SABL-3 Packer 7" Liner Top Packer 9-5/8" TIW PIN Packer 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program Œ] BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 30" Conductor 13-3/8" 72# L-80 7" 29# L-80 3-1/211 9.3# L-80 2-7/8" 6.16# L-80 9-5/811 47# L-80 18-5/8" 96.5# K-55 Perforation Depth TVD (ft): 8704.08 - 8696.3 8688.59 - 8677.8 top bottom top bottom 28 - 108 28.0 - 108.0 26 - 2287 26.0 - 2286.9 4930 2670 9710 - 10563 7887.2 - 8592.1 8160 7020 10243 - 10693 8320.5 - 8685.9 10160 10530 10693 12600 8685.9 8668.9 13450 13890 26 10265 26.0 8339.1 6870 4760 27 2309 27.0 2308.9 930 870 Tubing Size: Tubing Grade: Tubing MD (ft): 7 " 26 # NT-80S 25 - 9710 July 14, 2004 Packers and SSSV MD (ft): 10243 9612 9748 2281 Date: 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D GasD WAG D GINJO ServiceŒ] /' PluggedD AbandonedD WINJ~ / WDSPLD Prepared by Sharmaine Copeland 564-4424. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Katrina Cooper Title Phone Petroleum Engineer 564-4212 6/30/04 Printed Name Signature Katrina Cooper ~ ÚrflA Commission Use Only I Sundry Number: .3oJf .. ;;.s-/ Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity Test D Location Clearance D D Other: Form 10-403 Revised 06/2004 JUl 0" 7 100~ RBOMSBFl ~0 r BY ORDER OF I) THE COMMISSION Date: 7- SUBMIT IN DUPLICATE ~/ nQ'G1~'AI- bp .,. ,\1'.'11. -......~ ~...- ~..- ~..-- ...~ ~~.. .'1'.11'"& ". { ( ( To: Doug Cismoski/J ohn Smart GPB Well Ops Team Leaders Date: June 25, 2004 From: Trina Cooper M - Pad Engineer Paul Bartel Wells Engineer SubjectM-03Ai FCO and Mud Acid PBMPDWL03-C Est. Cost: $60M lOR: 400 BOPD Please pull the ISSSV, drift, perform an injectivity test, and perform a FCO/mud acid stimulation if necessary in injector M-03Ai. It is currently locked up since its last MI cycle. ,/ 1. 2. 3. S 0 C Pull ISSSV. Drift and tag. Injectivity test FCO. Mud acid. Current Status: Deviation: Min. ID: Last TD tag: Last Downhole Ops: Latest H2S value: ~nject~r. Shut-in and freeze protected. . Jùst completing MI slug at 4000 mscfpd at 3250 pSI. After FCO put on PW injection at 4000 bwpd (estimated 1500 psi) / 103 degrees at 12,600' md ' 2.372"at 10,693' md at the 3-1/2" X 2-7/8" LNXO 11/07/01: 12,560' CTMD. 10/3/2003: SBG. 12/10/02: Set ISSSV. Injector, beware of the potential for H2S in the returns. M-03Ai is a WAG injector that recently locked up and has locked up in the past. Also the well was not able to take its full MI target rate during the last MI cycle. The purpose of this program is to // return M-03Ai to normal WAG injection leaving the well injecting 4000 bwpd at an estimated 1500 psi surface pressure. Note: No significant problems occurred during FCO/Step Rate Test/MA stirn performed 9/01. Contact Paul Bartel at x5402, 696-1682 (home) or 240-8036 (cell) or Trina Cooper at x4212, 279- 2667 (home) or 230-4212 (cell) with any questions or comments. cc: w/a: Well File P. Bartel ( (" M-03Ai FCO and Mud Acid Program Prepared By: T. Cooper x4212, 279-2667 (hm), 230-4212 (cell) JOB PLANNING DETAILS: Perfs: 12420' - 12470' 12510' - 12560' Perf Deviation: 100° ISSSV: Installed, 12/1 0102 Gas Lift Design: No Mandrels. MITIA to 4000 passed on 11/8/03. TD Tag History: 11/07/01 CT tag at 12,560' CTMD during IPROP and SRT. Displacement bbls: 406 bbls (tubing = 372, liner to top perf = 34) Injectivity: Expected water injection rate = 4000 bwpd at 1500psi. Coil String Weight: 11/7/01 - 13.5K# @ 9050'. 9/3/01 - PCO/SRT. 21.5# @ 12555'. 22.8#@10922'. Static: No static surveys since sidetracked. Beware of potential H2S in any returns taken at surface! ,// NOTES: 1. Pull ISSSV. Drift the tubing as deep as possible to ensure there are no obstructions. 2. Perform an injectivity test to confirm that the well is still locked up. 3. MIRU CT. RU return line to adjacent well or returns tank. Be aware of the potential for H2S in the returns. 4. MU jetting nozzle. Jet the tubing at maximum rate with slick, filtered 1500P water while RIH. Take returns at surface. 5. Pump minimum rate and tag PBTD for depth control. 6. Circulate bottoms up while reciprocating the coil across the 2-7/8" and 3-1/2" liner up to 1 0,300' md. 7. Pull above the top perfs and check for injectivity with a maximum WHP of 3000 psi. If the perfs are taking fluid then skip to step 8. If the perfs are too tight then pump 10 bbls of 7.5% HCl followed by 10 bbls of 9: 1 mud acid as an attempt to establish injectivity. It may be necessary to ~: take returns in order to stage acid to the nozzle. 8. Make multiple passes across the perfs and pump the following at maximum rate with a recommended maximum WHP of 2000 psi (*). Make one pass to bottom while pumping the overflush. Don't POOH until the entire overflush has been pumped behind pipe in order to reduce the chance of stirring up schmoo. // 25 bbls 3% NH4CI with 10% U-66 and 0.2% F103 50 bbls 7.5% HCl 50 bbls 9% - 1 % HCI-HF 100 bbls 3% NH4CI with 10% U-66 and 0.2% F103 overflush (behind pipe) * Go to 3000 psi during the first half of the HCl stage if necessary to establish injection. Once mud acid is at the perfs the maximum treating pressure should be 2000 psi. All fluids should be filtered to 3 microns. Please note the initial and final injectivity in the WSR summary. Please note the rates and pressures in the WSR when each stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the EXCEL treating report (5 minute readings) to the program author. 9. POOH. At surface perform an injectivity test and note the results in the WSR. RDMO. Immediately put on injection. Treatment Design: -125 bbls 3% NH4Cl water with 10% U-66 and 0.2% F103 60 bbls 7.5% HCI 0.5% A261 0.5% A201 20 ppt L58 0.2% FI03 0.5% W54 0.5% W60 60 bbls 9/1 HCl/HF 0.5% A261 0.5% A201 20 ppt L58 0.2% F103 0.5% W54 0.5% W60 Please note the acid titrations and iron ppm on the WSR. 1/ / 1REE= 7-1/16"5MCIW WELLHEAD = 5MWCEVOY ACluA TOR = OTIS KB. EL8J = 44.54' BF. H.8J = 27.84'- KOP =' 30ÖÖi . n....... . .... ....m.... . fv'ax A I1Qle = 103 <$ 12600', Datum MJ = 11034' Datum 1V 0 = 8700' SS 1 13-3I8"CSG, 72#,L-80, D=12.347' H 2283' M-03A (8 :8 " ~ / ~ 118-5/8" CSG, 96.5#, K-55, 10 = 17.655" H 2309' l,j Minimum ID = 2.372" @ 10693' 3-1/2" X 2-7/8" LNR XO ITOPOFTIWPBR, 10 =7.375" J-I 9710' 19-5/8" X 7" llW LINER HANGER 1-4 15.59" BKR LNR TOP PKR, D= 2.39" 1-1 15.90" BKR DEPLOY SLV, 10 = 3.00" 1-1 19-5/8" CSG, 47#, L-80,ID = 8.681" 1-1 9753' 1 10243' I 10249' 1 10265' 1 1 BKR CIBP (SET ON 08/02/01) H 10600' I PERFORA 1l0N SUMrv\A.RY REF LOG: SWS-BI-CS ON 09/15/71 ANGLE AT TOP PERF: 31 @ 10688' Note: Refer to Production DB for historical perf data SIZE SA= INTERVAL Opn/Sqz DATE 2-7/8" 4 10688-10705 S 12/28/90 3-3/8" 1 10705-10730 0 06/19/91 3-3/8" 4 10745-10790 0 06/19/91 3-3/8" 1 10807-10845 0 01/10/91 3-3/8" 1 10845-10865 S 12/28/90 2-7/8" 1 10884-10945 S 12/28/90 2-7/8" 1 10960-10974 S 12/28/90 2-7/8" 4 10980-11010 S 12/28/90 3-3/8" 4 11010-11020 S 12/28/90 3-3/8" 6 11000-11044 0 10/16/95 3-3/8" 4 11020-11044 0 01/10/91 SIDEfRACK PERFS I 2" 1 4 112420-12470 1 0 1 08/17/01 I 2" 4 12510-12560 0 08/17/01 I FBlD 1-1 17' LNR, 29#, L-80. .0371 bpf, 10 = 6.184" 1-1 [~]-i DAlE 10/19/77 12/31/90 01/23/01 03/16/01 04/22/01 COMMENTS ORlGNAL COMRETlON RWO CONVERfEDTO CANVAS FINAL CORRECllONS REV BY JQ SIS-SL T SIS-CS RN/Øh 11227' 1 11350' 1 11362' 1 1 9612' H9-5/B" X 7" BKR SABL PKR W/ K-LATæ, ID= 6.00"1 1 9664' H7" OTIS R NIP, 10 = 5.963" 1 1 9708' J 1 9715' ~~ 9748' 7' MlLOUTWINDOW -10563' -10570' TOP OF WHIPSTOO< - 10560' RA TAG - 10570' ~ 10693' H3-1/2'X2-7/8"LNRXO,ID=2.372" I I H ~ I PBID H 125~.1 Il 12-7/8" LNR, 6.4#, L-80,.0058 bpf, D = 2.372"1-1 12600' :8: . :8: I ( SA FETY NOTES: WELL> 70 DEG @ 10750' AND> 90 / DEG @ 11065'. 2029' H7" OllS SSSV LANDING NIP, D = 5.962" 1 2281' H 13-3/8" x 9-518" TIW PIN PKR 1 2287' H 13-3/8" x 9-5/8" xo 1 1-17" 18G, 26#. NT80S, .0383 bpf, 10 = 6.276" 1 ~7"llWBTMSEALASSYW/OSEALS, D=6.187" 1 1-49-5/8" X 7' TtN LNR TOP PKR 1 10255' H3-112" LNR, 8.8#, L-80, .0087bpf, 10 = 2.992" 1 z ~ 1 10877' 1-17" llW HBBP-R REf A<R, 10 = 4.00" 1 1 10896' 1-17" rv\A.RKER JOINT 1 Z ~ 1 10956' 1--i7" llW HBBP ÆRM A<R, 10 = 4.00" 1 - 1~ 1 10964' 1--14-1/2" PARKER SWS NIP, 10 = 3.813" 1 - 1 10971' 1-I4-1/2"PARKERSWNNIP,ID=3.725" 1 I 10975' IJ4-1/2"TBG, 12.6#, L-80, .0152 bpf, 10 =3.958" 1 I 1 10976' H 4-1/2" WLEG, 10=3.995" 1 1 10969' 1--1 H.MD TT - LOGGED 06/09/96 I -, I 11020' I~FISH - 1-1/16" x 3" FBS NOSE LOCK (4/13/98) 1 - DA lE REV BY COMMENTS 08/13/01 ?/lP ADD WHIPSTOO< AND CIBP 08/17/01 æ/KAK CTDSIDETRAO< l ~ ~ PRUDHOE BA Y UNIT WELL: M-30A PERMIT No: 201-147 AA No: 50-029-20102-01 2878' SNL & 605' WEL, Sec. 1, T11 N, R12E BP Exploration (Alaska) Permit to Drill 2011470 MD 12600 TVD DATA SUBMITTAL COMPLIANCE REPORT 8/25/2003 Well Name/No. PRUDHOE BAY UNIT M-03A Operator BP EXPLORATION (ALASKA) INC 8669 Completion Dat 8/18/2001 Completion Statu 1WINJ APl No. 50-029-20102-01-00 Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log N_9o Sample N._9o Directional Survey N__9o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt ~____F___~D D Pre Pressure Fr~/ D · -B'"~C' Cn See Notes .~'~D D Te Temperature Ver LIS Verification Ver LIS Verification Cn See Notes (data taken from Logs Portion of Master Well Data Maint) Log Log Name Scale Media Interval Run No Start Stop OH / Dataset CH Received Number Comments Directional Survey Directional Survey Jewelry / Temp Log Directional Survey PB1 Directional Survey PB1 FINAL 1 FINAL 10200 oh 9/27/2001 Directional Survey digital data 12560 Case oh FINAL 9600 12553 OH 1 10200 12560 Case 1 10546 11530 Open FINAL 9600 12553 OH 1 10562 12598 Open FINAL 1 10546 1 10562 FINAL oh 12572 Open 11566 Open oh 12/1/2001 *-'~505 9/27/2001 10/3/2001 12/1/2001 ~1~505 3/20/2002 ~63 10/3/2001 "~74 12/6/2002 9/27/2001 3/20/2002~,"'~0662 12/6/2002 9/27/2001 Directional Survey paper copy 9600-12553 BL, Sepia PB1 9600-12553 Digital Data 11420 ~iital Well Logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity Directional Survey Digital Data 11421 ,,Bl~i'~al Well Logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity PB1 Directional Survey paper copy Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments Permit to Drill 2011470 MD 12600 TVD DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Well Name/No. PRUDHOE BAY UNIT M-03A Operator BP EXPLORATION (ALASKA) INC 8669 Completion Dat 8/18/2001 Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-20102-01-00 UIC Y ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? "~"'/"L-. Analysis ~' Daily History Received? ~/N Formation Tops ~_____)/N Compliance Reviewed By: Date: To-" WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs' M-03A & M-03A PB 1, M-03A: Digital Log Images: 50-029-20102-01 M-03A PB1: Digital Log Images: 50-029-20102-70 July 30,2002 AK-MW-Ill33 1 CD Rom 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 . Date: WELL LOG TRANSMITTAL To: State of Alaska March 15, 2002 Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs M-03A PB1 AK-MW-11133 1 LDWG formatted Disc with verification listing. API#: 50-029-20102-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING. AND RETURNIN'G 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-TechnicaI Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED u,p 20 ,.002 Alaska Oil & Gas Cons. Comm~im~ ,Anchorage WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 15, 2002 MWD Formation Evaluation Logs M-03A, AK-MW-I 1133 1 LDWG formatted Disc with verification listing. API#: 50-029-20102-01l PLEASE ACKNOWLEDGE RECEIPT BY SIGNING. ANI) 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 Center LR2-1 900 'E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed(~~lr~ L~_Oa~ RECEIVED ~JaB~(a Oil & Gas Cons. CommiBe~n bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Tom Maunder, P. E. Petroleum Engineer State of Alaska Oil & Gas Conservation Commision Date: Dec 5, 2001 From: Bryan McLellan Petroleum Engineer BP Exploration, Alaska ,f') ~ '''''> /'\:" ~". t' 1"'" .; \!.\1, !.~.,! ~ l ,... ~- .'. "" ,1' ~:;f ,/1">1 /) ¥ t.. l!."t.. Subject: M-03Ai and M-38Ai Cement Intearitv ~ 4 if()\'-\.~d Tom, d.Q(-\'-\,\ ¡~~./t~'/. .! ¡I"') "..., t"¡ ~ '-' ,:,.' ,I ;' 11.,'" ) .., tI ~ '., I:.. V \1 I ~'"Ma~.f(a {j . .- ,~ 'oJ. ;1 & Ii:,. (', '-l""""O('(' '. 4ncb()ra~~ LommisSi(m Please find enclosed the following 4 logs confirming cement integrity in wells M-03Ai and M- 38Ai. 1) M-38Ai Temperature Pressure Run 2-Sep-01 2) M-38Ai Temperature Pressure Run 10-0ct-01 3) M-03Ai Temp. Log & Jewelry Log Run 10-Sep-01 4) M-03Ai Temperature Pressure Log Run 07-Nov-01 The purpose of running these logs was 1) to confirm cement isolation to the perforated interval and 2) for reservoir surveillance, to observe what portions of the reservoir have already experienced cooling and to observe which perforation intervals are taking fluid. The plan, agreed to by the AOGCC, was to first run a baseline temperature log prior to injection (see enclosed e-mail correspondence). After injecting for approximately 1 month, a temperature warmback log would be run and compared to the baseline temperature log. If fluids are injecting uphole of the perforations via a cement channel, the temp warmback log should clearly indicate this. The baseline temperature log will indicate any temperature anomalies that were caused by other injectors in the area, prior to drilling M-03Ai or M-38Ai. Deviation from the normal procedure of running a wire line conveyed cement bond log through the window was done for the following reasons: 1) A lost circulation zone was experienced while drilling the new injector, uphole of the perforation interval. Therefore, cement integrity in the vertical section above this LC zone is qu~stionable. Good cement is anticipated between the LC zone and the perf intervals, however, a wireline conveyed cement bond log would not be able to reach beyond the lost circulation zone due to the high angle of the wellbore. 2) A coil tubing E-line unit was not in operation on the slope, and obtaining a CTE-line bond log could not be done without considerable expenditure and time. 3) A temperature warm back would be more conclusive about the point of injection than the cement bond log. These logs will also provide valuable information about injector conformance and previously swept zones in the reservoir. The results of the logs suggest that the wells are injecting into the appropriate intervals in the reservoir. There is no cooling uphole of the perfs that can not be explained by the pre- injection temperature baseline. This evidence shows that with some degree of certainty, the perforation intervals are isolated from uphole. These wells have, at the request of the AOGCC, been put on a monthly monitoring list so that the pressure and rate will be reported to the commission on a monthly basis. The purpose of reporting this data is to establish a normal operating envelope, where any deviation from the normal injection conditions could warrant further investigation. This reporting will continue indefinitely until the AOGCC is satisfied that there is no need to continue. If you would like to discuss the results of these logs in person, I would be happy to come to your office at your convenience. Please do not hesitate to call at 564-5516. Sincerely, Bryan McLellan ~~ McLellan, Bryan J From: Sent: To: Subject: Tom Maunder [tom_maunder@admin.state.ak.us] Wednesday, September 05, 2001 3:43 PM McLellan, Bryan J Re: Cement integrity in M-03Ai ~ Card for Tom Maunder Brian, My apologies for not getting this note back sooner. Your proposal is an acceptable method to determine the isolation. I only have 2 recommended changes. 1--1 would prefer that the temperature log be run as near 1 month as practical. 2--Contact Joe Anders and Kevin Yeager to place this well on the monthly monitoring list. This will assure that the rate and injection pressure is monitored and then reported. A graph of the pressure versus rate can be used to develop an operating envelope for the well which can be used as a diagnostic tool to confirm injection performance. Good luck with the testing operation. Please call with any questions. Tom Maunder, PE AOGCC "McLellan, Bryan J" wrote: > Tom, > As we discussed yesterday, BP recently drilled a coil tubing sidetrack > (M-03Ai) from well M-03i in Prudhoe Bay. The results of the cement bond log > in the original well bore are inconclusive, and can not definitively confirm > or deny the presence of good cement above the sidetrack window. > > > > > > > > > > > > > > > > > > > > > > Does the AOGCC approve of the above method for demonstrating cement > isolation in Prudhoe Bay well M-03Ai? > > Thank you, > Bryan McLellan > > Bryan McLellan > BP Exploration, Alaska To confirm cement integrity above the window, we plan to run a baseline temperature log prior to injecting any fluid in the well. We will then establish produced water injection for a period of 1 - 2 months before running a temperature warmback log. If any fluid is injecting above the window, the warmback log will clearly show cooling in the reservoir at the depth of injection. If no cooling is observed uphole of the window, cement integrity will be confirmed and injection will continue. If uphole cooling is observed, remedial action will be taken prior to comencing injection. Note: We are deviating from the normal procedure of running a wireline conveyed cement bond log through the window for two reasons: 1) A lost circulation zone was encountered in the new sidetrack at about 100 feet outside the window, and no cement is expected above that point. Wireline can not go beyond the LCZ because the deviation is too great. 