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202-219
By Samantha Carlisle at 9:49 am, Aug 15, 2022 David Douglas Hilcorp North Slope Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 02/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL (23-FEB-2022) Folder Contents: Log Print Files, Reports and Digital Data Files: Well API #PTD #Log Company Log Date Log Type Notes: PBU L-207 50029237020000 221081 HALLIBURTON 1/12/2022 PPROF INCLUDES ANALYSIS PBU 04-51 50029235970000 218018 BAKER 11//24/2021 RPM INCLUDES ANALYSIS PBU 09-38 50029219190000 189021 BAKER 12/1/2021 RPM INCLUDES ANALYSIS PBU 09-39 50029221330000 191012 BAKER 12/6/2021 RPM INCLUDES ANALYSIS PBU 18-02C 50029207620300 213009 BAKER 11/25/2021 RPM INCLUDES ANALYSIS PBU 18-03C 50029207760300 211066 BAKER 11/26/2021 RPM INCLUDES ANALYSIS PBU 18-05A 50029215830100 202219 BAKER 12/8/2021 RPM INCLUDES ANALYSIS PBU Z-32C 50029219240300 213127 BAKER 12/10/2021 RPM INCLUDES ANALYSIS Please include current contact information if different from above. 202-219 T36373 PBU 18-05A 50029215830100 202219 BAKER 12/8/2021 RPM INCLUDES ANALYSIS Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.02.25 08:36:20 -09'00' BAF�UGHES PRINT DISTRIBUTION LIST a GE company COMPANY BP Exploration Alaska Inc. WELL NAME 18-05A FIELD Prudhoe Bay Unit COUNTY North BHI DISTRICT Alaska AUTHORIZED BY Dirk Zeijlemaker EMAIL Dirk.zeiilemakeranbakerhughes.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V No 20 22 19 3 134 1 Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, L132-1 900 E. Benson Blvd. Anchorage, Alaska 99508 or AKGDMINTERNAL@bp.com to acknowledge receipt of this data. LOG TYPE RPM:PNC3D LOG DATE September 9, 2019 TODAYS DATE October 18. 2019 Revision Details: Rev. Requested by: --- FIELDI FINALCD/DVD FINAL PRELIM LOGS (las, dlis. PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) #OF PRINTS #OF COPI ES I#OFCOPIES I#OFCOPIES J; 4 4 I BP North Slope. LOA. PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Burka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. .Attn: Ricky Elgarico ATO 3-344 700 G Street OCT 2 2 2019 Anchorage, AK 99501 _ _ AO G C Q 3 1 Exxon Mobil, Alaska Attn: Lynda M. Yaskell and/or Lisa Boggs 3201 C Street, Suite 505 Anchorage, AK 99503 41 State of Alaska -AOGCC 1 1 1 Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 51 DNR - Division of Oil & Gas *** 1 Attn: Garret Brown I, 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: David Itter 0 4 9 TOTALS FOR THIS PAGE: 0 1 4 0 0 • STATE OF ALASKA RECEIVED AL KA OIL AND GAS CONSERVATION COMMIooION NOV 21 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U' Other UAOG CC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time ExtensionE Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 202-219-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21583-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028307 ' PBU 18-05A • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL- 11.Present Well Condition Summary: 1 Total Depth measured 13656 feet Plugs measured 12699 feet true vertical 8764.55 feet Junk measured 13561 feet Effective Depth measured 12699 feet Packer measured See Attachment feet true vertical 8759.22 feet true vertical See Attachment feet • Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 25.65-105.65 25.65-105.65 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10234.55 9-5/8"47#L-80 29.45-10264 29.45-8264.16 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12165-12185 feet 12275-12295 feet 12320-12340 feet 12340-12360 feet 12530-12670 feet 12770-13250 feet 13320-13560 feet True Vertical depth 8752.26-8754.42 feet 8760.93-8761.7 feet 8762.61-8763.36 feet 8763.36-8763.87 feet 8760.53-8759.49 feet 8758.39-8750.07 feet 8752.08-8761.25 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN 2 ,' •,(n4 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 518 7190 6 0 305 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Ei • Gas U WDSPIU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCCI 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garrv.CatronL_BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 11/21/2013 fie Vi- !� �/ / RB! M- NOV 2 1 ;�=1\ Form 10-404 Revised 10/2012 `/G �/i4 Submit Original Only a) U CO '-' U C a) a) a3 a43 OY - a r) o, N ° ECoo co o= ao H M C? ch co .(1 Y N ` CO CO L_ 03 0:1 a) O C' co � r r E V co Cf) Q N N � ti O N y O N O) O) 0 O f- f- a0 cn O to J Q co cp CD C co 00 N 2 NOOO) a0ig V M 0 0 CQ CL ceWrrce O. )i0000 F < < 4: < aaaa w E < < < < z9999 3co aococo U) ,• o00000000 • r NCD CO Cr) N00 O Uf) N. N CO CC) 10 C V 00) Ott COO C) ON. O COQ) C) C) • �h N CO N 0) Tr m N. co CO CO Cr) V' CO CO � CO � — 0) CO 0)) CCD• O CO O N Ch CD CD N Cr)0 N. O co c° co 0N0 0 N co o0 co c • OMO ' co co O CONCOco a> NCh0 N0 CV co .1+ CD N O U) NI- CD CC) 070 CO U') O CO CON . ' N. ' M 0 co co 0) 00) M CO N- CO C N— N- 0) r- C� N NM0cooi CO NN- C O C 7 I— O Q 000 O to co CO w U = co co J !� J y ilk N N. E N N N. O - CO 03 Cfl O• E. E. N 14,) M - N C� Cr) Cr) N NI- .0 Ln (NJ co 0)0 00 coo co O M N L J co cr CO N. O CNI co N OO)) z 0 MDC‘ CLCLDlailu_ ZZ v Z w w w O ce m m O Z Z Z D D D D UM CL (/) CAHH • N 2 \ o $ % E \ \ % E ƒ % \ t ° 5 c o_,.t ( § -' 0.» r a = ~ 2 = _ � � _ / A .K7 \ » � / bt -CO � 0$ / / \ \ / R » = g E o / j / `- / O k \ n > Ia § / = aw / � / \ 72 33 -0 c I E \ e I . c / & E 0 / � � u - _/ / / 0 -% o -1 f ® / 5 S b j,),._ / / f U) a _ /% _ e a + 2 bE § (Ni Lo/ f $ oe \ § 7 m e / _ " IP / \ 0 - / / ƒ K w c k 0 @ & 2 / c 2 £ J o O O � i R � CS>X 0 \ 0 I = o N M ¥ : \ 3gE2 \ 3 { I o\ 0_ CNI / \ \ 7 \ / &0_ a) o . ) O/ \ O (- C e - \ / g O o o < ƒ - c 9 ƒ \ °/ / \ \ N. 9 ± / \ a_ / ° a » ° ° E 0 ƒ 2 / / CC ƒ q ,„>,co ± 6 ± ƒ 't % m § o m . . U = � � ea ± m . . me © /E _ k G = / m \ E CI) 0- o X % o e = o m ° ƒ E o - \ o § u \ W E o w = CD CI \ » r $ / � / ?�� & \ _ § / \ \ ¥ \ A o m = ' I � .R m = m 2 = r E m _ 0 \ § / \ \ q ƒ \ § ± 7 \ / / / $ G / - 7 « S I e ® \ ) 2 = 7 7 5 3 % n E ® 2 > 0 « ® l / £ 1-- o § # » � ^ E \ S ° / / / ° S \ CO a