2) We do not currently have a coil tubing e-line unit running, and there are no memory cement bond logging tools on the slope. We therefore can not log past the lost circulation zone with coil tubing. 1 WELL. LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To; State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' doey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR --, Open Hole I I 1 M-O3Ai 1 1/7/01 Res. Eval. CH I I 1 . Mech. CH I '~' Caliper Survey Signed · Print Name: Date · ECE!VED , , E:'SC 'i 2001 Alaska Oil & Gas Cons. Commission Anchorage ProActive Diagnostic Services, Inc., 310 K STREET SuitE 200, AnchoragE, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: _w._.w....W_.l~.gj_~.o_r.y../..o_g:C_O...!3. MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 10, 2001 Camille O. Taylor Chair .,~ ,,,,r3 . BJECT: Mechanical Integrity Tests Tom Maunder ~,' P.I. Supervisor M Pad M-03A. M-38A Jeff Jones PBU Petroleum Inspector PBF NON~ CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI M-03A I Typelni. I S I T.V.D. I 7807 ]Tubing] 1675 ] 1675 ] 1675 I~ I lntervall O P.T.D.] 2011470.Typetest] P ITestpsil 1952 ]Casing] 1000I 2500I 2490] 24901 PIE I__P Notes: Post coil tubin~l workover MIT. WellI M-38A I Typelni. I S ]T.V.D.I~ I Tubing] 750 I 800 1800 I 800 I lntervall O P.T.D.] 2011320 ]Typetest] P I.Testpsi] 2113 I Casingl 40 I 25°°l 2450 ].2450 ] P/F I__P Notes: Post coil tubing workover MIT. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (desCribe in notes) Test's Details Saturday~ November ~ 2001: I traveled to BPX's M Pad in the Prudhoe Bay Field to witness post" coil tubing workover MIT's on wells M-03A and M,38A. The pretest pressures were monitored for 30 minutes and found to be stable. The standard annulus pressure test was then performed with both wells passing the MIT's. , M.I.T.'s performed: 2 Number of Failures: 0_. Attachments: wellbore schematics ( 2 ) Total Time during tests: 2.5 hrs cc: MIT report form 5/12/00 L.G. MIT PBU M-03A,M-38A 11-10-01 JJ.xls 12/2/01 STATE OF ALASKA~ ~' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 201-147 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20102-01 4. Location of well at surface '...' ' '".'.". T~ 9. Unit or Lease Name 2878' SNL, 605' WEL, SEC. 01, T11N, R12E, UM . At top of productive interval ~. ;L~/' ~ yr:kl~,~~ ~ Prudhoe Bay Unit -2~x : 10. Well Number 2043' SNL, 1123' WEL, SEC. 02, T11N, R12E, UM ,:"Y -~~~ M-03Ai . ! 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 = 44.54' ADL 028260 12. Date Spudded8/6/2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'8/14/2001 0/10/2001 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 12600 8669 FTI 12566 8676 FTI [] Yes [] NoI (Nipple) 2O29' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, ROP, EWR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED , , 30" Insulated Conductor Surface 117' 280 sx Cement 18-5/8" 96.5# K-55 Surface 2309' 24,, 3840 sx Permafrosi II ' 13.3/8,,x 9-5/8,, 68# / 47# K-55 / N-80 Surface 10265' 12-1/4" 3078 sx Class 'G' 7" 29# N-80 9710' 10563' 12-1/4" 685 sx Class 'G' 3-1/2. x 2-7/8" 8.8# / 6.16# L-80 10243' 12600' 3-3/4" 167 SX Class 'G' , 24. Perforations open to Production (MD+TVD of Top and ' 25. TUBING RECORD ' Bottom and interval, size and number) ...... ii ..... , ..... SIZE" DEPTH S'E'r,(iMD) ' P'ACK';R SET,(MD)' 2" Gun Diameter, 4 spf 7", 26#,' NT80$ ' 9710' ' 961'2' ' MD TVD MD TVD 12420'- 12470' 8704'-8696' 26. AC~D, FRACTURE, CEMENT 'SQUEEZE, E'rc. 12510' - 12560' 8689' - 8678' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' :reeze Protect with Diesel 27. PRODUCTION TEST 'bate First Production Method of Operation (Flowing, gas lift, etc.) October 11,2001 Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Row Tubing Casing 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 orwater,su mF EJVED..... N01/ 0 '? ?_ 0 0 I Alaska 0il & Gas Cons. Cornmissi0~, Anchorage .~'~. I'".. I _,_ ~ _ _ _ Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Shublik A 10587' 8612' Shublik B 10640' 8652' Shublik C 10675' 8675' Sadlerochit 10699' 8689' NOV 0 ? 2On,t Alas.az, Oil ~ (~,a.~, C~,),~s ,..,, 31'. List of A~achments: Summa~ of Daily Drilling Repo~s, Su~eys ' , ~ 32. I hereby ce~ify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~ ~. Title TechnicalAssiotant Date l['0¢'O/. M-03Ai 201-147 Prepared By Name/Numbec 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 AND 24: if this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL BP EXPLORATION Page 1 of lo Operations Summa Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/5/2001 00:00 - 12:00 12.00 MOB N WAIT PRE Rig to standby at 00:00 from M-24A. Standing by at M-24A waiting on pad prep for M-03A. Wellhouse removed from M-03A at 04:00. Continue standing by. Rig on standby until 12:00 hrs. 12 hours total. 12:00 - 14:30 2.50 MOB P PRE Move rig to M-03AI. Spot rig over well. 14:30 - 16:00 1.50 MOB P PRE ACCEPT RIG AT 14:30 HRS, 08/05/01 ON M-24AI Spot equipment, Rig up berm and spot cuttings tank. 16:00 - 17:00 1.00 BOPSUF.P DECOMP N/U BOP STACK, Grease lock master, wing and swab valves. Well is twinned with M-38 injector. Press tested wing with flowline press of 800 psi. Press tested lateral and closed flowline choke with 800 psi. Well is secured from twinned well with closed lateral, choke and wing valve. 17:00 - 21:30 4.50 BOPSUF.P DECOMP Perform initial BOPE Pressure / Function test. AOGCC Witness waived by Chuck Scheve. Send test report to AOGCC. 21:30 - 22:00 0.50 STWHIP P WEXIT BOP test completed. All passed ok. Hold PJSM with all rig hands. Discuss milling operations, potential for lost circulation, new employees on rig, etc. 22:00 - 23:15 1.25 STVVHIP P WEXIT MU BHA #1, to mill window. Straight D287 motor and 4.0" HS diamond speed mill. 23:15 - 00:00 0.75 S'I'WHIP P WEXIT RIH BHA # 1 8/6/2001 00:00- 01:10 1.17 STWHIP P WEXIT Continue RIH with BHA #1 01:10 - 03:00 1.83 STWHIP P WEXIT :RIH, Tag up at 10590', should be 10563'. Make -27' correction. Up weight = 37klbs. Down wt 20k lbs. Kick on pumps, begin milling window fr 10563'. 03:00 - 04:00 1.00 STVVHIP P WEXIT 03:00 update. 10565.1' milling ahead. Free spin 1100 psi, milling at 1400 psi, 1 for 1 returns. 2.8 bpm, 2700 lbs weight on bit. 04:00 - 05:00 1.00 STWHIP P WEXIT 04:00 update. 10566.2', milling ahead. Milling at 1500 psi, 2.7 bpm, 1 for 1 returns. 3800 lbs weight on bit. 05:00 - 06:00 1.00 S'I'WHIP P WEXIT 05:00 update. 10568.1', milling ahead. Milling at 1520 psi, 2.7 bpm, full returns. 3500 psi weight on bit. 06:00 - 07:30 1.50 STWHIP P WEXIT 06:00 update. 10569.2', milling ahead. Milling at 1470 psi. 2.8 bpm, no losses. 3500 psi weight on bit. 07:30 - 09:00 1.50 STVVHIP P WEXIT 07:30 update. 10570 ft. milling ahead. 2.7 / 2.7 bpm, 1350 :)si. 800 WeB. Exit 7" liner at 10570 ft. Drill fomation to 10572 ft. 09:00 - 11:00 2.00 S'I'WHIP P WEXIT Milling formation. 2.7 / 2.7 bpm, 1400 psi, Mill to 10577 ft. Back ream. Mill formation to 10582 ft. Bottom of window at 10570 ft. Back ream. Swap well to New FIoPro drilling fluid while reaming window. 11:00-13:00 2.00 STWHIP P WEXIT Ream window. Pump New FIoPro. 2.7/2.7bpm, 2100psi. Run thru window with no pump, clean window. TD = 10,582 ft. 13:00 - 15:45 2.75 STWHIP P WEXlT POOH with window milling BHA #1. 15:45 - 16:00 0.25 STWHIP P WEXlT Lay out milling BHA. Mill #1 was 60% worn. In gauge. 16:00 - 16:30 0.50 DRILL P PROD1 SAFETY MEETING. Review well plan and special considerations. Review hazards of M/U MWD BHA. 16:30 - 17:30 1.00 STWHIP P PROD1 M/U Sperry MWD, 1.7 deg motor, and ReRun M09 STC Bit #1. M/U DS CTC and pull / press test. 17:30 - 19:45 2.25 STWHIP P PROD1 RIH with MWD BHA #1. Circ at 0.4 bpm while RIH. 19:45 - 20:00 0.25 STWHIP P PROD1 Stop at flag. Set depth, make -21' correction. Orient to 15R, Printed: 8/21/2001 4:01:10 PM BP EXPLORATION Page 2 or lO Operations Summary Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/6/2001 19:45 - 20:00 0.25 STVVHIP P PROD1 RIH smooth through window. Tag up at 10592', should be 10582', based on last tag on milling run? Set depth to 10582'. 20:00 - 21:00 1.00 STWHIP P PROD1 Begin drilling. Free spin 2600 psi, 2.5 in 2.5 out, 3500 psi drilling, TF 19R. 21:00 - 00:00 3.00 STVVHIP P PROD1 21:00 update. Drilling ahead at 50 fph, 3400 psi drilling, 19R tool face, 34 deg inclination. 1 for I returns. Midnight depth 10660'. 8/7/2001 00:00 - 00:20 0.33 DRILL P PROD1 Drilling ahead from 10660'. Slow drilling. 00:20 - 00:30 0.17 DRILL P PROD1 Wiper trip to shoe from 10667'. 00:30 - 01:00 0.50 DRILL P PROD1 Drilling break at 10670', started getting losses. 2.5 in, 2.2 out. Loosing 20 bbls/hr. Continue drilling, moniter losses. Drilling at 2800 psi, 40 fph. 01:00 - 01:15 0.25 DRILL P PROD1 10678', lost all returns. PUH to see if it heals. 01:15 - 01:30 0.25 DRILL P PROD1 Wait at shoe. Pumping minimum rate. 0.4 in, 0 out. 01:30 - 01:40 0.17 DRILL P PROD1 Never got returns back, RIH and try drilling. 01:40 - 02:40 1.00 DRILL P PROD1 10678' Return to drilling. 2.5 in 2580 psi, 95 fph, 100% losses. Notify town. Drill to 10720' to confirm we are out of the Shublick and into zone 4. Still 100% losses. Drill to 10720'. 02:40 - 04:20 1.67 DRILL N DPRB PROD1 PUH to 10575', pump at minimum rate. Wait on Formaset pill from Deadhorse. 04:20 - 04:40 0.33 DRILL N DPRB PROD1 Safety meeting prior to mixing Formaset pill. 04:40 - 06:05 1.42 DRILL N DPRB PROD1 Continue waiting while pill is mixed. 06:05 - 07:20 1.25 DRILL N DPRB PROD1 Start pumping 32 bbl formaset LCM pill. Chase with mud. Displace at 1.0 bpm for first 20 bbls, no returns, with bit at 10530 ft. Pump 0.5 bpm next 8 bbls, lay in last 4 bbls at 0.5 bpm. Pull to 9500 ft. Park CT. No returns seen while laying Form-A-Set pill. 07:20 - 11:20 4.00 DRILL N DPRB PROD1 Wait 4 hours for Form-A-Set pill to set up. No circ. 11:20-12:30 1.17 DRILL N DPRB PROD1 Circ. with bit at 9500 ft. 1.5bpm, 500psi, No returns after 20 bbls. RIH slow pumping 1.5 bpm, no returns. Pump 50 bbls, no returns. 12:30 - 12:45 0.25 DRILL N DPRB PROD1 Orient to get thru window. 12:45 - 14:00 1.25 DRILL N DPRB PROD1 Pump second Form-A-Set pill. Pump total of 32 bbls. Displace , to bit. Lay in 2bbls from 10720 - 10630 ft, Displace 15 bbls at 1 'bpm, Displace 15 bbls at 0.5 bpm. No returns. POOH to 9500 ft. 14:00- 16:00 2.00 DRILL N DPRB PROD1 POOH. 16:00 - 17:00 1.00 DRILL N DPRB PROD1 Lay out drilling BHA. Flush tools. Bit OK for re-run. 17:00 - 17:30 0.50 DRILL N DPRB PROD1 M/U big hole nozzle, 2 jts PH6 tbg, hyd disc and crc. 17:30 - 19:30 2.00 DRILL N DPRB PROD1 RIH with CMTG BHA. 19:30 - 20:30 1.00 DRILL N DPRB ~PROD1 Pump 80 bbls 35 ppb Icm (mx 2, nut plug & mica) Spot 10 bbls out nozzle. Lay in 1:1 remaining 70 bbls '20:30 - 21:00 0.50 DRILL N DPRB PROD1 Circulate above LCM to "squeeze" pill away. No returns established 21:00 - 21:55 0.92 DRILL N DPRB PROD1 WO LCM to go south 21:55 - 22:35 0.67 DRILL N DPRB PROD1 RIH 1.0 bpm/630 psi @ 50'/min w/well SI displacing LCM to 10600'. No set downs or WHP incr. PUH 37K to 10500' 22:35 - 22:50 0.25 DRILL N DPRB PROD1 Safety mtg re: cmt 22:50 - 23:50 1.00 DRILL N DPRB PROD1 PT DS @ 3500 psi. DS load CT w/5 bbls neat, 40 bbls w/ 20#/bbl aggregate, 5 bbl neat 13.8 ppg bentonitic cement. 'IT 2:30. Displace w/rig mud while RIH 23:50 - 00:00 0.17 DRILL N DPRB PROD1 SI @ choke w/cmt @ noz at 10580'. PUH 2'/min 40K 1.6/340 displacing cement Printed: 8/21/2001 4:01:10 PM BP EXPLORATION Page 3 of lO Operations Summary Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/8/2001 00:00 - 00:30 0.50 DRILL N DPRB PROD1 Continue displ cmt w/mud w/choke closed-no press response. Open choke and displace remaining 20 bbls from 10500'-no returns. PUH to safety 00:30 - 01:30 1.00 DRILL N DPRB PROD1 Park at 10000' and circ at min rate while WOC. Fill pits w/ used mud from CDR 01:30 - 02:00 0.50 DRILL N DPRB PROD1 RIH 2.0 bpm/920 psi 50'/min jetting cmt w/choke closed to 10610'-no press incr. PUH 02:00 - 05:45 3.75 DRILL N DPRB PROD1 Park at 10000' and circ at rain rate while WO LCM 05:45 - 06:55 1.17 DRILL N DPRB PROD1 RIH while pumping 100 bbl LCM pill #2 (coarse nutplug, coarse mica, coarse Mix 2) 2.611250. Close choke w/pill at noz at 10550'. Had 175 psi WHP w/20 bbls out and red rate to 2.0 bpm to hold same 06:55 - 08:00 1.08 DRILL N DPRB PROD1 Open choke and leave remaining 20 bbls in 7" liner while PUH. Partial returns, then none. 08:00 - 12:30 4.50 DRILL N DPRB PROD1 Wait on additonal LCM and bentonite cement. 12:30 - 13:00 0.50 DRILL N DPRB PROD1 Hold pre job safety/tool box mtg. discuss LCM & cement schedule etc. 13:00 - 14:45 1.75 DRILL N DPRB PROD1 Test cement lines to 4000 psi. Pump 60 bbls 40 ppb Icm (nut plug, mica (c), mix 2 (c) in flo vis). Begin mixing cmt. Pump 5 bbls 13.8 neat, 30 - 20ppb agg, 5 neat. Shut in well and squeeze at 1 bpm. Max whp:170 psi. Slowly broke back to 50 psi. 14:45 - 16:00 1.25 DRILL N DPRB ~PROD1 POOH and lay in last 10 bbls cmt 1:1. 60 psi WHP. CIP at 1445. POOH to safety. WHP: 40 psi with no pump. Bled to 22 psi and stabilized for a while. Bled to 0 psi. 16:00 - 18:00 2.00 DRILL N DPRB PROD1 Pump 1 bbl every 30 minutes. No inc in whp. Continue to WOC. Discuss options with town. Test plug @ 1800 hrs to 50 psi and bled off immed 18:00 - 21:50 3.83 DRILL N DPRB PROD1 Pump 1 bbl every 30 min while WO MI/DS to mix Forma Plug II at MI plant 21:50 - 22:10 0.33 DRILL N DPRB PROD1 Comp str 300 psi. RIH jetting from 10000' at 2.5/1300 w! choke shut in and no press response to 10615' and tagged up. PUH 22:10- 23:20 1.17 DRILL N DPRB PROD1 RU DS cementers 23:20- 23:40 0.33 DRILL N DPRB PROD1 Safety mtg re: Forma Plug 23:40 - 00:00 0.33 DRILL N DPRB PROD1 Fin mix Forma Plug 8/9/2001 00:00 - 00:30 0.50 DRILL N DPRB PROD1 DS pump 2 bbl FW. PT DS @ 4000 psi. DS load CT w/20 bbls preflush of FIo Vis pill w/choke open 2.3/1170 00:30- 00:45 0.25 DRILL N DPRB PROD1 Mix accelerator 00:45 - 01:00 0.25 DRILL N DPRB PROD1 DS load CT w/27 bbls Forma Plug 2.2/1470 10.9 ppg 115 deg F. RIH from 10500' 20.3K. Displace with 10 bbls postflush of FIo Vis pill 01:00 - 01:35 0.58 DRILL N DPRB PROD1 Displace with FIo Pro mud 2.0/2580. Red rate to 1.0 bprn/1600 w/FP @ noz @ 10570'. Close choke w/2 bbls out, then PUH l'/min 36.6K. No WHP response after 18 bbls out as c'rP continued to drop due to heavy pill 1.0/1210. Sample in 150 deg HWB is hard @ 0115 hrs 01:35 - 02:00 0.42 DRILL N DPRB PROD1 Open choke w/noz at 10550' 1.0/1150. PUH 34k leaving 9 bbls in liner w/WCTOFP @ 10300' 1.0/900. Continue PUH flushing CT of post flush pill. 02:00 - 02:45 0.75 DRILL N DPRB PROD1 Park at 9780' and wait for FP to set (no pump). Fill pits w/mud 02:45 - 03:05 0.33 DRILL N DPRB PROD1 Press test w/18 bbls and nary a psi increase 03:05 - 04:30 1.42 DRILL N DPRB PROD1 POOH w/tail between legs Printed: 8/21/2001 4:01:10 PM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/9/2001 04:30- 04:50 0.33 DRILL N DPRB PROD1 LD cmt BHA 04:50 - 05:00 0.17 DRILL N DPRB PROD1 Safety mtg re: BHA MU in rain 05:00- 05:45 0.75 DRILL N DPRB PROD1 MU drilling BHA 05:45-06:10 0.42 DRILL N DPRB PROD1 RIH w/ BHA #4 (2.8 deg motor). SHT at 500' and1500' and MWD was on/off 06:10- 06:25 0.25 DRILL N DFAL PROD1 POOH 06:25- 07:00 0.58 DRILL N DFAL PROD1 Change out MWD tool 07:00 - 09:00 2.00 DRILL N DPRB PROD1 RIH with drilling assy. SHT mwd OK 09:00 - 09:30 0.50 DRILL P PROD1 Tag up at 10592'. Orient to 35R. 09:30 - 10:30 1.00 DRILL P PROD1 Ream through open hole at 30R 10:30 - 12:00 1.50 DRILL P PROD1 Drilling. 2.5/3100 psi/15R Averaging 50% mud returns. Drill to 10760'. 30-40 fph. 12:00 - 12:45 0.75 DRILL P PROD1 Drill to 10800'. Swap to SW 12:45 - 13:00 0.25 DRILL P PROD1 Short trip to window. Returns varying from 50 to 100%. 13:00 - 15:00 2.00 DRILL P PROD1 Drill ahead. 2.6/3200/45R 80 to 100% rtns. Complete build at 10870' 15:00 - 16:45 1.75 DRILL P PROD1 POOH for lateral assembly. 16:45 - 17:45 1.00 DRILL P PROD1 OOH. LD mwd, motor & bit. MU 1 deg mtr w/DS49 bit. 17:45-19:45 2.00 DRILL P PROD1 RIH. Shallow test mwd. Ok. Continue RIH. 19:45 - 20:40 0.92 DRILL P PROD1 RIH thru window, clean at 39L. Precautionary ream to TD, full returns 2.4/2600. Set down at 10804' w/TF 180 deg out. Orient to right side. RIH w/45R to TD at 10906' CTD. Corr -36' to 10870'. Wiper to tie-in 20:40 - 21:10 0.50 DRILL I P PROD1 Log tie-in to GR marker and OH logs 2.4/2.1 2450 110R 21:10-21:25 0.25 DRILL P PROD1 Add6.0'. RIH to TD at10880' 21:25 - 21:40 0.25 DRILL P PROD1 Orient to 90R 21:40 - 22:15 0.58 DRILL P PROD1 Drilling 2.4/2450/73R 50-100'/hr w/SW 10880-10910' 22:15 - 23:00 0.75 DRILL P PROD1 Drilling 2.4/2.0 and stacking. PU (rite) and had full retums-SW not carrying cuttings. Start FIo Pro mud 23:00 - 23:40 0.67 DRILL P PROD1 Drilling 2.4/2.3 2950/84R 50'/hr w/60 bbls mud in ann at 10940' 23:40 - 00:00 0.33 DRILL P PROD1 Wiper to window from 10970' 2.4/2.4 2900/90R 8/10/2001 00:00 - 00:15 0.25 DRILL P PROD1 Fin wiper to window 00:15 - 00:45 0.50 DRILL P PROD1 Orient around from 90R 00:45 - 02:00 1.25 DRILL P PROD1 Drilling from 10970' 2.4~2.3 3000 79R 88 deg. Hole displaced back to mud 02:00 - 03:40 1.67 DRILL P PROD1 At 11004' began losing fluid again 2.5/1.6 2960 84R near mapped fault. Drill ahead and losses healed to 0.5 bpm loss for a while 03:40 - 04:50 1.17 DRILL P PROD1 11050' 2.4/1.4 2800 84R 04:50 - 05:15 0.42 DRILL = PROD1 11120' 2.4/1.4 2830 90R Wiper to window. Losses diminished gradually as bit was pulled above 10900' 05:15 - 05:30 0.25 DRILL ~ PROD1 Tie-in to GR marker from 10610' 2.4~2.0 2830 130R 05:30 - 05:50 0.33 DRILL = PROD1 No corr, RIH to TD at 11120' 05:50 - 06:30 0.67 DRILL ~ PROD1 Drilling 2.4~2.0 2840 90R 06:30 - 07:15 0.75 DRILL ~ PROD1 11180' 2.4/2,2 2840 96R Drill to 11220' Stacking out. 07:15 - 07:45 0.50 DRILL ~ PROD1 Short trip to window. Hole smooth. 07:45 - 09:00 1.25 DRILL ~ PROD1 Drilling ahead. 2.4/2850fs/120R 2.4 in/2.2 out. Drilling much ~mproved after wiper. Drill to 11310'. 09:00 - 09:15 0,25 DRILL ~ PROD1 Orient to 100L. Continue slight angle drop in target. Start turn to left. 09:15 - 10:00 0.75 DRILL ~ PROD1 Drilling ahead to 11370' 10:00 - 10:30 0.50 DRILL ~ PROD1 Short trip to window. Hole smooth. 10:30- 13:15 2.75 DRILL ~ PROD1 Drilling. 2.6/3100fs/129L 2.6 in/2.4 out Smooth drilling Printed: 8/21/2001 4:01:10 PM BP EXPLORATION Page 5 of 10 Operations Summa Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/10/2001 10:30- 13:15 2.75 DRILL P PROD1 60-80fph. Drillto 11490'. 13:15 - 14:00 0.75 DRILL P PROD1 Short trip to window. Hole smooth. 14:00 - 14:30 0.50 DRILL P PROD1 Orient to 55L 14:30 - 16:00 1.50 DRILL P PROD1 Drill ahead. Apparent formation change. Reactive torque varying, ROP slowed. Drill to 11550' TF:30L Plowed into Shublik 16:00 - 16:45 0.75 DRILL P PROD1 Orient to 135L 16:45 - 18:45 2.00 DRILL N DPRB PROD1 Attempt to drill ahead. Hanging up in formation and / or balled bit. Work pipe & pump. Short trip 200'. Try again and no go. Hole extremley unstable. Wiper to window. Discuss sidetrack options with town. 18:45 - 19:10 0.42 DRILL N DPRB PROD1 Tie-in 2.4~2.3 2940 19:10-21:10 2.00 STKOH N DPRB PROD1 Add5.0'. Flagatl0500'EOP. POOH to change BHA 21:10 - 22:30 1.33 STKOH N DPRB PROD1 Change out bit, motor, orientor, MWD probe. LD shock sub 22:30 - 00:00 1.50 STKOH N DPRB PROD1 RIH w/BHA #6 (1.37 deg motor/M09X) 8/11/2001 00:00 - 00:45 0.75 STKOH N DPRB PROD1 Continue to RIH. 00:45 - 01:20 0.58 STKOH N DFAL PROD1 Corr-34' at flag. Tie-in to GR marker 2.4~2.2 2780 104L. Work w/MWD tool (on-off prob) and get it working 01:20 - 02:10 0.83 STKOH N DFAL PROD1 No corr. Orient to drilled TF and 0/17 w/clicks. Downtime starts at 0130 hrs 02:10- 03:45 1.58 STKOH N DFAL PROD1 POOH to change orientor 03:45 - 04:35 0.83 STKOH N DFAL PROD1 Change out orientor for the last one layed down. Check MWD tool, bit, motor 04:35 - 06:10 1.58 STKOH N DFAL PROD1 RIH/w BHA #6RR. SHT MWD, ok. Chk orientor at 3000' and 5000' (nope) while wo CDR's backup orientor to arrive. Watch a herd of 27 Musk Ox graze about 300 yds away near the Kuparuk River 06:10 - 06:45 0.58 STKOH N DFAL PROD1 POOH to change orientor 06:45 - 07:45 1.00 STKOH N DFAL PROD1 Change out orienter. Inspect rest of BHA. 07:45- 09:30 1.75: STKOH N DFAL PROD1 RIH. Test mwd & orienter at 3000'. Ok. Continue RIH. End downtime @ 0930 hrs 09:30 - 09:45 0.25 STKOH N DPRB PROD1 Log gr tie in at 10610' bit depth. Add 3' correction. 09:45 - 10:00 0.25 STKOH N DPRB PROD1 RIH below kick off point. Work through tight hole outside window. 10:00 - 10:15 0.25 STKOH N DPRB PROD1 Orient to 160L. 10:15 - 12:30 2.25 STKOH N DPRB PROD1 Flag pipe at 11150' on down stroke. Begin time back reaming to trough Iow side from 11150'. (1 fpm to 11125'). tf:168L Repeat pass. 18k# dn wt. 2.5/3200psi fs. Repeat up/down pass to 11140'. 12:30 - 14:00 1.50 STKOH N DPRB PROD1 Begin time drilling at 11148' (on down stroke) tf:168L. 0.05' ~per minute. Appear to be stacking weight (differential ?) Drill ~to 11153, but stacked weight. 14:00-14:45 0.75 STKOH N DPRB PROD1 PUl0'. RIH. Time drill again from11150', at 0.1' per ft (twice rate as before) Drill to 11153'. Not stacking any wt, slight mtr work. 14:45-15:15 0.50 STKOH N DPRB PROD1 Reduce time drill rate to 0.1' per 2 min. Drillto11154.8' No weight or motor work. 15:15-16:00 0.75 STKOH N DPRB PROD1 Increase drill rate to 0.1' per minute. Drillto11160'. 16:00 - 16:45 0.75 STKOH N DPRB PROD1 Increase time drill rate to 0.2' per minute. Drill to 11165'. Stacking weight. Appear to be diff stuck. 16:45-17:30 0.75 STKOH N DPRB PROD1 PUl0'. RIH to11163' Resume time drilling at 0.2' per min. Time drill (again) to 11165'. Diff stuck again. PU. 17:30-18:00 0.50 STKOH N DPRB PROD1 Time drill ahead at 0.3 fpm from11163'. 2.6 bpm/ 3120 psi fs. Printed: 8/21/2001 4:01:10 PM BP EXPLORATION Page 6 of 10 Operations Summa Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/11/2001 17:30 - 18:00 0.50 STKOH N DPRB IPROD1 tf:163L. 50-100 psi mtrwork. Drilling off smoothly. 18:00 - 18:15 0.25 STKOH N DPRB PROD1 Continue drilling sidetrack at 11175' at 0.5 fpm. Inc dropping compared to original hole. Drill to 11180'. 18:15 - 19:30 1.25 STKOH N DPRB PROD1 Back ream to 11120'. One more ream to TD 19:30 - 22:45 3.25 DRILL N DPRB PROD1 Drill 10' from 11180-90' 2.5/2.2 3100 174L. Then, orient and drill ahead adjusting TF to depart left and drop to 8725' TVD by 11500' I 22:45 - 23:10 0.42 DRILL N DPRB I pROD1 Drill to 11283' 2.6~2.2 3150 80L @ 82 deg. Wiper to window 23:10 - 23:25 0.25 DRILL N DPRB ' PROD1 Orient around below window 23:25 - 23:40 0.25 DRILL N DPRB PROD1 RIH 2.5/2.3 3080 119R to 11130' 23:40-00:00 0.33 DRILL N DPRB PROD1 Orient to 157L. RIHtoTD, clean andtag at 118Lat 11283' 8/12/2001 00:00 - 03:45 3.75 DRILL N DPRB :PROD1 Drill from 11283-360' 2.6~2.2 3370 at 84-50L TF. MWD detection began deteriorating from 11300'. Stop often to get surveys and G Totals are too out of range to continue. Last good survey at 11275' 03:45 - 04:20 0.58 DRILL N DPRB . PROD1 Wiper to window and had good G Totals 04:20 - 04:35 0.25 DRILL N DPRB PROD1 Tie-in from 10605'. No corr. Flag at 10500' EOP 04:35 - 06:15 1.67 DRILL N DPRB i pROD1 POOH for bit and MWD probe 06:15 - 07:00 0.75 DRILL N DPRB ;PROD1 Change bit, mwd, motor. Test motor at surface: very rough. 07:00 - 12:00 5.00 BOPSUF P 'PROD1 Weekly test BOPE. Witness waived by J. Crisp, AOGCC. 12:00 - 12:45 0.75 DRILL N DPRB ~PROD1 MU lateral assembly (1.04 deg mtr w/DS49). 12:45 - 15:00 2.25 DRILL N DPRB PROD1 RIH. Slit mwd good. Continue in hole. Shublik a little rough from 10680' to 10700'. 15:00- 15:15 0.25 DRILL N DPRB PROD1 Orient to 35R. 15:15 - 15:45 0.50 DRILL N DPRB PROD1 Drill ahead at 11360'. 2.413100 psi fs/16R-40R 2.4bpm in/2.2bpm out. Drill to 11400'. 32k# up, 18k# dn wt. 15:45 - 16:15 0.50 DRILL N DPRB PROD1 Orient to 90R. Drill ahead to 11440'. 90-120fph. 16:15 - 16:30 0.25 DRILL N DPRB PROD1 Orient to 35R 16:30 - 17:30 1.00 DRILL N DPRB PROD1 Drill ahead. 2.6/3400fs/45R. Drill to 11504' 17:30 - 18:30 1.00 DRILL N DPRB PROD1 Short trip to window. Hole & sidetrack very smooth. Tag TD @ 11504' 18:30 - 21:00 2.50 DRILL N DPRB PROD1 Orient to 84R w/multiple trys while drilling to 11566'. Orientor clicks off btm, but doesn't seem to lock and climbs back to previous TF 21:00 - 21:30 0.50 DRILL P PROD1 Orient around 21:30 - 23:50 2.33 DRILL P PROD1 Drilling again and seems to be holding TF. Drill from 11566-11692' 2.6/2.3 3350 80-90R 23:50 - 00:00 0.17 DRILL P PROD1 Wiper to window 8/13/2001 00:00 - 00:35 0.58 DRILL P PROD1 Wiper to window 00:35 - 00:45 0.17 DRILL P PROD1 Tie-in 2.7/2.4 3350 100R 00:45-01:30 0.75 DRILL P PROD1 Add 3.0', RIH. Orient from 78Rto 164Lto enter OH#2. RIH to TD at 11692' 01:30 - 01:45 0.25 DRILL P PROD1 Orient to left side 01:45 - 04:10 2.42 DRILL P PROD1 Drilling 2.6~2.2 3350 90L 04:10 - 05:45 1.58 DRILL P PROD1 Drill to 11852'. Wiper to window. Clean to TD 05:45 - 06:35 0.83 DRILL P PROD1 Orient to right side while drilling a few feet. Getting 70 deg reactive 06:35 - 08:00 1.42 DRILL P PROD1 Drilling ahead TF:50R Drill to 11964'. 8727' TVD @ 11906' MD 08:00 - 09:30 1.50 DRILL P PROD1 Short trip to window. Hole smooth. 09:30 - 10:00 0.50 DRILL P PROD1 Re-orient to 15L to start climb to final target from 11964' 10:00 - 10:30 0.50 DRILL P PROD1 Drilling. 2.5/3000 fs/15L 35k# up, 17k# dn wt Slow drilling Drill to 11980' Printed: 8/21/2001 4:01:IOPM BP EXPLORATION Page 7 of 10 Operations Summa Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/13/2001 10:30- 11:15 0.75 DRILL P PROD1 Orient to 90L 11:15 - 13:00 1.75 DRILL P PROD1 Drilling ahead to 12050' Tf:90L. 13:00 - 13:30 0.50 DRILL P PROD1 Drill to 12060'. Weight transfer getting tough. 13:30 - 14:00 0.50 DRILL N RREP PROD1 Repair orienting choke. 14:00 - 15:00 1.00 DRILL P PROD1 Drill to 12090'. In and out of shale stringers, very slow drilling. Tf:80L 15:00 - 15:30 0.50 DRILL P PROD1 Drill to 12104'. 15:30 - 16:45 1.25 DRILL P PROD1 Short trip to window. Hole smooth. 16:45 - 17:00 0.25 DRILL P PROD1 Orient to 90L 17:00 - 18:50 1.83 DRILL P PROD1 Drilling ahead 12104-12156' 2.4/2.1 2950 68L @ 97 deg and tough to make hole due to invert 18:50 - 19:30 0.67 DRILL P PROD1 500' wiper while wo vac trk w/higher lubetx % (delayed by 2ES move) 19:30 - 19:45 0.25 DRILL P PROD1 Back to 'rD and can't drill. Start new mud while backream slow 19:45 - 20:05 0.33 DRILL N STUC PROD1 Temporarily immobile at 12030' bit depth (prob diff stuck BHA in shale at 11985', had minor overpull earlier). Park and fin cir¢ new mud to bit 20:05 - 20:35 0.50 DRILL N STUC PROD1 After 10 bbls out, work free in down mode (uphill). Then work free in up mode. Wiper thru 11970-90' had considerable motor work backreaming. Got bit stuck for a bit... Wiper to 11850'. RIH, clean 20:35 - 22:00 1.42 DRILL P PROD1 Drilling-love new mud. 2.6/2.3 3300 85L 80-100'/hr. Drill to 12220' (8690' TVD) 22:00 - 22:55 0.92 DRILL P PROD1 Wiper to window, clean 22:55 - 23:10 0.25 DRILL P PROD1 Tie-in 2.4/2.1 2980 95R 23:10 - 00:00 0.83 DRILL P PROD1 Add 7.0', RIH. Orient to go in OH #2 8/14/2001 00:00 - 00:30 0.50 DRILL P PROD1 Fin wiper to TD. Set down at 11900'? w/Iow side TF. Orient high side, RIH 00:30 - 00:50 0.33 DRILL P PROD1 Tag TD at 12225'. Orient 00:50 - 02:00 1.17 DRILL P PROD1 Drilling 2.5~2.2 3150 85L 40-70'/hr w/2-5K. At 12240' had a few stalls and GR indicated a 20' shale (last fault?) 02:00 - 03:00 1.00 DRILL P PROD1 Drilling at 12285' 20-70'/hr w/-8k and 200 psi diff holding 98 deg at 8680' TVD. 03:00 - 04:40 1.67 DRILL P PROD1 Drill to 12322' 2.4/2.1 3100 85L when Sam sat down and blinked at -8k and couldn't get back to drilling. Wiper to window, clean 04:40 - 05:15 0.58 DRILL P PROD1 Set down at 11984' at 90R. Orient around to drilled TF. RIH to TD. Orient around 05:15 - 07:30 2.25 DRILL P PROD1 Drilling 2.6~2.3 3280 97L. Drill from 12322-12414' 07:30 - 08:00 0.50 DRILL P PROD1 Short trip to 12000'. 08:00 - 08:30 0.50 DRILL P PROD1 Drill to 12427'. Stacking out. 08:30 - 10:00 1.50 DRILL P PROD1 Short trip to window. Orient to get past OH sidetrack. Hole smooth. 10:00 - 10:30 0.50 DRILL P PROD1 Orient to resume build. TF:75L 10:30 - 11:30 1.00 DRILL P PROD1 Drill ahead to 12500'. 2.5/3200 FS/75L 35k# up, 15k# dn wt. 80 fph with new mud coming around OH coil. 11:30 - 12:30 1.00 DRILL P PROD1 Drill ahead to 12545'. 12:30 - 13:30 1.00 DRILL P PROD1 Short trip to window. Hole smooth. 13:30 - 13:45 0.25 DRILL P PROD1 Log gr tie-in. Add 5' correction. 13:45 - 15:00 1.25 DRILL P PROD1 Continue short trip. RIH. 15:00 - 16:40 1.67 DRILL P PROD1 Resume drilliing. 16:40 - 19:00 2.33 DRILL P PROD1 TD well at 12600', POOH to pick up resistivity tool. 19:00 - 21:05 2.08 DRILL P PROD1 Change MWD probe, add resistivity tool. Upload res tool, PT Printed: 8/21/2001 4:01:10 PM BP EXPLORATION Page 8 of 10 Operations Summa Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/14/2001 19:00 - 21:05 2.08 DRILL P PROD1 kill line chk valve 21:05 - 23:00 1.92 DRILL P PROD1 RIH w/BHA #9 23:00 - 23:25 0.42 DRILL P PROD1 Corr -34' at 10654'. Tie-in to RA tag 2.5/2.1 3030 164R 23:25 - 00:00 0.58 DRILL P PROD1 Add 8.5', RIH precautionary reaming 8/15/2001 00:00 - 00:45 0.75 DRILL P PROD1 I Fin precautionary ream to TD, clean. 17k @ 30'/min. Tag at 12593' 00:45 - 03:00 2.25 DRILL P PROD1 PUH 34k 2.0/1.6 2350 63R logging MAD pass at 900'/hr. Leave fresh mud in btm 800' of hole 03:00 - 03:20 0.33 DRILL P PROD1 Relog tie-in, add 1.5'. Flag at 10200' EOP 03:20 - 05:15 1.92 DRILL P PROD1 POOH for liner 05:15 - 06:00 0.75 DRILL P PROD1 LD drilling BHA 06:00 - 07:00 1.00 DRILL P PROD1 Download resistivity data. Showed TD is at 12604' tied into OH logs 07:00 - 07:45 0.75 DRILL P PROD1 Top off well, standby to observe fluid loss. 07:45 - 08:15 0.50 DRILL P PROD1 Top offwell again at 07:45. Took 6 bbls to top off. Well still itaking fluid at a rate of 12 bbls/hr static. Wait on Baker hand. 08:15 - 08:35 0.33 DRILL P PROD1 :Baker on location, hold PJSM prior to running liner. 2 BOT, 5 I rig hands, 2 DS, 1 BP. 08:35 - 12:30 3.92 CASE P COMP MU liner BHA. Displacement kept the hole full with MU liner. 12:30 - 13:00 0.50 CASE P COMP Fill last 1/3 of liner. 13:00 - 14:00 1.00 CASE P COMP !Make up Baker deployment eq. 14:00 - 15:00 1.00 CASE P COMP Pick up injector. 15:00 - 16:35 1.58 CASE P COMP RIH with 2-7/8" x 3-1/2" tapered liner string. BHA length=2359.82'. 16:35 - 17:20 0.75 CASE P COMP 10500', weight check up=42klbs, RIH weight=26 klbs. RIH in open hole. Set down at 12020', pick up clean at 42klbs. RIH, set down at 12049', fell through. RIH set down at 12307', PU clean, RIH to 12417' PU clean, RIH to 12445' PU clean, RIH to flag. Make -33' correction. Tag bottom at 10595', pickup at 44klbs, set down again at 10595.7'. 17:20 - 18:00 0.67 CASE P ~COMP Position reel to drop ball. Drop 5/8" ball to release from running tool. Reposition reel at TD. Tagged up at 12594'. Circulate ball with mud, pumping at 2.4 bpm. Drop to minimum rate at 30 bbls away, in 0.7 bpm, out 0.3 bpm. Land ball with 44 bbls away (coil vo1=59.7), Got good indication of shear at 4000 psi (2800 psi over min rate). Pick up to confirm free of liner. 18:00 - 18:40 0.67 CASE P COMP Standby for changeout. 18:40 - 18:55 0.25 CASE P COMP Safety mtg re: cmt 18:55 - 19:20 0.42 CASE P COMP Batch mix cmt 19:20 - 20:00 0.67 CASE P COMP DS pump 2 bbls FW. PT 4000. Load CT w/34 bbls 15.8 ppg G cmt w/Latex 2.7/2.3 3000. Load wiper dart and check 20:00 - 20:25 0.42 CASE P COMP Displace w/KCI water 2.8/2.4 2500 after catching fluid. 2.8/2.5 2600 when first cmt at wiper plug. 2.9/2.5 3100 when cmt @ shoe. 2.5/2.2 3250 at 58.5 bbls at plug. 2.5/2.1 3230 before latchup at calc displ and press to 2200 psi. Had 5 extra bbls (over top) return. Unsting, chk floats 20:25 - 21:00 0.58 CASE P COMP PUH to 10100' and circ 0.5/0.2 360. Same loss rate, WOC 30 min. RIH jetting 2.5/2.2 2100 to TOL 21:00 - 21:20 0.33 CASE P COMP Begin displacement to KCI 21:20 - 00:00 2.67 CASE P COMP POOH 3.0/2.6 2300 and fin displ. Noted 30 bbls of 9.0-9.6 ppg cmt returns 8/16/2001 00:00 - 00:30 0.50 CASE P COMP LD liner running tool Printed: 8/21/2001 4:01:10 PM BP EXPLORATION Page 9 of 10 Operations Summa Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/16/2001 00:30 - 01:00 0.50 CASE P COMP Safety mtg re: CSH. MU 2.3" mill, 2.125" motor, MHA 01:00 - 02:30 1.50 CASE P COMP MU 39 stds CSH workstring 02:30 - 04:00 1.50 CASE P COMP RIH w/BHA #10 04:00 - 04:55 0.92 CASE P COMP 10200' 32k, 18k Comp str=1000 psi. Start motor 1.5/1.2 2150 and RIH thru TOL, clean. RIH to PBD 19k at 12500' 04:55 - 06:40 1.75 CASE P COMP Tag PBD at 12579' CTD twice. POOH 1.5/1.2 2520 36k 06:40 - 07:00 0.33 CASE P COMP Stop at top of CSH. Prior to breaking off well, establish loss rate. With chokes open, pumping down CSH, thru motor at 0.9 bpm, returns were 0.5. Appear to be loosing 0.4 bpm. 07:00 - 07:30 0.50 CASE P COMP Tag up at top of CSH work string. Stand back injector. 07:30 - 07:45 0.25 CASE P COMP Safety meeting prior to standing back CS hydrill work string. Covered CSH, the plan forward for the well, new employee safety, H2S, etc. 07:45 - 08:50 1.08 CASE P COMP Stand back CS hydrill work string. 08:50 - 15:00 6.17 CASE P COMP Waiting on Baker Oil Tools to get liner top packer together. 15:00 - 16:00 1.00 CASE P COMP Rigup Baker Model D permanant liner top packer with J hydraulic setting tool. 16:00 - 17:50 1.83 CASE P COMP RIH with Liner top packer and seal assembly. Seal had a mule shoe profile on bottom. 17:50 - 18:45 0.92 CASE P COMP Weight check up at 10200'=33klbs. RIH, tag up at 10275' CTM. No depth correction made. Last correction made on liner run was -33'. Top of liner left at 10249' ELM. PU 10' to drop ball. RIH again, tag up again at 10275', same depth. Set an additional 10klbs down on no go. Chase ball with KCL at 2.9 bpm in, getting 2.7 bpm back. Pump 35 bbls, drop rate to 0.7 bpm, continue to pump. Ball on seat at 44.7 bbls, press to 1500 psi. Verify seals stung in, go to neutral wt. Press CT to 3280 psi where ball seat sheared. PUH and verify 1/1 returns. PT at 1480 psi for 3 rain, no loss 18:45 - 20:10 1.42 CASE P COMP POOH. Top of LTP is at 10243' ELMD 20:10 - 20:30 0.33 CASE P COMP LD Baker running tool 20:30 - 20:50 0.33 CASE P COMP Safety mtg re: hi press. RU HB&R to IA and PT. 20:50 - 21:50 1.00 CASE P COMP Pressure tubing to 1500 psi w/KCI water in hole w/3.4 bbls. Pressure IA to 1500 psi w/2.6 bbls diesel. Pressure tubing to 3010 psi w/rise in IA to 1675 psi for 30 min and chart. Final pressures were 3003 psi on injection tubing string and 1644 psi on IA. Bleed off tubing to 1500 psi. Bleed off IA to 100 psi, then tubing to zero. 21:50 - 22:05 0.25 CASE P COMP MU side jet nozzle on 2 jts PH6 22:05 - 00:00 1.92 CASE P COMP RIH jetting KCL water while adding w/FRW-14 3.3 bpm 3050. Jet wash tubing of drilled solids, LCM and mung 8/17/2001 00:00 - 00:10 0.17 CASE P COMP Fin RIH jet washing tubing of mung and drilled solids. Tag LTP @ 10263' CTD 00:10 - 02:10 2.00 CASE P COMP POOH 4.0~2720 at 90%. Load guns in pipeshed 02:10 - 02:30 0.33 CASE P COMP LD jetting BHA. Recovered about a barrel each of cuttings and mung 02:30 - 02:40 0.17 CASE P COMP Safety mtg re: perf guns 02:40 - 03:20 0.67 PERF P COMP MU 154' SWS 2" perf gun assy 03:20 - 04:30 1.17 PERF P COMP MU 37 stds CSH 04:30 - 06:10 1.67 PERF P COMP RIH w/CT 06:10 - 07:30 1.33 PERF N DPRB COMP Set down at 10543' CTD. Work it easy to try to get down-nope. PUH dragging 15' and had 18k over pull before coming free. POOH w/CT Printed: 8/21/2001 4:01:10 PM BP EXPLORATION Page lO of 10 Operations Sumrna Report Legal Well Name: M-03 Common Well Name: M-03A Spud Date: 8/6/1971 Event Name: REENTER+COMPLETE Start: 8/3/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/17/2001 107:30 - 08:00 0.50 PERF N DPRB COMP Stand back injector. 08:00 - 08:15 0.25 PERF N DPRB COMP Safety meeting prior to pulling CS hydrill work string. 08:15 - 09:15 1.00 PERF N DPRB COMP Trip CS hydrill 09:15 - 09:30 0.25 PERF N DPRB COMP Safety meeting prior to laying down guns/picking up motor and mill. 09:30 - 10:00 0.50 PERF N DPRB COMP Lay down guns. (Unfired ok) 10:00 - 10:15 0.25 PERF ,N DPRB COMP PU Baker 2.30" DSM, motor, jars. BHA #14. 10:15 - 11:15 1.00 PERF N DPRB COMP MU CS hydril work string. 11:15 - 11:30 0.25 PERF ;N DPRB COMP MU injector. 11:30 - 12:50 1.33 PERF N DPRB COMP RIH with BHA#11. 12:50 - 14:30 1.67 PERF N DPRB COMP Weight check prior to entering liner at 10200'=31klbs. Free spin 1.8 bpm, 3050 psi. RIH did not see any obstructions or motor work at liner top or at 10550', where the perf guns tagged up. Continue RIH. Tag up at 12578' CTM. Landing collar at 12565' ELM. PU tag a 2nd time at same depth. Hard tag, clean PU. 14:30 - 15:25 0.92 PERF N DPRB COMP Pump 15 bbls 2# biozan sweep, 5 bbl spacer of used KCL, followed by Lithium Chlorite bleach. Chase with KCL from pits. 15:25 - 16:00 0.58 PERF N DPRB COMP POOH laying in bleach. 16:00 - 16:20 0.33 PERF N DPRB COMP Tag up while POOH at 10279' CTM. Hung up several times. unable to move down hole, can't pull up Attempt down jarring. Not getting aggressive with down weight on jars due to CS hydrill in hole. Appear to be bit stuck. Also appear to be packed off. CTP will not bleed down. Finally worked it and popped free. Definatly something in the hole. 16:20 - 17:00 0.67 PERF N DPRB COMP Run back in the hole with pumps on. RIH to 10725', below 2-7~8 by 3-1/2" crossover. Standby, pump 15 bbls 2# biozan at 1.8 bpm. 17:00 - 17:45 0.75 PERF N DPRB COMP PUH, pumping at 1.8 bpm, chasing 2# sweep. Make it up through liner top ok. RIH to tag TD again. 17:45 - 18:30 0.75 PERF N DPRB COMP RIH, did not tag anything again. Circulate clean KCL to bit. 18:30 - 21:00 2.50 PERF N DPRB COMP Tag PBD again. Leave fresh KCl water in linerwhile POOH pumping at max rate. Liner is clean. Drop ¢irc sub ball at TOE POOH at max pump rate disposing of bleach to tiger tank 21:00 - 22:15 1.25 PERF N DPRB COMP Standback CSH. LD milling assy 22:15 - 22:25 0.17 PERF N DPRB COMP Safety mtg re: perf guns 22:25 - 23:05 0.67 PERF N DPRB COMP MU 154' SWS 2" pen" gun assy 23:05 - 00:00 0.92 PERF N DPRB COMP MU 37 stds CSH 8/18/2001 00:00 - 02:20 2.33 PERF N DPRB COMP RIH w/CT and pen" gun assy 02:20 - 02:40 0.33 PERF P COMP Tag PBD at 12576' CTD. PUH. WO vac truck w/bleach 02:40 - 02:50 0.17 PERF P COMP Safety mtg re: bleach 02:50 - 04:15 1.42 PERF P COMP RU vac trk. Load CT w/20 bbls bleach followed by KCl water. Load 5/8" steel ball. Displace w/KCl and landed at calc displ. Fired guns at 3280 psi. Good indication of firing. Lost 1 bbl of fluid Perforated 12420-470' and 12510-560' w/SWS 2" HSD PJ 2006 @ 6 spf 04:15 - 0.00 PERF IP COMP POOH filling from BS Printed: 812112001 4:01:10 PM Well: M-03Ai Rig Accept: 08/05/01 Field: Prudhoe Bay Rig Spud: 08/06/01 APl: 50-029-20102-01 Rig Release: 08/18/01 Permit: 201-147 Drilling Rig: Nordic 1 POST - RIG WORK 08/30101 Drift liner to 10692' wlmd. 09/02/01 Make up memory tools. Run in hole, taking returns to tiger tank. Can't get into 2-7/8" liner. Try pumping, with no luck. Pull out of hole. Prep for FCO. Tools covered in heavy mung and iron shavings. Make up motor and mill assembly. 09/03/01 Run in hole with 2.30" mill. Encounter obstruction at 10722', mill through. Continue running in hole, milling to TD of 12577' ctmd. Circulate and pull out of hole. Run in hole with 2" JSN. 09104101 Run in hole jetting 2-7/8" liner. Change wellbore over to filtered 2% KCL. Perform max rate injectivity test. Decide to proceed with mud acid job. Pump 350 bbls, no distinct break seen. 09/05101 Pull out of hole. Freeze protect tubing with 50/50 MeOH to 2200'. 09/06/01 MITIA to 2500 psi, passed. 09/10101 Log hole with PDS Memory logging tools (temperature, pressure). 26-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well M-03A PB1 Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,500.00' MD Window / Kickoff Survey: 10,562.00' MD Projected Survey: 11,566.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP ?- 7 ?_001 Naska Oil & Gas Cons. Oommissior, Anct~orage DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_ WOA M Pad, Slot M-03 M-03- M-O3A PB1 Job No. AKMW11133, Surveyed: 14 August, 2001 SURVEY REPORT 26 September, 2001 Your Ref: API500292010270 Surface Coordinates: 5973478.05 N, 628227.32 E (70° 20' 08.7946" N, 148° 57' 34.7308" W) Kelly Bushing: 44.54ft above Mean Sea Level I:1 R'I L L-I N l] SER ,VIC:t~ A Halliburton Company Survey Ref: svy10936 Sperry-Sun Drilling Services Survey Report for M-03 - M-O3A PB1 Your Ref: API500292010270 Job No. AKMW11133, Surveyed: 14 August, 2001 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10500.00 32,330 297.000 8494.26 8538.80 10562.00 32.020 298.240 8546.74 8591.28 10581.90 35.240 298.840 8563.31 8607.85 10610.70 39.730 299.780 8586.15 8630.69 10642.30 45.880 300.780 8609.33 8653.87 10681.50 53.350 302.020 8634.71 8679.25 10711.10 60.140 302.960 8650.93 8695.47 10740.50 65.570 301.050 8664.34 8708.88 10773.70 72.600 303.330 8676.19 8720.73 10804.30 77.960 306.150 8683.96 8728.50 10854.66 84.110 314.230 8691.82 8736.36 10885.66 86.310 319.510 8694.41 8738.95 10916.06 87.540 323.200 8696.04 8740.58 10944.66 87.710 326.190 8697.22 8741.76 10973.86 87.450 330.050 8698.46 8743.00 11005.26 88.680 333.920 8699.52 8744.06 11034.46 89.560 338.490 8699.97 8744.51 11064.66 90.260 342.010 8700.01 8744.55 11105.26 90.610 347.460 8699.71 8744.25 11138.46 91.410 352.550 8699.12 8743.66 11172.26 92.110 357.300 8698.08 8742.62 11216.26 92.460 5.560 8696.32 8740.86 11257.86 90.440 8.730 8695.27 8739.81 11298.06 88.240 13.820 8695.73 8740.27 11327.46 87.980 11.540 8696.70 8741.24 11358.66 89.120 6.970 8697.49 -8742.03 11402.66 88.590 0.640 8698.37 8742.91 11433.06 87.450 357,300 8699.42 8743.96 11471.46 85.780 354.490 8701.69 8746.23 11516.86 84.810 352,380 8705.42 8749.96 Local Coordinates Global Coordinates Northings Eestings Northings Eastings (ft) (ft) (ft) (ft) 770.84S 4794.39W 5972625.35 N 623446.81E 755.54 S 4823.64 W 5972640.15 N 623417.30 E 750.27 S 4833.32 W 5972645.25 N 623407.53 E 741.69 $ 4648.60 W 5972653.57 N 623392.11 E 730.86 $ 4867.13 W 5972664.08 N 623373.40 E 715.29 S 4892.58 W 5972679.21 N 623347.68 E 702.00 S 4913.45 W 5972692.14 N 623326.59 E 688.15 S 4935.63 W 5972705.61 N 623304.18 E 671.63 $ 4961.85 W 5972721.68 N 623277.68 E 654.76 S 4986.15 W 5972738.13 N 623253.09 E 622.68 S 5024.08W 5972769.56 N 623214.62 E 600.15 S 5045.19W 5972791.73N 623193.13 E 576.44S 5064.14W 5972815.11 N 623173.77 E 553.12 $ 5080.65W 5972838.14 N 623156.87 E 528.35S 5096.06W 5972862.64N 623141.04 E 500.66 S 5110.80W 5972890.08 N 623125.83 E 473.95 S 5122.57W 5972916.59 N 623113.60 E 445.53 S 5132.78W 5972944.83N 623102.91 E 406.38 S 5143.46W 5972963.79 N 623091.56 E 373.70 $ 5149.22W 5973016.37 N 623085.24 E 340.06 S 5152.21W 5973049.95 N 623081.68 E 296.14 S 5151.11W 5973093.88 N 623082.02 E 254.89 $ 5145.94W 5973135.22 N 623086.49 E 215.48 S 5138.08W 5973174.75N 623093.67 E 186.81 $ 5131.64W 5973203.52 N 623099.63 E 156.04 S 5126.62W 5973234.38 N 623104.12 E 112.17 S 5123.70W 5973278.29 N 623106.28 E 81.80 $ 5124.25W 5973308.65 N 623105.22 E 43.57 S 5126.99W 5973346.83N 623101.82 E 1.38 N 5132.16W 5973391.68 N 623095.88 E Dogleg Rate (°/100ft) 1.176 16.267 15.716 19.580 19.207 23.092 19.352 22.123 19.652 20.001 18.396 12.778 10.462 13.237 12.925 15.936 11.884 13.451 15.517 14.198 18.775 9.O33 13.792 7.801 15.092 14.434 11.603 8.501 5.101 Alaska Drilling & Wells PBU_WOA M Pad Vertical Section Comment 1729.63 1757.51 1766.91 1781.98 1800.62 1826.83 1848.77 1871.86 1899.28 1926.03 1972.78 2002.85 2032.86 2061.31 2090.46 2121.82 2150,84 2180.55 2219.80 2250.98 2281.61 2319.09 2352.23 2382.43 2404.03 2428.18 2464.71 2491.29 2525.77 2567.28 Tie on point MWD Magnetic Window Point 26 September, 2001 - 10:15 ~' Page 2 of 4 DrillQ~est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for M-03 - M-O3A PB1 Your Ref: API500292010270 Job No. AKMW11133, Surveyed: 14 August, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth '(ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 11566.00 84.810 352.380 8709.86 8754.40 49.89 N 5138.65 W 5973440.07 N 623088.57 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.441° (06-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 330.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11566.00ft., The Bottom Hole Displacement is 5138.90ft., in the Direction of 270.556° (True). Dogleg Rate (°/100fi) 0.000 Alaska Drilling & Wells PBU_WOA M Pad Vertical Section Comment 2612.53 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (fi) (fi) (ft) 10500.00 8538.80 770.84 S 4794.39 W 10562.00 8591.28 755.54 S 4823.64 W 11566.00 8754.40 49.89 N 5138.65 W Comment Tie on point Window Point Projected Survey 26 September, 2001 - 10:15 Page 3 of 4 DrillQuest 2. 00. 08. 005 Sperry-Sun Drilling Services Survey Report for M-03 - M-O3A PB1 Your Ref: API500292010270 Job No. AKMW11133, Surveyed: 14 August, 2001 North Slope Alaska Alaska Drilling & Wells PBU_WOA M Pad Survey tool program for M-03 - M-O3A PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (fi) (ft) (ft) 0.00 0.00 10500.00 8538.80 10500.00 8538.80 11566.00 8754.40 Survey Tool Description AK-2 BP_CG (M-03) MWD Magnetic (M-O3A PB1) 26 September, 2001 - 10:15 Page 4 of 4 DrillQuest 2.00.08.005 26-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well M-03A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,138.46' MD Window / Kickoff Survey: 11,150.00' MD Projected Survey: 12,598.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED SEP 2. 7 2001 Alaska Oil & Gas Cons, Commi~o~ Anchorage Attachment(s) DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_ WOA M Pad, Slot M-03 M-O3A Job No. AKMW11133, SURVEY REPORT 26 September, 2001 Your Ref: AP1500292010201 Surface Coordinates: 5973478.05 N, 628227.32 E (70° 20' 08.7946" N, Kelly Bushing: 44.54ft above Mean Sea Level 148° 57' 34. 7308" W) DRILLINI~ A Halliburton Company Survey Ref: svy10955 Sperry-Sun Drilling Services. Survey Report for M-O3A Your Ref: APl 500292010201 Job No. AKMW11133, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth m) Vertical Local Coordinates Global Coordinates Depth Northings Eastlngs Northlngs Eastings (ft) (ft) (ft) (ft) (ft) 11138.46 91.410 352.550 8699.12 8743.66 11150.00 91.690 354.350 8698.81 8743.35 11181.02 85.430 353.080 8699.59 8744.13 11213.22 81.650 350.090 8703.21 8747.75 11246.62 82.440 344.470 8707.84 8752.38 11274.82 84.190 338.210 8711.12 8755.66 11298.02 82.000 334.1 O0 8713.91 8758.45 11321.22 80.860 333.040 8717.37 8761.91 11353.29 83.320 326.360 8721.79 8766.33 11398.69 87.100 330.930 8725.58 8770.12 11441.69 86.480 334.450 8727.99 8772.53 11473.49 89.300 337.610 8729.16 8773.70 11509.69 91.860 340.990 8728.79 8773.33 11543.29 92.550 344.470 8727.50 8772.04 11579.89 91.760 347.630 8726.12 8770.66 11616.09 91.760 352.200 8725.01 8769.55 11653.69 91.320 357.300 8724.00 8768.54 11673.89 90.950 359.950 8723.60 8768.14 11708.49 88.860 355.540 8723.66 8768.20 11741.69 88.330 351.670 8724.47 8769.01 11770.69 89.300 348.330 8725.07 8769.61 11805.29 89.120 344.120 8725.55 8770.09 11847.69 87.890 342.010 8726.65 8771.19 11906.49 90.930 344.930 8727.26 8771.80 11935.29 92.990 344.120 8726.27 8770.81 11969.69 97.290 343.940 8723.19 8767.73 11997.49 99.050 340.420 8719.24 -8763.78 12027.29 97.910 336.910 8714.85 8759.39 12064.49 97.120 335.330 8709.98 8754.52 12099.09 96.770 330.760 8705.79 8750.33 373.70S 5149.22W 5973016.37 N 623085.24 E 362.24 $ 5150.54W 5973027.80 N 623083.73 E 331.43S 5153.93W 5973058.55N 623079.81 E 299.79 S 5158.61W 5973090.10 N 623074.59 E 267.53 S 5165.89W 5973122.23 N 623066.76 E 241.01S 5174.85W 5973148.59 N 623057.35 E 219.95 S 5184.15W 5973169.49 N 623047.68 E 199.41 $ 5194.37W 5973189.86 N 623037.12 E 172.01S 5210.39W 5973216.98 N 623020.64 E 133.39 $ 5233.91W 5973255.19 N 622996.45 E 95.25 S 5253.61W 5973292.99 N 622976.11 E 66.21S 5266.51W 5973321.80 N 622962.71 E 32.36 S 5279.31W 5973355.43 N 622949.34E 0.30 $ 5289.27W 5973387.31 N 622938.83E 35.19 N 5298.09W 5973422.64 N 622929.41 E 70.80 N 5304.42W 5973458.15 N 622922.46 E 108.22 N 5307.86W 5973495.50 N 622918.39 E 128.41 N 5308.34W 5973515.67 N 622917.56 E 162.97 N 5309.70W 5973550.21 N 622915.60 E 195.95 N 5313.40W 5973583.12 N 622911.35 E 224.49 N 5318.43W 5973611.58 N 622905.82 E 258.09 N 5326.67W 5973645.02 N 622897.02 E 298.63 N 5339.02W 5973685.35 N 622883.98 E 354.99 N 5355.74W 5973741.41N 622866.29 E 382.72 N 5363.42W 5973769.02 N 622858.14 E 415.66 N 5372.84W 5973801,78 N 622848.15 E 441.85 N 5381.26W 5973827.83 N 622839.29 E 469.30 N 5391.98W 5973855.09 N 622828.10 E 503.02 N 5406.91W 5973888.55 N 622812.60 E 533.63 N 5422.48W 5973918.88 N 622796.51 E Dogleg Rate (°/lOOff) 15.780 20.591 14.930 16.831 22.903 19.959 6.675 22.009 13.035 8.299 13.313 11.712 10.551 8.894 12.618 13.609 13.243 14.104 11.762 11.991 12.178 5.759 7.168 7.685 12.511 14.041 12.262 4.716 13.150 Alaska Drilling & Wells PBU_WOA M Pad Vertical Section Comment 2250.98 Tie On Point 2261.56 Window Point 2289.94 2319.68 2351.25 2378.70 2401.59 2424.49 2456.23 2501.44 2544.32 2575.91 2611.63 2644.37 2679.52 2713.53 2747.65 2765.37 2795.99 2826.39 2853.63 2886.85 2928.13 2985.30 3013.16 3046.39 3O73.28 3102.42 3139.09 3173.37 26 September, 2001 - 10:18 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for M-O3A Your Ref: AP1 500292010201 Job No. AKMW11133, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local cOOrdinates Global Coordinates Depth Depth Northings Easting$ Northlngs Eastlngs (ft) (ft) (fi) (ft) (ft) (ft) 12129.69 97.210 327.590 8702.07 8746.61 559.71 N 5438.04 W 5973944.69 N 622780.50 E 12161.89 97.290 324.430 8698.03 8742.54 586.19 N 5455.90 W 5973970.87 N 622762.20 E 12193.89 98.000 322.320 8693.75 8738.29 611.64 N 5474.81 W 5973995.99 N 622742.85 E 12223.49 98.440 320.390 8689.51 8734.05 634.52 N 5493.11 W 5974018.55 N 622724.17 E 12252.49 98.700 317.400 8685.19 8729.73 656.12 N 5511.96 W 5974039.83 N 622704.95 E 12287.89 99.320 314.230 8679.65 8724.19 681.19 N 5536.32 W 5974064.48 N 622680.16 E 12322.69 99.400 310.890 8673.99 8718.53 704.41 N 5561.61 W 5974087.27 N 622654.48 E 12347.89 99.050 308.430 8669.95 8714.49 720.29 N 5580.76 W 5974102.81 N 622635.06 E 12380.89 98.520 305.620 8664.90 8709.44 739.92 N 5606.79 W 5974122.00 N 622608.70 E 12415.49 97.380 301.750 8660.12 8704.66 758.92 N 5635.30 W 5974140.51 N 622579.87 E 12446.89 99.050 300.170 8655.63 8700.17 774.91 N 5661.95 W 5974156.04 N 622552.95 E 12480.69 100.810 297.530 8649.80 8694.34 790.97 N 5691.11 W 5974171.60 N 622523.52 E 12517.69 102.130 295.070 8642.44 8686.98 807.04 N 5723.61 W 5974187.11 N 622490.75 E 12549.69 102.630 291.730 8635.53 8680.07 819.45 N 5752.28 W 5974199.03 N 622461.87 E 12579.89 102.830 289.620 8628.82 8673.36 829.84 N 5779.83 W 5974208.95 N 622434.15 E 12598.00 102.830 289.620 8624.80 8669.34 835.77N 5796.46W 5974214.59 N 622417.42 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.423° (26-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 330,000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12598.00ft., The Bottom Hole Displacement is 5856.40ft., in the Direction of 278.205° (True). Dogleg Rate (°/100fi) 10.382 9.738 6.901 6.622 10.235 9.016 9.473 9.735 8.567 11.557 7.286 9.290 7.428 10.423 6.812 0.000 Alaska Drilling & Wells PBU_WOA M Pad Vertical Section Comment 3203.74 3235.60 3267.10 3296.06 3324.20 3358.09 3390.85 3414.17 3444.19 3474.90 3502.07 3530.56 3560.72 3585.80 3608.58 3622.03 Projected Survey 26 September, 2001 - 10:18 Page 3 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for M-O3A Your Ref: AP1 500292010201 Job No. AKMW11133, North Slope Alaska Alaska Drilling & Wells PBU_WOA M Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (fi) (ft) (ft) 11138.46 8743.66 373.70 S 5149.22W 11150.00 8743.35 362.24 S 5150.54W 12598.00 8669.34 835.77N 5796.46W Comment Tie On Point Window Point Projected Survey Survey tool program for M-O3A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (fi) 0.00 0.00 10500.00 8538.80 10500.00 8538.80 12598.00 8669.34 Survey Tool Description AK-2 BP_CG (M-03) MWD Magnetic (M-O3A PB1) 26 September, 2001 - 10:18 Page4of4 DrillQuest 2. 00. 08. 005 LOG TRAiV$/PflTTAL Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole I I 1 M-O3Ai 9/10/01 Res. Eval. CH I I 1 Mech. CH 1 Caliper Survey Name: Date' D 0CT 0 3 2001 Alaska Oi~ & Gas Cons. CommJ~on .Aqchorage ProActive Diagnostic SErvices, Inc., 310 K STREET Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: www.memor~.l~c~_~. ~KA OIL AND GAS CONSERVA~ION C0Pl)IXSSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Cubbon C'][ Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re' Prudhoe Bay Unit M-03Ai BP Exploration (Alaska) Inc. Permit No: 201-147 Sur. Loc. 2878' SNL, 605' WEL, SEC. 01, T1 IN, R12E, UM Btmhole Loc. 2145' SNL, 1087' WEL, SEC. 02, T1 IN, R12E, UM Dear Mr. Cubbon: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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. Annular disposal has nOt been requested as part of the Permit to Drill application for Prudhoe Bay Unit M-03Ai. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of any BOPE tests, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field, inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner BY ORDER OF.THE COMMISSION DATED thisL3rd~ day of August, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory []/Stratigraphic Test [] Development Oil 1 a. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas I"~ingle Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB)' 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 44.50' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028260 4. Location of well at surface '7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2878' SNL, 605' WEL, SEC. 01, T11N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3606' SNL, 200' WEL, SEC. 02, T11 N, R12E, UM M-03Ai Number 2S100302630-277 At total depth 9. Approximate spud date 2145' SNL, 1087' WEL, SEC. 02, T11 N, R12E, UM 09/10/01 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 028257, 2145' MDI No Close Approach 2560 12550' MD / 8641' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10560' MD Maximum Hole Angle 96 ° Maximum surface 2238 psig, At total depth (TVD) 8800' / 3300 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Wei.qht Grade Couplinq Len.qth MD TVD MD TVD (include staqe data) 3-3/4" 3-1/2. x2-7/8. 6.2 / 6.16# L-80 ST-L 2190' 10360' 8376' 12550' 8641' 103 sx Class 'G' D Er' Ih I\[..~.,I.. I ¥ I..U 19. To be completed for Redrill, Re-entry, and Deepen Operations. JUL-I ( .00i Present well condition summary Total depth: measured 11362 feet Plugs (measured) Alaska 0il & Gas Cons. Commission true vertical 9292 feet Anchorage Effective depth: measured 11227 feet Junk (measured) Fish: 1-1/16" x 3" FBS Nose Lock at 11020' (04/98) true vertical 9170 feet Casing Length Size Cemented MD TVD Structural Conductor 100' 30" 280 sx Cement 117' 117' Surface 2292' 18-5/8" 3840 sx Permafrost II 2309' 2309' Intermediate 10248' 13-3/8" x 9-5/8" 3078 sx Class 'G' 10265' 8339' Production Liner 1640' 7" 685 sx Class 'G' 9710' - 11350' 7887' - 9282' Perforation depth: measured Open: 10705' - 10730', 10745' - 10790', 10807' - 10845', 11000' - 11044' Sqzd: 10688' - 10705', 10845' - 11000' true vertical Open: 8713'- 8734', 8747'- 8786', 8801'- 8834', 8969'- 9007' Sqzd: 8699'- 8713', 8834'- 8969' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: John Cubbon,,.~ .~ .~ ~4}'4158 ~- I~,.~.."~ ~o,~ I 5~,~ ' 5 ~,G~, Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the for/~ i~ t~Y'and correct to the best of my knowledge ! , Si~n~ J~hn C~on /~(~/X~/~/ ~itle CT Drillin~ Engineer Date '~/~',~3~// Permit Number / APl Number Approval Date See cover letter ,~-~-P//-- / ~/"~ 50- 029-20102-01 ,, for other requireme,n, ts ,, Conditions of Approval: Samples Required [] Yes I~ No Mud Log Required [] Yes [~"No Hydrogen Sulfide Measures ~ Yes [] No Directional Survey Required l~Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~[~,.5K psi for CTU Other: by order of / Approved By ~J'~v---~ ~'r[-? I r' ~ l\ ! /~% I Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX M-03Ai Sidetrack Summary of Operations: A CTD sidetrack of well M-03Ai will be drilled. Specific preparation work, (Phase 1), and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus, (IA). Drift/caliper liner and set whipstock. Mill window if service coil is available. Planned for August 15, 2001 · Liquid pack and Integrity test IA. · Clean out fill and schmoo with service coil down to 10,975' MD. · Use slickline to drift tubing and liner, and run a caliper across the liner at the proposed whipstock setting depth. · Using slickline or E-line, set a mechanical plug in the 4-1/2" liner at approximately 10,956' MD (8,886' TVDss). · Using E-line, set a 7" through tubing whipstock at approximately 10,560' MD (8,545' TVDss). · Service coil may be used to squeeze cement the perforations between the mechanical plug and the whipstock with 18 bbls of cement. · Mill window with service coil, if available. Phase 2: Drill and Complete CTD sidetrack: Planned for September 10, 2001 2-3/8" coil will be used to drill a ~2000 foot, 3-%" open hole sidetrack, (as per attached plan) and run a solid, cemented & perforated 3-1/2" x 2-7/8" liner completion. Mud Program: · Phase 1: Seawater · Phase 2: FIo-Pro (8.6- 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · A combination 3-1/2" x 2-7/8", L-80, solid liner will be run from approximately 10,360'md (8,376' TVDss) to TD at approx 12,550'md. Liner will be cemented in place with approximately 21 bbls (annular volume plus 25% excess in OH) of 15.8ppg class G cement. Well Control: · 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 preventer will be tested to 400 psi and 2200 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 the open hole section. · A memory CNL will be run inside the liner. Hazards The HaS concentration for M-03i was measured at 70 ppm on 4/7/2001. The well-path will cross 2 mapped faults, the first to be crossed has a throw of about 50 feet and the second has a throw of about 25 feet. The risk of lost circulation from the first fault is considered to be moderate, while the risk from the second fault is considered Iow. Both faults will be crossed by the proposed wellbore perpendicular to their orientation. Reservoir Pressure Res. pressure is estimated to be 3300 psi at 8800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2238 psi. , VVELLHEAD= 5M MCEVOY SAFETY NOTES A Cl'LI~TOR= OTIS M-03 KB. ELEV = 44.54' BF. ELEV: 27.84 KOP=DatumMaX AngleMD = = 51 @10858,5000'3000' ' I ~=- -- -- - ---~ 2029' H 7" OTIS SSSV LA NDING NIP' D = 5'962" I DatumTVDss= 8800' ~ --~ 2281' H13-3/8"x9-5/8"TIWPINPKRI Minimum ID - 3.725" @ 10963' 4-1/2" OTIS SWN NIPPLE ~ 9611' HK-2~ TBG ANCHOR I I I- ._, ^NGLE Al TOPPEF~: 31 @ 10688' Note: Refer to R'oduction ri3 for histodeal porf dataI I SIZE SPFi NTERVAL Opn/Sqz DATE 2-7/8 4 ~ 1088~-10705 s Rwo 1991 3-3/8 1; 10705-10730 0 06/19/91 ! ~ ~ t lo870' ~7"T~VHB~P-..Er~K~D=3.87~'I ;3-3/8 4 1074~10790 0 06/19/91 ~ i 1o884' ~7"~<mjC~.T I 3-3/8 1 10807-10845 O 01/09/91 3-3/8 1 10845-10865 s .w01991 II 2-7/8 1 10884-10945 S RWO 1991 2-7/8 I i 10860-10874 S RWO1991 ~ !~,~1 10946' H7"TIWHBBPFERMPKR, ID=3.87~' I 2-7/8I 4 10980-11010 S RWO 1991 3-3/81 4 11010-11020 S RWO1991 I I I 10956' H4-1/2"OTIS'SWS'NIP, ID=3.813"I 3-3/~' 6 11000-11044 O 10/16/95 · , . o ' '11 I 10969' ~ [~ Tr- I-OGGI~ O610019~I I mmH 11227' ~ 11362' [ DATE REV BY COMMI~ITS DATE PRLDHOEBAY UNIT 08/12/75 i ORIGI~IAL COMR. ETION I ' WELL: ~30 01/01/91 JQ POST RWO ' PERMIT No: 71-0180 01123/01 ~ SIS-SLT CONVERTEDTOCANVAS APl No: 50-029-20102-00 03/16/01 SIS-CS FINAL Sec. 1, T11N, R12E 04/22/01 RN/IJh CORRECTIONS . i BP Exploration (Alaska) SIZE SPF NTERVAL Opn/Sqz DATE 2-7/8 4 10688-10705 S RWO 1991 3-3/8 1 10705-10730 O 06/19/91 3-3/8 4 1074~ 10790 O 06/19/91 3-3/8 1 10807-10845 0 01/09/91 3-3/8 1 10845-10865 $ RWO 1991 2-7/8 1 10884-10945 S RWO 1991 2-7/8 1 10860-10974 $ RWO 1991 2-7/8 4 10980-11010 $ RWO 1991 3-3/8 4 1101 0-11020 S RWO 1991 3-3/~' 6 11000-11044 O 10/16/95 3-3/8" 4 11020-11044 O 01109191 DATE REV BY COMMI~ITS DATE 08/12/75 ORIG HA L COMFLETION 01/01/91 JQ POST RWO 01123/01 SlS-SLT CONVERTEDTOCANVAS 03/16/01 SIS-CS FINAL 04/22/01 RN/IIh CORRECTIONS , 'FREE= 7-1/16" 5M ClW WELLI-"~ D= 5M MCEVOY ACTUATOR= OTIS KB. ELEV = 44.54' BF. ELEV = 27.84' KOP = 3000' Max Angle = 51 @ 5000' Datum MD = 10858' Datum TVDss= 8800' I 13-3/8" CSG, 7Z#, L-80, ID = 12.347" 14 I 18-5/8" CSG, 96.5#, K-55, ID = 17.655" 14 M-03Ai PROPOSED CTD SIDETRACK 2029' ]~7" OTIS SSSV LANDING NIP, ID = 5.962' 2283' 230g' 2281' 14 13-3/8" x 9-5/8" TIW PIN PKR 1 2287' I'-] 13-3/8"x 9-5/8" XO ! 2290' I-I .oc I Minimum ID = 3.725" @ 10963'I 4-1/2" OTIS SWN NIPPLE ITOPOF 7" LNR 14 9710' 17"'I'BG, 26#, NT80S, .0383 bpf, ID=6.276" I--~ 9715' 10265' Top of Proposed 3-1/2" Liner ]---{ 10360'I Mill Window off Mechanical WhiPstock PERFORATION SUMMARY REF LOG: SWS-BHCS, 9/15/71 ANGLE AT TOP PERF: 31 @ 10688' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sq~ DATE 2-7/8 4 10688-10705 S RWO 1991 3-3/8 I 10705-10730 O 06/19/91 3-3/8 4 10745-10790 O 06/19/91 3-3/8 1 10807-10845 O 01/09/91 3-3/8 I 10845-10865 S RWO 1991 2-7/8 I 10884-10945 S RWO 1991 2-7/8 1 10960-10974 S RWO 1991 2-718 4 10980-11010 S RWO 1991 3-3/8 4 11010-11020 S RWO 1991 3-3/8" 6 11000-11044 O 10/16/95 3-3~8" 4 11020-11044 O 01/09/91 4-1/2" 'I-BG, 12.6#, L-80, .0152 bpf, ID = 3.958" 14 10975' 9611' 9612' 9663' 9715' I-~ K-22 TBG ANCHOR ! I-I~-~"x ~"~s^~~~,~=~.o. I 4 7" TIW BTM SEAL ASSY w/o SEALS, ID = 6.18 I2-7/8" Liner, Cemented & Perforated '~ 10620'1-----~ 3-1/2" to 2-7/8" XO I 10870' 10884' 10946' 10956' Set Plug I--]7" T~, HBBP-R RET PKR, ID = 3.875" I I--]4-1/2" otis 'sws' NIP. ID = 3.813" [ 10963' 1"-~4-1/2" OTIS 'SWN' NIP, ID= 3.725" I ~-~-WL~ I 4 ~MO~-~0~ 0~,0~,~ I I 11020' 14FISH- 1-1/16"x 3" FBS NOSELOCK (4/13/98 ] 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ]4 11350' r--~--] 11362, o8/12/751 IOR~GINAL COMFLETION o~o~I ~Q I.OS~RWO 01/23/01 I SIS-SET ICONVERI Id_) TO CANVAS o~o~I s~s-~s i.,~, o4/22/OlI RN/tlh ICORREOTIONS COMMENTS M-03Ai ST Proposed PRUDHOE BAY UNIT WELL: M-30Ai STProposal PERMIT No: 71-0180 APl No: 50-029-20102-01 Sec. 1, T11 N, R12E BP Exploration (Alaska) Obp BP Amoco Baker Hu~hes INTEQ Plannin~ Report INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB M Pad Well: M-03 Wellpath: Plarg~ M-03A Date: 7/212001 Time: 13:59:13 Page: 1 Co-ordinate(NE) Reference: Well: M-03, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,330.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ge# Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2001 Site: PB M Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5971246.37 ft Latitude: 70 19 47.175 N 626262.80 ft Longitude: 148 58 33.196 W North Reference: True Grid Convergence: 0.96 deg Well: M-03 Slot Name: 03 M -03 Well Position: +N/-S 2198.49 ft Northing: 5973478.06 ft Latitude: 70 20 8.795 N +E/-W 2001.96 ft Easting: 628227.32 ft Longitude: 148 57 34.731 W Position Uncertainty: 0.00 ff Wellpath: Plan#6 M-03A Drilled From: M-03 500292010201 Tie-on Depth: 10560.00 ft Current Datum: 4: 03 8/6/1971 00:00 Height 44.50 ft Above System Datum: Mean Sea Level Magnetic Data: 7/2/2001 Declination: 26.50 deg Field Strength: 57480 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 330.00 Plan: Plan #6 Date Composed: 7/2/2001 Identical to Lamar's Plan #6 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets ,'.: ...... ' ........... " . Map . Map '.<~_ Latitude .m> <., Longitude _.> Name.' Description TVD +N/-S +E/-W. . Northing.' Easting '. Dog Min' Sec. Dog Mia SEC!' · ft ...ft .. ft . . ft · ff.. .. M-03A Polygon6.1 0.00 -753.39 -5041.12 5972638.65 623200.22 70 20 1.369 N 149 0 1.937 W -Polygon 1 0.00 -753.39 -5041.12 5972638.65 623200.22 70 20 1.369 N 149 0 1.937 W -Polygon 2 0.00 -188.12 -5346.68 5973198.57 622885.07 70 20 6.926 N 149 0 10.871 W -Polygon 3 0.00 197.95 -5405.19 5973583.55 622819.97 70 20 10.722 N 149 0 12.588 W -Polygon 4 0.00 499.36 -5485.14 5973883.53 622734.88 70 20 13.686 N 149 0 14.929 W -Polygon 5 0.00 637.52 -5967.92 5974013.40 622249.85 70 20 15.041 N 149 0 29.032 W -Polygon 6 0.00 972.50 -5962.28 5974348.40 622249.76 70 20 18.336 N 149 0 28.875 W -Polygon 7 0.00 851.73 -5324.17 5974238.57 622889.79 70 20 17.153 N 149 0 10.235 W -Polygon8 0.00 71.06 -4997.24 5973463.67 623230.00 70 20 9.477 N 149 0 0.671 W -Polygon 9 0.00 -210.02 -4936.95 5973183.68 623295.08 70 20 6.713 N 148 59 58.905 W -Polygon 10 0.00 -568.70 -4722.94 5972828.74 623515.17 70 20 3.187 N 148 59 52.649 W M-03AT6.1 8695.00 102.29 -5151.76 5973492.24 623074.98 70 20 9.783N 149 0 5.184W M-03AT6.2 8675.00 577.15 -5438.95 5973962.08 622779.74 70 20 14.451 N 149 0 13.582 W M-03AT6.3@TD 8640.00 693.44 -5817.11 5974071.88 622399.68 70 20 15.592 N 149 0 24.629 W Annotation MD TVD '" ft ft: 0500.00 8494.30 TIP 0560.00 8545.08 KOP 0889.16 8698.53 1 1459.16 8698.53 2 1784.16 8698.53 3 ObP BP Amoco Baker Hu~hes INTEQ Plannin~ Report INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB M Pad Well: M-03 Wellpath: Plars~6 M-03A Date: 7/2/2001 Time: 13:59:13 Page: 2 Co-ordinate(NE) Reference: Well: M-03, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,330.00Azi) Sur~ey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD 11849.16 8698.28 4 12199.16 8677.69 5 12550.00 8640.95 TD Plan Section Information MD lncl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft dog/100ft deg/100ft deg/100ft deg 10500.00 32,33 297.00 8494.30 -770.87 -4794.43 0.00 0.00 0.00 0.00 10560.00 32.03 298.19 8545.08 -756.07 -4822.75 1.17 -0.50 1.98 115.83 10889.16 90.00 313.59 8698.53 -585.92 -5038.46 18.00 17.61 4.68 18.00 11459.16 90.00 10.59 8698.53 -65.63 -5206.60 10.00 0.00 10.00 90.00 11784,16 90.00 338.09 8698.53 253,46 -5238.22 10.00 0.00 -10.00 270.00 11849.16 90.45 344.57 8698.28 315.01 -5259.01 10.00 0.70 9.98 86.00 12199.16 96.09 309.96 8677.69 604.52 -5444.75 10,00 1.61 -9.89 280.00 12550.00 95.55 274.69 8640.95 734.93 -5762.45 10.00 -0.15 -10.05 271.00 Survey MD · Incl Azim SSTVD. .N/S. · E/W MapN MapE. · DLS VS TFO Tool ft . . 'deg deg ft ft" .: ft ft ft deg/100ft .ft deg 10500.00 32.33 297.00 8494.30 -770.87 -4794.43 5972625.39 623447.16 0.00 1729.62 0.00 TIP 10525.00 32.20 297.49 8515.44 -764.76 -4806.30 5972631.30 623435,19 1.17 1740.85 115.83 MWD 10550.00 32.08 297.99 8536.61 -758.57 -4818.07 5972637.29 623423.31 1.17 1752.09 115.42 MWD 10560.00 32.03 298.19 8545.08 -756.07 -4822.75 5972639.71 623418.59 1.17 1756.60 115.00 KOP 10575.00 34.61 299.66 8557.61 -752.08 -4829.96 5972643.57 623411.31 18.00 1763.66 18.00 MWD 10600.00 38.93 301.72 8577.64 -744.44 -4842.82 5972650,99 623398.33 18.00 1776.71 16.77 MWD 10625.00 43.29 303.43 8596.47 -735.58 -4856.66 5972659.61 623384.34 18.00 1791.30 15.12 MWD 10650.00 47,67 304.89 8613.99 -725.56 -4871.40 5972669.37 623369.43 18.00 1807.34 13.83 MWD 10675.00 52,07 306.15 8630.10 -714.46 -4886.95 5972680.21 623353.69 18.00 1824.74 12.81 MWD 10691.66 55.00 306.91 8640.00 -706.48 -4897.71 5972688.00 623342.80 18.00 1837.02 11.99 M-O3A 10700.00 56.47 307.27 8644.70 -702.32 -4903.21 5972692,06 623337.23 18.00 1843.37 11.54 MWD 10725.00 60.89 308.28 8657.69 -689.24 -4920.08 5972704.86 623320.14 18.00 1863.14 11.34 MWD 10750.00 65.31 309,21 8669.00 -675.29 -4937.47 5972718.51 623302.52 18.00 1883.92 10.81 MWD 10765.15 68.00 309.74 8675.00 -666.44 -4948.20 5972727.17 623291.64 18.00 1896.94 10.39 M-03A 10775.00 69,74 310.08 8678.55 -660.55 -4955,25 5972732.94 623284.49 18.00 1905.57 10.18 MWD 10800.00 74.17 310.89 8686.29 -645.12 -4973.32 5972748.06 623266.16 18.00 1927.97 10.06 MWD 10825.00 78.61 311.67 8692.17 -629.09 -4991.58 5972763.77 623247.63 18.00 1950.98 9.81 MWD 10850.00 83.05 312.43 8696.16 -612.57 -5009.90 5972779.98 623229.03 18.00 1974.45 9.62 MWD 10875.00 87.49 313.17 8698.22 -595.64 -5028.17 5972796.59 623210.47 18.00 1998.25 9.50 MWD 10889.16 90.00 313.59 8698.53 -585.92 -5038.46 5972806.13 623200.02 18.00 2011.81 9.43 1 10900.00 90.00 314.67 8698.53 -578.37 -5046.24 5972813.54 623192.11 10.00 2022.24 90.00 MWD 10925.00 90.00 317.17 8698.53 -560.41 -5063.63 5972831.20 623174.42 10.00 2046.48 90.00 MWD 10950.00 90.00 319.67 8698.53 -541.71 -5080.22 5972849.61 623157.52 10.00 2070.97 90.00 MWD 10975.00 90.00 322.17 8698.53 -522.31 -5095.98 5972868.74 623141.43 10.00 2095.66 90.00 MWD 11000.00 90.00 324.67 8698.53 -502.23 -5110.87 5972888.56 623126.19 10.00 2120.49 90.00 MWD 11025.00 90.00 327.17 8698,53 -481.53 -5124.88 5972909.02 623111.84 10.00 2145.43 90.00 MWD 11050.00 90,00 329.67 8698.53 -460.23 -5137.97 5972930.09 623098.39 10.00 2170.41 90.00 MWD 11075.00 90.00 332.17 8698.53 -438.38 -5150.12 5972951.73 623085.87 10.00 2195.41 90.00 MWD 11100.00 90.00 334.67 8698.53 -416.02 -5161.30 5972973.89 623074.30 10.00 2220.36 90.00 MWD 11125.00 90.00 337.17 8698.53 -393.20 -5171.50 5972996.53 623063.72 10.00 2245.23 90.00 MWD 11150.00 90.00 339.67 8698.53 -369.95 -5180.69 5973019.61 623054.13 10.00 2269.96 90.00 MWD 11175.00 90.00 342.17 8698.53 -346.33 -5188.86 5973043.09 623045.56 10.00 2294.50 90.00 MWD 11200.00 90.00 344.67 8698.53 -322.37 -5195.99 5973066.93 623038.02 10,00 2318.82 90.00 MWD 11225.00 90.00 347.17 8698.53 -298.12 -5202.07 5973091.06 623031.53 10,00 2342.85 90.00 MWD 11250.00 90.00 349.67 8698.53 -273.63 -5207.09 5973115.46 623026.09 10.00 2366.57 90.00 MWD ObP BP Amoco Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 7/2/2001 Time: 13:59:13 Page: 3 Field: Prudhoe Bay Ce-erdinate(NE) Reference: Well: M-03, True North Site: PB M Pad Vertical (TVD) Reference: System: Mean Sea Level Well: M-03 Section (VS) Reference: Well (0.00N,0.00E,330.00Azi) Wellpath: Plar~6 M-03A Sur~ey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ff deg deg ft ft ff ft ft deg/100ft ff deg 11275.00 90.00 352.17 8698.53 -248.95 -5211.03 5973140.07 623021.73 10.00 2389.92 90.00 MWD 11300.00 90.00 354.67 8698.53 -224.11 -5213.89 5973164.85 623018.44 10.00 2412.86 90.00 MWD 11325.00 90.00 357.17 8698.53 -199.18 -5215.67 5973189.75 623016.24 10.00 2435.34 90.00 MVVD 11350.00 90.00 359.67 8698.53 -174.19 -5216.36 5973214.72 623015.12 10.00 2457.33 90.00 MVVD 11375.00 90.00 2.17 8698.53 -149.20 -5215.95 5973239,72 623015.10 10.00 2478.77 90.00 MWD 11400.00 90.00 4.67 8698.53 -124.24 -5214.46 5973264,69 623016.17 10.00 2499.63 90.00 MWD 11425.00 90.00 7.17 8698.53 -99.38 -5211.88 5973289.59 623018.32 10.00 2519.88 90.00 MWD 11450.00 90.00 9.67 8698.53 -74.65 -5208.22 5973314.38 623021.56 10.00 2539.46 90.00 MVVD 11459.16 90.00 10.59 8698.53 -65.63 -5206.60 5973323.43 623023.02 10.00 2546.46 90.00 2 11475.00 90.00 9.01 8698.53 -50.02 -5203.90 5973339.08 623025.45 10.00 2558.63 270.00 MWD 11500.00 90.00 6,51 8698.53 -25.25 -5200.53 5973363.90 623028.40 10,00 2578.40 270.00 MWD 11525.00 90.00 4.01 8698.53 -0.36 -5198.24 5973388.82 623030.26 10.00 2598.81 270.00 MWD 11550.00 90.00 1,51 8698.53 24.61 -5197.04 5973413.81 623031.04 10.00 2619.83 270.00 MWD 11575.00 90.00 359.01 8698.53 49.61 -5196.93 5973438.80 623030.72 10.00 2641.43 270.00 MWD 11600.00 90.00 356.51 8698.53 74.59 -5197.91 5973463.76 623029.32 10.00 2663.55 270,00 MVVD 11625.00 90.00 354.01 8698.53 99.50 -5199.97 5973488.63 623026.82 10.00 2686.16 270.00 MWD 11650.00 90.00 351.51 8698,53 124.30 -5203.13 5973513.37 623023.25 10.00 2709,21 270.00 MWD 11675.00 90.00 349.01 8698.53 148.93 -5207.36 5973537.93 623018.60 10.00 2732.66 270.00 MVVD 11700.00 90.00 346.51 8698.53 173.36 -5212.66 5973562.26 623012.88 10.00 2756.47 270.00 MVVD 11725.00 90.00 344.01 8698.53 197.54 -5219.02 5973586.32 623006.11 10.00 2780.58 270.00 MWD 11750.00 90.00 341.51 8698.53 221.41 -5226.43 5973610.06 622998.29 10.00 2804.96 270.00 MWD 11775.00 90.00 339.01 8698.53 244.94 -5234.88 5973633,44 622989.44 10.00 2829.56 270.00 MVVD 11784.16 90.00 338.09 8698.53 253.46 -5238.22 5973641.90 622985.95 10.00 2838.61 270.00 3 11800.00 90.11 339.67 8698.51 268,24 -5243.93 5973656.58 622980.00 10.00 2854.26 86.00 MVVD 11825.00 90.28 342.16 8698.43 291.86 -5252,10 5973680.06 622971.42 9.99 2878.81 86.03 MVVD 11849.16 90,45 344.57 8698.28 315.01 -5259.01 5973703.08 622964.12 9.99 2902.31 86.04 4 11850.00 90.46 344.49 8698.27 315.82 -5259.23 5973703.89 622963.88 10.00 2903.13 280.00 MVVD 11875.00 90.90 342.02 8697.98 339.76 -5266.44 5973727.70 622956.27 10.00 2927.46 280.00 MVVD 11900.00 91.33 339.56 8697.49 363,36 -5274.66 5973751.15 622947.65 10.00 2952.01 279.97 MVVD 11925.00 91.76 337.10 8696.82 386.58 -5283.88 5973774.21 622938.02 10.00 2976.73 279.92 MWD 11950.00 92.19 334.63 8695.96 409.38 -5294.10 5973796.83 622927.42 10.00 3001.58 279.86 MWD 11975.00 92.61 332.17 8694.91 431.71 -5305.28 5973818.97 622915.86 10.00 3026.52 279.77 MWD 12000.00 93.02 329.70 8693.68 453.54 -5317.41 5973840.58 622903.36 10.00 3051.48 279.67 MWD 12025.00 93.44 327.23 8692.27 474,81 -5330.47 5973861.62 622889.94 10,00 3076.43 279.55 MWD 12050.00 93.84 324.76 8690.68 495.49 -5344.42 5973882.06 622875.64 10.00 3101.32 279.41 MWD 12075.00 94.24 322.28 8688.92 515.54 -5359.24 5973901.85 622860.48 10.00 3126.09 279.25 MWD 12100.00 94.63 319.81 8686.99 534.92 -5374.91 5973920.96 622844.48 10.00 3150.71 279.08 MVVD 12125.00 95.01 317.33 8684.89 553.60 -5391.40 5973939.35 622827.68 10.00 3175.13 278.88 MWD 12150.00 95.38 314.84 8682.62 571.53 -5408.66 5973956.99 622810.11 10.00 3199.29 278.68 MWD 12175.00 95.75 312.36 8680.20 588.69 -5426.68 5973973.83 622791.81 9.99 3223.16 278.50 MWD 12199.16 96.09 309.96 8677.69 604.52 -5444.75 5973989.35 622773.47 9.99 3245.90 278.26 5 12200.00 96.09 309.88 8677.60 605.06 -5445.39 5973989.88 622772.82 10.00 3246.69 271.00 MWD 12225.00 96.13 307.36 8674.94 620.57 -5464.81 5974005.05 622753.14 10.00 3269.83 270.99 MWD 12250.00 96.15 304,85 8672.26 635.22 -5484.89 5974019.35 622732.81 10.00 3292.56 270.72 MWD 12275.00 96.17 302.33 8669.58 648.97 -5505.60 5974032.75 622711.88 10.00 3314.82 270.45 MWD 12300.00 96.17 299.82 8666.89 661.79 -5526.88 5974045.21 622690.38 10.00 3336.57 270.18 MWD 12325.00 96.16 297.30 8664.21 673.68 -5548.71 5974056.71 622668.35 10.00 3357.78 269.91 MWD 12350.00 96.14 294.79 8661.53 684.59 -5571.04 5974067.24 622645.84 10.00 3378.39 269.64 MWD 12375.00 96.11 292.28 8658.86 694.51 -5593.83 5974076.78 622622.89 10.00 3398.38 269.37 MWD 12400.00 96.06 289.76 8656.21 703.43 -5617.03 5974085.29 622599.54 10.00 3417.70 269.11 MWD 12425.00 96,01 287.25 8653.58 711.32 -5640.61 5974092.78 622575.83 10.00 3436.32 268.84 MWD 12450.00 95.94 284.74 8650.98 718.17 -5664.51 5974099.22 622551.82 10.00 3454.21 268.58 MWD 12475.00 95.86 282.22 8648.41 723.96 -5688.69 5974104.60 622527.55 10.00 3471.32 268.31 MWD Obp BP Amoco Baker Hu~hes INTEQ Plannin~ Report INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB M Pad Well: M-03 Wellpath: Plan06 M-03A Date: 7/2/2001 Time: 13:59:13 Page: 4 Co-ordinate(NE) Reference: Well: M-03, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,330.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S E]W MapN MapE DLS VS TFO Tool ff deg deg ff ft ff ff ft deg/100ft ff deg 12500.00 95.77 279.71 8645.88 728.70 -5713.10 5974108.91 622503.06 10.00 3487.62 268.06 MWD 12525.00 95.66 277.20 8643.39 732.35 -5737.71 5974112.15 622478.40 10.00 3503.09 267.75 MWD 12550.00 95.55 274.69 8640.95 734.93 -5762.45 5974114.30 622453.61 10.00 3517.69 267.50 TD ~ri -- - M-03 (M-O3) Magnetic North: 26.50" Created By: Brij PotnisOafe: 7/2/2001 . S-30 (S-3O) BP Amoco ~, Plan #6 Magnetic Field Con[ac[ Information: ~:".'~i'~_Ll~-";'. '!; Strength: 57480nT ........... ~;:-'~ i"-?'",-'- Dip Angle: 80.78' Direct (907) ~2,=e~.=~ ....... Date: 7/2/2001 E.mail brij po[nJs~jin~eq. COm Model: BGGM2001 Hughes INTEO: ~907) 267-6600 TI~ ~l MD: t{1550.00 Ref. Datllm: 4: DS 8/~t971 00:00 ~.,~'~m o.~ F~.~, ~ ~ ............... '"~'~ '.i " \ " i-~ Co-ordinate (N/E) Reference: Well Cenb'e: M4)3. lrue North 800"7~.~Z.'_."_')i~ ; --;'i --_'-.'.'.'}'i:~'.'.i'.~'~. ~6 M-03.~. ~ '.'"'? ........ i .'i "~'"- ...... !' !' ·" ~ ' Ver'~al {TVD) Reference: System: Mean Sea Level 7~ { .......... i .......... : ": I · .~/' ..... · · ~-- ~ - i : : : Section0/S)Refemnce: Slot-03{0.00N,0.0OE) 23 'i'''"'"~ ...... :} -! "~ · : ..... ;" \ - i' '! ! i : Measured Oeplh Reference: 4: 03 8/6/1971 00:00 44.50 7nt'~--t: ~ i i } [ ~i.~ - i " ~, i . i Calcula§onMelhod: Minimum Curvature --ii :' ii i !'L~-~'xx. 'l-~l ~ i :i : i i i ' ' ............................ 80od.'-:------~ .......................... ; ............ .---?~~ \\ '", ......... i'"'"";'""i ........ ~ .......... ~ ............ : '~ .......... ; ........ ................................... t}' : ' .' : '~~ ..... . ' . \~ ........... :~=u:=:~ F,~ '~F, ~ 1~"? ~' 5oo ,.---~-.----., ............... ; ......... ,-~~--~ .... . \\ -~ ...-~ ......... :--~ ...... ;' ~ ~ ' ' ' ' ."2, ............... ~o It~o ,go.~.~ ,-, ~i ::ii i - ~- ~ ~~i \ \ i...i .!.. - i i. ' - ' ~.oe 3o~.e~ ~477.~ ~o&s3 -~4~1s lo, oo ~oo 3 ~ ~ t ........ :--'t---'~- · - ~_ ~ ~ ..... ~ .... 1 't ~ : '~ : - : _ ,.:.. .,...& . o oo : ................ ! ............ ........ -, . · . ......... · ~ --- ,- .~-_...-?i-:,'.-:.i-_.i:-?:.:-:'.'.'i.'i-:-:.7:':-'--~'~ ~-'.~..~ ' ~-: \ \ -i'.'.-.'-.~".".i" ! . ; : ......... I ....... '-'2oo-:F-----7~-; ~ ....................... '?:.ti~"' "....\ ~ \ \:::-¢-i-.-..i.' ...... -~ i ..... ; ..'~ · - ' · 854.5,O8 10580'O0 KOP J,J~)3AT$~ ~7S~O ~r/.15 ~ ~ ~ -- ~ : ~ , ~ - : :, * . : : : :. ; ~ . , Ill?Il 11111.11 I I ~ 4; ..... :- '-.~" :' ~ ' ~ : _z._,,: °i!~'-"!'i'-'"'!:!'::' ...... ;:~.i ........ ~--i. i .... !...-.:-:. :,,,~ · . . ._ ,~-10 . .. ~ . :i ...... ~ ' - · . :'.~':':':.:::.."";'":'"':"'."i:". .... - ~-200-~_i? '~:~ ~ '.?.... .'..:..:..'.:'.'::' :::':--_'!-:' } r ~ .................. : : . : ; ':;i ........................... : i -3°°dY--~-¢'~-":"}"':'"-"""::::iv:":"d "?~ ! i !"-":'"": ............ i-"'"'i'':'''' ~ "'i'"~':'""'"} ~'''' '~ .... i'" r ; ! · ..... ?.,... :: ..... ......... , .....· . . ,:. "' i -- ::~: : · ' i i i : ~: ~ -600~'i .......... !-~-~. .................. ~¥ '~ ........ :'" : ' ~' T ...... --~ .; : ; ..:.'...L....::..;....:...; .... i -i . ;~ i i ; i ; i ' : :.i"..'~': ....... ?'""'"":: ":-:- ..... :.' :.' ; .~ .:.--i-...?....:...-...i.'.".:': .... :::::::::::::: ::::::::::::::::::::: ::: '. ! ' '~ ;~ "i. !- i ' .i :.~ . - '"". ............ ! ....... -"' :" -'! :~ - ---l.t.-.-.'.-.--.'~.-.!.-.'~'-.-~:- --- :~-:.....---..-.i..'-:.'.'.'."~. .¢.'--.'.'.-...-.:- ' '~'.'.'.".:-.'; ~;~'i .:- -: ~¢-~ ....... ,, ....... ~1~ 845~ \; i' i : ~: -:: :::. ' i - : -6300 -6200 -6J00 q~(~00 -5900 -5800 -5700 -5600 -5500 -5400 -5300 -5200 -5100 -5000 4900 -4800 4700 -4600 '4500 4400 4300 4200 '4100 4000 '3900 -3800 '3700 -iX i i : i' : ~ ~ i i ; ! :-' :: . . West(-)/East(+)[lOOft/in] ~®..~::-.::i_:~:..,:......;.....;..:.._..~....-.- ....... '"~'-~"-'"-'-/"~":'~'"-i'" ========================= ~ ~ , ~ ~ :: .~:. :.....~ ......... ~ .:.~.....~...:.: ...... ~ ......... , ~ .... ': .... ::i'"~""'VF~m ,. ':: "~';'"'!'":"'"":'"'""':'!':'"":'"'"'i ..... ~ :. i:".'"~ ............. !'~"t- i~"- ..... f'"'"; ! .... "":-i~ ~ .... ~" ~'! ...... .' 855~ !~ ~'~!,:.! , :. ~ ~ il:: ' .... ! : . : . ii! i i ~ i' . , - _ ~.i ~i-.....~:_.~ .............. : ......................... , '. 860o-i+---.-' ....... i ":{.',-~ . ~ :'} ' ! : ' : .L..i_...~ ................................ ~i ............. i..'.".,:?¢, ........ : ........ :"-'~.'--':-'~ :. : ........ ~..:!'-'"i"i'-";"'"-'i ;...;..--...: :..-i.: ':':-"'!' '; i....: .... -'"'~ ...... i~ ~ ...... "7. ......... · ..... '..-"T ~.'! · · : ~. i ' 8650---~ -- - !'-, ' -~-, ' r ............ ?'"'-'"'~ .......... ~'"'"'-~ ........... ~'" i ' 'i ........................ ~ ~? ............... f ................. ; '- ': "'""~" TM ............... ~ ~ I :' ~ ........ ' .... I [ ~ ", "-.. : ~i ' i :m ~ · :,m 'r~ : : +../~..---.-+ ............... ~ :/ ; ~ ~ ' \ - ' ........... ~i i ~ : ' ~. ' i ! i! : ~. ,~ , : : ,: i ~ i~ L ......... ;,_.i ............................................. :. ~3~z,.3~dl ~i....! .... '~ ~; ~ " - ~-..i .. i ...... ........ i... ............ L.'!.!: i i ...i...i.........i....i.'.i...~.~.: ..... ::'~ :-....i ..... : ...i.....;~: . .. . /. · · : 87~o-,~......:..-~......_..............!..........,....~....;..-..:~k .... -:- i -'-i----~ :'--7: .............. !-'-'"-"'.'-':-'--!':-'.'.'.'-'.':?.?-'."~.'-i i :---i-7'-'""-?'.'.'".'.'-.'v:.~:'-I' :-'-i'-:'-'-"-?'.'-'-':'.;;:. :'7:---?--':':::.',.- ......... i---:~--':-'' ':'-:"?- ..... ~ 88§0----~" ~ ...... :: i ~ i ~ ~ ~\ i ~ ~ i ~ ~ ' .................. ~ ............. ?'"'"?- i ~ ' ' ~ ' ' ! ; ~ -:--..-.?.-.-7 7:- '~ ' ' :: ' ~ ': ' ; i .......... r':' '~ ' ~ i '.: ...... ~'""~ ...... ; · '; .. '~-"; .... ~'" ' - ;i i Z.~ ' ' ' ' : !\:: } i i i i - ! '..; ~i : ' ~ il ~. ~ ; : -~ : ii : ; i - : - ! · ! ~ . lf~ 1750 1800 1850 19'00 19~ 2~0 2050 21~ 2150 2200 2250 2300 2350 2400 2~0 2500 25~ 26~ 2650 2700 2750 28~ 2850 29~ 2950 3000 3050 3100 3150 32~ 3250 3~0 3350 3400 3450 3500 3550 3600 Ve~ical Section at 330.00' [5~in] 7/2/200! 2:35 PM BP Amoco Anticollision Report INTEQ Date: 7/2/2001 Time: 14:12:29 Co-ordinate(NE) Reference: Well: M-03, True North Vertical (TVD) Reference: 4: 03 8/6/1971 00:00 44.5 Page: I Company: BP Amoco Field: Prudhoe Bay Reference Site: PB M Pad Reference Well: M-03 Reference Wellpatb: Plan06 M-03A Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There arel~R~il~ells in th~j~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 19.00 to 12550.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1453.10 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 7]212001 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name 100.00 10500.00 1: Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 10500.00 12550.00 Planned: Plan #6 ¥1 MWD MWD - Standard Casing Points Summary <. Offset Wellpath > Reference Offset Ctr-Ctr · No-Go '. Allowable Site Well .. MD · MD Distance Area DeviatiOn 'Warning · · Wellpath PB M Pad M-01 M-01 Vl 3383.41 3400.00 393.09 No Reference Casings PB M Pad M-02 M-02 V2 2198.99 2200.00 114.26 No Reference Casings PB M Pad M-02PB1 M-02PB1 V2 2198.99 2200,00 114.26 No Reference Casings PB M Pad M-03 M-03 V3 10599.79 10600.00 2.53 No Reference Casings PB M Pad M-04 M-04 V1 2400.00 2400.00 92.12 No Reference Casings PB M Pad M-05A M-05A V2 2895.33 2900.00 180.62 No Reference Casings PB M Pad M-05APB1 M-05APB1 V2 2895.33 2900.00 180.62 No Reference Casings PB M Pad M-05APB2 M-05APB2 V2 2895.33 2900.00 180.62 No Reference Casings PB M Pad M-05 M-05 V3 2895.33 2900,00 180.62 No Reference Casings PB M Pad M-06A M-06A V1 1992.52 2000.00 213.74 No Reference Casings PB M Pad M-06 M-06 V1 1992.52 2000.00 213.74 No Reference Casings PB M Pad M-07 M-07 V1 3136.48 3200.00 310.53 No Reference Casings PB M Pad M-08 M-08 V1 2482.75 2500.00 414.90 No Reference Casings PB M Pad M-09A M-09A V4 4214.29 4400,00 258.63 No Reference Casings PB M Pad M-09 M-09 V1 4293.32 4500.00 272.62 No Reference Casings PB M Pad M-10 M-10 V1 4554.55 4700.00 479.43 No Reference Casings PB M Pad M-17 M-17A V2 Plan: M-17A W 1488.26 1500.00 305.70 No Reference Casings PB M Pad M-25 M-25 V1 1487.44 1500.00 226.67 No Reference Casings PB M Pad M-26A M-26A V1 2387.45 2400.00 140.97 No Reference Casings PB M Pad M-26 M-26 V1 2387.44 2400.00 141.44 No Reference Casings PB M Pad M-27A M-27A V1 7943.79 7900.00 329,43 No Reference Casings PB M Pad M-27 M-27 V1 8044.33 8000.00 322,69 No Reference Casings PB M Pad M-28 M-28 V1 3189.48 3199.90 244.93 No Reference Casings PB M Pad M-29 M-29 V2 3310.18 3300.00 105.30 No Reference Casings PB M Pad M-29 M-29A V1 3310.18 3300.00 105.30 No Reference Casings PB M Pad M-30 M-30 V1 2172.65 2200.00 142.42 No Reference Casings PB M Pad M-34 M-34 V1 3605.23 3700.00 129.77 No Reference Casings PB M Pad M-38 M-38 V1 1487.79 1500.00 34.30 No Reference Casings PB M Pad M-38 Plan~4 M-38A V0 Plan: 1487.79 1500.00 34.30 No Reference Casings PBS Pad S-07A S-07A V1 Out of range PBS Pad S-07 S-07 V1 Out of range PBS Pad S-13 S-13 V1 12300.00 11400.00 1282.57 No Reference Casings PBS Pad S-30 S-30 VI 12199.16 12000.00 241.72 No Reference Casings PBS Pad S-40A S-40A V1 Out of range PBS Pad S-40 S-40 V1 Out of range M-03/Plan#6 M-03A I 10000 10500 11000 11500 12000 Measured Depth [ft] 12500 13000 M-01 (M-01) M-02PB 1 (M-02PB 1) M-04 (M-04) M-05APB 1 (M-05APB 1) M-05 (m-05) m-06 (m-06) m-08 (U-08) m-09 (U-09) m-17 (M-17A) M-26A (M-26A) M-27A (M-27A) M-28 (M-28) M-29 (M-29A) M-34 (M-34) M-38 (Plan#4 M-38A) s-o7 (s-oT) s-30 (s-30) s-40 (s-40) M-02 (M-02) M-03 (M-03) M-05A (M-05A) ~::..... :~- ............. M-05APB2 (M-05APB2) ........................................... M-06A (M-06A) .................. M-07 (M-07) M-09A (M-09A) .......................... ..................... ...................... U-10 (m-10) M-25 (M-25) M-26 (M-26) .................. M-27 (M-27) .... M-29 (M-29) , m-30 (m-30) M-38 (M-38) S-07A (S-07A) .............. S-~3 (S-~3) S-40A (S-40A) 3S CTD BOP Detail Methanol Injection tis 7" WLA Quick onnect ~ -- 7" Riser CT Injector Head g Box (Pack-Off), 10,000 psi Working Pressure 7-1/i~a~DF, y,i~0B~ ~[~ing pressure Manual ov~O~y~raulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR 7-1/1~,y15:~0~[~ ~[~ing pressure Manual ov~(~y~raulic Side Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure IBlind/Shear ] / Flange by Hammer up 1/ Kill line check valve Valve on DS Hardline to St ~ ~,,,~,~ manifold ii 2 718" Combi Pipe/Slip 2 318" Combi Pipe/Slip MOJ 5/16/01 xo spool as necessary Single Manual Master Valve THA I Tubing 2 flanged gate valves 7" Annulus 9 5/8" Annulus ~ RANSMITAL LETTER CHECK L~o - CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 CHECK WHAT APPLIES STANDARD LETTER "CLUE" DEVELOPMENT DEVELOPMENT REDRILL ~ EXPLORATION INJECTION INJECTION WELL REDRILL~ ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( ) YES + SPACING EXCEPTION The permit is for a new wellbore segment of existing well , Permit No, ~ AP1 No. ~. Production should continue to be reported as a function of the original APl number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the apProved application for permit to drill the above referenced well. The permit is approved' subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates I DATE I CHECK NO. I H ~933~5 VENDOR ..... DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 370201 cKO70201B 100. O0 100. O0 PYMT ~;OMMENTS: Pe~it to D~ill )'ee HANDL~.'.N~ INST: S/H - Te~ie Hubl le ×4~8 o~ Sond~a Step,man X4750 E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. II~e] ~r-~1 ~ ] , BP EXPLORATION, (ALASKA)INC. RO. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY To Th e DRDER FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H I93315 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 O019331 5 .. :'' DNE:'.':H U ':': .... U DRED & OO/1OO,..~'.~.~--~.~--~-.~-.~-~.~'.~-~-~-.~--~-*x--~.~.-~-~-~-~~~~ US DOLLAR .: "ALASKA OIL AND OAS 'C.ONSERVATION COMMISS'IONi 333: WEST 7TH AVENUE SUITE 100 ANCHORAQE AK 99~01 07'/0&/01 ]:.."..ii ~!:;': ::.:. Ii NOT:.VAL D AF3'ER 120 DAYS AMOUNT $100. :.00' I' WELL PERMIT CHECKLIST FIELD & POOL ~' ~ ADMINISTRATION DATE 7./~.ol .. WELL NAME 4'{'SSJ~' PROGRAM: exp __ ENGINEERING INIT CLASS 1. Permit fee attached: ...................... 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 ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs...' ........ 16. CMT vol adequate to circulate on conductor & 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 to-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations ........... GEOL AREA dev redrll __ wellbore sag ann. disposal para req ~ 'V'"' serv UNIT# ON/OFF SHORE Y N Y N Y N Y N N A' .... DATE IIGEOLOG'-~Y DATE 24. Drilling fluid program schematic & equip list adequate ...... (~ N 25. BOPEs, do they meet regulation ................ ~ N 26. BOPE press rating appropriate; test to .z,,~ ps~g. ~1~ N ~~'~) 27. Choke manifold complies w/APl RP-53 (May 84) ..... .... (,~ N -- 28. Work will occur without operation shutdown ........ ' . . . I~) _!~ _ ,:, ~,, ' . ~, . . 29. Is presence of H2'S gas probable ................. Y 30.' Permit can be issued w/o hydrogen sulfide measures .... . Y ('~ 31. Data presented on potential overpressure zones ....... Y,,~I~ ' //~ "" ~ / - 32. Seismic analysis of shallow gas zones... .......... ,.[ ~,,,Y~N .... _ . 33. Seabed condition survey (if off-shore) ..... ....... .,~,.--Y" ~' Y N 34. Contact name/phone for Weekly progress reports [explor~ry only] Y N ' DISPOSAL35. With proper cementing records, this plan (A) will' contain waste in a suitable receiving zone; ....... Y N DATE (B) will not contaminate.freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the wail'used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAc 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular,.,--~ COMMISSION: Comments/Instructions: 0 Z 0 z --I -1= c:\msoffice\wordian\diana\checklist (rev. 11/01//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 readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPEbI. 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 $ Tue Mar 12 15:12:54 2002 Reel Header Service name ............. LISTPE Date ..................... 02/03/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/03/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-1 l133 B. JAHN R. WHITLOW M-03A 500292010201. BP Exploration (Alaska) Sperry Sun 07-MAR-02 MWD RUN 2 MWD RUN 3 AK-MW,-ll133 AK-MW-ii133 B. JAHN B. JAHN GOODRICH / S GOODRICH / S JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: HWD RUN 6 AK-MW-Ii133 B. JAHN GOODRICH / S WELL CASING RECORD MWD RUN 7 MAD RUN 8 AK-MW-ii133 AK-MW-iI133 B. JAHN S. LATZ GOODRICH / S SARBER 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: :[_iN 12E 28'78 605 44.54 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 13.375 2283.0 3.'750 9.625 10265.0 3.750 7.000 10562.0 I. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS). 3. M-03A KICKS OFF FROM bi-03 AT WHIPSTOCK WITH TOP' SET AT 10562' MD, 8546.8' TVDSS. M-03A KICKS OFF FROM M-03A PB1 IN OPEN HOLE SIDETRACK DURING RUN 3 AT 11150' MD, 8698.8' TVDSS. b~D RUNS 1-3 .AND 6-7 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. MWD RUNS 4-5 MADE NO FOOTAGE AND ARE NOT PRESENTED. 6. MWD RUN 8 IS A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE PULLING OUT OF HOLE FROM TD TO THE ORIGINAL KICK-OFF POINT, WITH DUAL GAMMA PROBE (DGR) UTILIZING GEIGER-MULLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 7. DEPTH SHIFTING WAIVED BY D. DICKEY PER THE E-MAIL OF 2/20/2002 FROM D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 8. MWD RUNS 1.-8 REPRESENT THE MWD BATA FOR WELL M-03A WITH API# 50-029-20102-0]... THIS WELL REACHED A TOTAL DEPTH (TD) OF 1261.6.5' MD, 8920.6' TVDSS. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY - GEIGER-MULI.,ER TUBE DETECTORS SGRD = SMOOTHED GAMMA RAY - SCINTILLATION SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP =: SMOOTHED PHASE SHIFT DERrVED RESISTrVITY ( DEEP S PACIN'G ) SFXE ='. SMOOTHED FORMATION EXPOSURE TIME M DENOTES MEASUREMENT AFTER DRILLING (MAD) PASS $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Dep'th shifted and clipped curves; all. bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10546.0 1.2572.5 ROP 1.0581.0 12602.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MW D MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE eASE 1 10546.0 10723.0 '2 10723.5 10876.0 3 10876.5 11150.0 6 1115(I.5 1136(I.(/ 7 11360.5 12602.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Cc}de Offset Channel DEPT FT 4 l. 68 0 ]. ROP MWD FPH 4 i 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10546 12602.5 ]_1574.3 41.14 ROP MWD FPH 0 1172.09 73.0!5'7'-/ 4044 GR MWD AP1 18.61 977.64 47.3872 4054 First Reading For Entire File ........... 10546 Last Reading For Entire File ........... 12602.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum, Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 10546 10581 10546 Last Reading 12602.5 12602.5 125'72.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name.., Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record.,65535 File Type ................ LO Previous File Name ....... STSLIB.001 Con~nent Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest u, asses. DEPTH INCREMENT: .5000 FiLE SUMMARY PBU TOOL CODE START DEPTH FET 10533.0 RAT 10533.0 GR 1 (3533.0 AP?,: 10533.0 RPS 10533.0 RPM 10533.0 RPD 10533.0 $ MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MWD 8 $ REMARKS: MERGED MAD PASS. $ Data Format Specificati. on Recerd Data Record Tpe .................. 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 STOP DEPTH 12584.0 12619.0 12565.0 12584.0 12584. Ii! 12584 . 0 ].2584.0 MERGE TOP MERGE BASE 10533.0 12619.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FPH 4 I 68 4 2 GR MAD API 4 I 68 8 3 RPX HAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 ]. 68 24 7 FET MAD HR 4 i 68 28 8 Name Service Unit Min Max DEPT FT 10533 12619 RAT MAD FPH 55.55 842.31. GR MAD API 12.9 41'7.28 R PX HAD OHMH 0.56 2000 RPS MAD OHMM 0.1 2000 RPM MAD OHMM 0.11 2000 RPD MAD OHMM 0.03 2000 FET MAD HR 9.3455 200.6'7"7 First Reading For Entire File .......... ],0533 Last Reading For Entire File ........... 1.261.,9 File Trailer Service name ............. STSLIB.'002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Mean 11576 "792.961 44.6406 18.0292 1.8.9358 16.9'73 1.,4.94'78 '75.2209 N s am 4173 4173 4065 4103 4103 4103 4103 4103 First Reading 10533 10533 1,0533 10533 10533 10533 10533 10533 Last Reading 12619 12619 12565 12584 12584 12584 12584 12584 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Ve~'sion Number ........... 1.0.0 Date of GeneraEion ....... 02/03/112 Ma:.:imum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comme~t Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bi~ run in separate tiles. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10546.0 _]_0687.5 ROP 10581.0 10723.0 $ LOG HEADER DATA DATE LOGGED: 07-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAI,-TIME): Memory TD DRILLER (FT): 10723.0 TOP LOG INTERVAL (FI'): 10581.0 BOTTOM LOG INTERVAL (FT): 10723.0 BIT ROTATING SPEED (RPM): [{OLE INCLINATION (DEG MINIMUM ANGLE: 32.0 MAXIMUM ANGLE: 45.9 TOOL STRING ('TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (i[iN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (SD: 60.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 11.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 124.8 MUD FILTPJ~TE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAbIDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down O',,-.,tical log. depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Ma:.~ frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification E',lock sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP ~D010 FPH 4 1 68 4 2 GR ~D010 AP1 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10546 10723 10634.5 355 ROP MWD010 FPH 0.5 112.92 42.1188 285 GR MWD010 API 34.16 977.64 186.395 284 First Reading For Entire File .......... 10546 Last Reading For Entire File ........... 10723 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Nun~er ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File TFpe ................ LO Next File Name ........... STSLIB.004 Firs~ Reading 10546 10581 10546 Last Reading 1_0723 10723 10687.5 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10688.0 10840.5 ROP 10723.5 10876.0 $ LOG HEADER DATA DATE LOGGED: 09-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10876.0 TOP LOG INTERVAl, (FT): ].0723.0 BOTTOM LOG INTERVAL (FT): 10876.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION {DEG MINIMUM ANGLE: 65.6 MAXlMUH ANGLE: 78.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOl, TYPE NGP NATLIRAL GAHHA PROBE $ TOOL NUMBER PB02t 00HNRG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATLIRE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT' MT: MUD CAKE AT MT: Flc, Pro/CWaz r 8.60 60.0 8.5 24000 8.4 .000 .0 .000 120.6 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION {liN): TOOL STANDOFF (liN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Di r e c,t i on ................. Down Optical leg 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-t, ype...0 Name Service Order Units Size Nsam Rep Code Offse't Channel DEPT FT ,4 1 68 0 1 ROP MWD020 FPH 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10688 10876 10782 3"? "? ROP MWD020 FPH 4.25 76.51. 48.6284 306 GR MWD020 APl 1_9.49 730.54 59.6363 306 First Reading For Entire File .......... 10688 Last Reading For Entire File ........... 10876 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Reco~'d..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Reading 1.0688 10723.5 10688 Last Reading 10876 10876 10840.5 Physical EOF File Header Service name ............. STSL,!8.005 Service Sub Level Name... Version Number ........... !.0.0 Date ef Generation ....... 02/03/12 Ma:~imum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIP..00.! Comme.r~t Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit urn in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL, CODE START DEPTH STOP DEPTH GR 10841[ . 0 111150.0 ROP 10876.5 11150.0 $ # LOG HEADER DATA DATE LOGGED: 10-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIHE): Memory TD DRILLER (PT): 11150.0 'POP LOG INTERVAL (FT): 10876.0 BOTTOM LOG INTERVAL (PT): 11150.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIHUM ANG'[,E: 84.1 HAXIMUM ANGLE: 92.5 'POOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE, TOOl, TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE PB02100HWRG6 $ BOREHOLE ANI} CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT'): BOREHOLE CONDITIONS MUD TYPE: FloPro/Water MUD DENSITY (1,B/G): 8.60 MUD VISCOSITY (S): 60.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 16000 FLUID LOSS (C3): 10.6 RESISTIVITY (OHMM) AT TEHPERATURE (DEGF) HUD AT HEASURED TEMPERATURE (HT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 133.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT': .000 .0 NEUTRON TOOl, MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Legg±ng Diuectien ................. Down Optical log depth units ........... Feet Data Refek~ence Point .............. Undefined FF,-nme Spacing ..................... 60 . lin Max frames per reco~-d ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-~ype...0 Name Service Order Units Size Nsam Rep Cede Offset Channel DEPT FT 4 1 68 0 1 ROP PYWD030 FPH 4 1 68 4 2 GR MWD030 AP1 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10841 11150 10995.5 619 ROP MWD030 FPH 0.33 174.11 80.0932 548 GR MWD030 API i[8.61 70.49 37.9901. 619 First Reading For Entire File .......... 10841 Last Reading For Entire File ........... 1.1150 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Tpe ................ LO Next File Name ........... STSZ, IB.006 First Reading 10841 10876.5 10841 Last Reading 111561 11150 11150} Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... 'Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 11150.5 11360.0 GR 11.].,50.5 11329.5 $ LOG HEADER DATA DATE LOGGED: 12-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (HEHORY OR REAL-TIME): Memory TD DRILLER (FT): 11360.0 TOP LOG INTERVAL (FT): ].1150.0 BOTTOM LOG INTERVAL (FT): 11360.0 BIT ROTATING SPEED {RPH}: HOLE INCLINATION (DEG MINIMUH ANGLE: 81.0 MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOH) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE; AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF' (IN): EWR FREQUENCY (HZ): REMARKS: $ 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 9 2.0 TOOL NUMBER PB02100HWRG6 3.~50 FloPre 8.60 60.0 8.5 14400 6.4 .000 .0 .000 133.0 · 000 .0 .000 .0 Name Service Order Units Size Nsam, Rep (lode Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FPH 4 1 68 4 2 GR MWD060 AP1 4 ii. 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11150.5 11360 1].255.3 420 ROP MWD060 FPH 0.08 142.35 59. 2863 420 GR M'WD060 API 22.66 90.91 38.0877 359 First Reading For Entire File .......... 1.1150.5 Last Reading For Entire File ........... 1,'.1,,360 File Trailer Service :name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 First Reading 11150.5 11150.5 11150.5 Last Reading 11360 11360 11329.5 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Pre¥ious File Name ....... STSLIB.006 Cor~ent Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log headeu data for each bit uun in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPT~t STOP DEPTH GR 11330.0 12572.5 ROP 11360.5 12602.5 S LOG HEADER DATA DATE LOGGED: 14-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE 'VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12602.5 TOP LOG INTERVAL (FT): 11360.0 BOTTOM LOG INTERVAL (FT): 12602.5 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.3 MAXIMUM ANGLE: 102.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAPPR PROBE PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 60.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 14000 FLUID LOSS (C3): 7.2 RESISTrVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .220 66.0 MUD AT MAX CIRCULATING TERMPER.ATURE: .100 154.0 MUD FILTRATE AT MT: .230 66.0 MUD CAKE AT MT: .170 66.0 NEUTRON TOOl, MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Speoification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference PoiFlt ............... Undefined Frame Spacing ..................... 60 . lin Ma:-: frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 i ROP MWD070 FPH 4 1 68 4 2 GR MWD070 APl 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEFT FT 11330 12602.5 11966.3 2546 ROP MWD070 FPH 0 1172.09 80.3903 2485 GR MWD070 API 20.94 152.01 33.6819 2486 First Reading For Entire File .......... 11330 Last Reading For Ent, ire File ........... 12602.5 File Trailer Service name ............. STSLIB.O07 Service Sub Level. Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ I,O Next File Name ........... STSLIB.008 First Reading 11330 1.1360.5 11330 Last Reading 12602.5 12602:.!5 12572.5 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of' each run in separate files. DEPTH INCREMENT: .5000 MAE} RUN NUMBER: 8 MAD PASS NUMBER: 1 FILE SUMMARY 'VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 1.,0533.0 12584.0 FET 10533.0 12584.0 RPD 10533.0 12584.0 RPM 10533.0 12584.0 RPX 10533.0 12584.0 RAT 10533.0 12619.0 GR 10533.0 12565.0 $ LOG HEADER DATA DATE LOGGED: 15-AUG-0]_ SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION': 66.16 DATA TYPE (MEMORY OR REAI,-TIME): TD DRILLER {FT): TOP LOG INTERVAL {FT): BOTTOM LOG INTERVAL (FT): BiT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~vPIA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (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: $ 'Il: Data Format. Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direoti, on .................. Down Optical. log depth units ........... .Feet Data Reference Point .............. Undefined Frame Spac, ing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 12602.5 10550.C !2602.i .0 .0 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 3.750 FloPro 8.68 60.0 8.0 14400 6.8 .220 66.0 .100 154.0 .230 66.0 .170 66.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD081 FPH 4 1 68 GR MAD081 AP1 4 1 68 RPX MAD081, OHMM 4 1 68 RPS NRD081 OHMM 4 1 68 RPM MAD081 OHMM 4 1 68 RPD MAD081 OHMM 4 1 68 FET MAD081 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Min Max DEPT FT 10533 1261. 9 RAT' MAD081 FPH 55.55 842.3]. GR MAD081 AP1 12.9 4]'7.28 RPX MAD081 OHMM 0.56 2000 RPS HAD081 OHMM 0.1 2000 RPM MAD081 OHMH 0.11 2000 Mean 11576 '792. 961 44.6406 i8. 0292 18.9358 16. 973 Nsam 4173 4173 4065 4103 4103 4103 F'irst Reading 10533 10533 ].0533 1.0533 10533 10533 Last Reading 12619 12619 12565 12584 12584 12584 RPD MAD081 OHMM 0.03 2000 FET MAD081 HR 9.3455 200.677 First Reading For Entire File .......... ].0533 Last Reading For Entire File ........... 12619 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/12 Maximum Physical Recerd..65535 File Type ................ LO Next File Name ........... STSLIB.009 14.9478 4103 10533 12584 75.2209 4103 10533 12584 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/03/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNO%~N Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/03/1.2 Origin ................... STS Reel Name ................ UNKNOWN ContJ. nuat;ion Number ...... 0], Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical End Of LIS File Sperry-Sun Drillino Services LIS Scan UtiliE\' SRevision: 3 $ LisLib SRevision: 4 $ Thu Mar 14 11:06:44 2002 Reel Header Service name ............. LISTPE Da~e ..................... 02/03/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/03/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... O1 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS W~iting Library. Scientific Technical Services 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: M-03A PB1 500292010270 BP Exploration (Alaska) Sperry Sun 08-MAR-02 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MW-ii133 AK-MW-iI133 AK-MW-ii133 B. JAHN B. JAHN B. JAHN R. WHITLOW GOODRICH / S GOODRICH / S JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MAD RUN 8 AK-MW-ii133 S. LATZ SARBER 1 lin 12E 2878 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 605 44.54 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 13.3'75 2283.0 3.750 9.625 10265.0 3.750 7.000 10562.0 I. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNI, ESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS). 3. M-03A KICKS OFF FROM M-03 AT WHIPSTOCK WITH TOP SET AT 10562' MD, 8546.8' TVDSS. M-03A KICKS OFF FROM M-03A PB1 IN OPEN HOLE SIDETRACK DURING RUN 3 AT 11150' MD, 8698.8' TVDSS. 5. ~D RUNS 1-3 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTII, IZING SCINTILI,ATION DETECTORS. MWD RUN 8 IS A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE PULLING OUT OF HOLE FROM M-03A TD TO THE ORIGINAL KICK-OFP POINT, WITH DUAL GAMMA PROBE (DGR) UTILIZING GEIGER-MULLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 7. DEPTH SHIFTING WAIVED BY D. DICKEY PER THE E-MAIL OF 2/20/2002 FROM D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 8. MWD RUNS 1.-3 AND 8 REPRESENT THE MWD DATA FOR WELL M-03A PB1 WITH API# 50-029-20102-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11571.5' MD, 8710.6' TVDSS. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY - GEIGER-MUI,LER TUBE DETECTORS SGRD = SMOOTHED GAMMA RAY - SCINTILLATION SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING. SESP = SHOOTHED PHASE SHIFT DERIVED RESISTIVITY SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME M DENOTES MEASUREMENT AFTER DRILLING (MAID) PASS $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/14 Maximum Physical Record..65535 Pile Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT': .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10546.0 11530.5 ROP 10581.0 11.565.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 10546.0 10723.{I MWD 2 10723.5 10876.0 MWD 3 10876.5 11565.5 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Polnt .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1, 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 i 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10546 11565.5 11055.8 2040 ROP MWD FPH 0.33 2259.89 78.8742 1970 GR MWD API ~8.61 977.64 68.2845 1970 First Reading For Entire File .......... 10546 Last Reading For F. ntire File ........... 11565.5 File Trailer Service name ............. STSLIB.001 Service Sub Level, Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/14 ~ . Maxzmum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 10546 10581 10546 Last Reading 11565.5 11565.5 1.1530.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU 'FOOL CODE START DEPTH STOP DEPTH FET 10533.0 11155.5 RAT 10533.0 11155.5 GR 10533.0 11155.5 RPX 10533.0 11155.5 RPS 1{}533.0 11155.5 RPM 10533.0 11155.5 RPD 10533.0 11155,5 $ MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE 'FOP MWD 8 1 10533.0 $ REMARKS: MERGED MA[) PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefirled Frame Sp~cing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1, 68 0 1 RAT MAD FPH 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1. 68 20 6 RPD MAD OHMM 4 1. 68 24 7 FET MAD HR 4 1, 68 28 8 MERGE BASE 11155.5 Name Service Unit Min Max DEFT FT 10533 1.1155.5 RAT MAD FPH 55,55 839. '78 GR MAD AP1 17 417.28 RPX MAD OHMM 0.56 2000 RPS MAD OHHH 0.1 2000 RPM MAD OHMM 0.11 2000 RPD MAD OHMM 0.03 2000 FET MAD HR 116.284 200.677 Mean 10844.3 '713.524 68.0733 44.8381 46.0973 38.548]. 31.4148 148.266 First Reading For Entire File .......... 1.0533 Last Reading For Entire File ........... 1.1.1.55.5 File Trailer Service name ............. STSLIB.O02 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Nsam 1.246 1246 1,246 1246 1246 1246 1246 1246 First Reading ].0533 10533 1.0533 10533 1..0533 10533 10533 10533 Last Reading 11155.5 ].11.55.5 11155.5 11155.5 11155.5 11155.5 11155.5 11155.5 Physical EOF File Header Service name ............. STSLI~.003 Service Sub Level Name... Vet-sion Nun~ber ........... t.0.ID Date of Generation ....... 02/03/14 ?,Ia:,:imum Physical Record..65535 File T ~. ~e ................ LO Previous File Name ....... STSLIB.002 Commer~t Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMP~RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR ~0546.0 ]0687.5 ROP 10581.0 10723.0 $ LOG HEADER DATA DATE LOGGED: 07-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10723.0 TOP LOG INTERVAL (FT): 10550.0 BOTTOM LOG INTERVAL (FT): 10723.0 BlT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 32.0 M~XIMUM ANGLE: 45.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (PT): BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): .0 MUD PH: 8.5 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 11.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AY' MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCU'LATING TERMPERATURE: .000 124.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 ! 68 0 1 ROP MWD010 FPH 4 1 68 4 2 GR MWD010 AP1 4 1 68 8 3 Name Service Unit Min Ma.'.< Mean Nsam DEFT FT 10546 10723 10634.5 355 ROP MWD010 FPH 0.5 112.92 42.1188 285 GR MWDOiO API 34.16 977.64 .186. 395 284 First Reading For Entire File .......... 10546 Last Reading For Entire File ........... 10723 File Trailer Service name ............. STSLIB.O03 Service Sub Level Name... Version Number ........... 1.0.0 Date ef Generation ....... 02/03/14 Maximum Physical. Record..65535 File Tpe ................ LO Next File Name ........... STSLIB.004 First Reading 10546 10581 10546 Last Reading 10723 1{1723 10687.5 Physical EOF File Header Service name ............. STSLIB.O04 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/14 Maximum Physical. Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Conm~ent Record FILE HEADER FILE NUMBER: 4 RAW HWD Curves and log header data for each bit run in separate files. BlT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START' DEPTH STOP DEPTH GR 1_0688.0 10840.5 ROP 10723.5 10876.0 $ LOG HEADER DATA DATE LOGGED: 09-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10876.0 TOP LOG INTERVAl, (FT): 10723.0 BOTTOM LOG INTERVAl, (FT): 10876.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.6 MAXIMUM ANGLE: '78.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOl, TYPE TOOl, NUMBER NGP NATURAL GT~MA PROBE PB02100HWRG6 5:OREHOLE 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 Direcrh~ on ................. 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 3.750 F1 o Puc,/CWat ," 8.60 60.0 8.5 24000 8.4 · 000 .0 · 000 120.6 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 i 68 0 1 ROP MWD020 FPH 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10688 11.0876 10782 377 ROP MWD020 FPH 4.25 76.51 48.6284 306 GR MWD020 API 1.9.49 '730.54 59.6363 306 First Reading' For Eh'tire File .......... 10688 Last Reading For En'tire File ........... 10876 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/1.4 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Reading 10688 10'723.5 10688 Last Reading 10876 10876 .10840.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/14 Ma:.:imum Physical Record..65535 File Tx_~e ................ LO Previous File Name ....... STSLI~:.004 Comment Record FiLE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL, CODE START DEPTH STOP DEPTH GR 10841.0 11530.5 ROP 10876.5 11565.5 $ I~OG HEADER DATA DATE LOGGED: 10-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE 'VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11565.8 TOP LOG INTERVAL (FT): 10876.0 BOTTOM LOG INTERVAL (FT): 11565.8 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.1 MAXIMUM ANGI, E: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOl., CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN'): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: FloPro/Water MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 60.0 MUD PH: 8.0 MUD CHLORIDES (PPM): 1.6000 FLUID LOSS (C3): 1.0.6 RESISTIVITY (OHMM) AT TEMPERATU'RE (DEGF) MUD AT MEASURED TEMPERATURE (ME'): .000 .0 MUD AT MALX CIRCULATING TERMPER.ATURE: .000 133.0 MUD FILTRATE Al' MT: .000 .0 MUD CAKE AT MT': .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL, STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames c, er reco:'d ............. U¥~define,~ Absent value ...................... -999 Depth UniYs ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD030 FPH 4 1 68 4 2 GR MWD030 AP1 4 1 68 8 3 Name Service Llnit Min Plax Mean Nsam DEPT FT 10841 11565.5 112,03.3 1450 ROP MWD030 FPH 0.33 2259.89 93.1821 1379 GR MWD030 AP1 18.61 194.1.2 45.8953 1380 First Reading For Enti~e File .......... 10841 Last Reading For Entire File ........... 11565.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 First Reading 10841 1 0876.5 ].0841 Last Reading 11565.5 11565.!5 115361.5 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 8 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR 'FOOL CODE START DEPTH STOP DEPTH GR 10533.0 11155.5 FET 10533 0 11155.5 RPD 10533 0 11155.5 RPH 10533 0 11155.5 RPX 10533 0 1.11.55.5 RAT 10533 0 11155.5 RPS 10533 0 11155.5 $ LOG HEADER DATA DATE LOGGED: 15-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11565.8 TOP LOG INTER'VAL (ET): 10550.0 BOTTOM LOG INTERVAL (FT): 11565.8 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. REGIS. 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 CIRCUI, ATING 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 Specifi. cation 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 TOOL NUMBER 3. 750 FloPro 8.70 60. Iii 8.0 14400 6.8 Units Size Nsam Rep Code Offset Channel .220 66.0 .100 154.0 .230 66.0 .170 66.0 DE PT FT' 4 1 68 RAT MAD081 FPN 4 1 68 GR MAD081 AP1 4 1 68 R PX MA D 081 OHMM 4 i 68 RPS MAD081 OHMM 4 i 68 RPM MAD081 OHMM 4 1 68 RPD MAD081 OHMM 4 1 68 FET MAD08i HR 4 1 68 0 1 4 2 8 3 1.2 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 10533 11155.5 RAT MAD081 FPH 5!5.55 839.78 GR MAD081 API 1.'7 417.28 RPX MAD081 OHMM 0.56 2000 RPS MAD081 OHMM 0.1 2000 RPM MAD081 OHMM 0.11 2000 RPD MAD081 OHMM 0.03 2000 FET MAD081 HR 116.284 200.677 First Reading For E:n'ti~"e [!"J. le .......... 10533 Mean 1.0844.3 713.524 68.0733 44.8381 46.0973 38.5481 31.41.48 148.266 Psam 1246 1246 1246 1246 1.246 1246 1.246 1246 First Reading 10533 10533 10533 10533 10533 10533 10533 10533 Last Reading 11]_55.5 11155.5 11155 5 11155 5 1.1155 5 11155 5 11155 5 11155 5 Last Reading For Entire File ........... 11155.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/'14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/03/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. L!STPE Date ..................... 02/03/14 Origin ................... STS Reel Name ................ UNKNOWN Continuatien Number ...... 01 Next Reel. Name ........... UNKNOWN Cemments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File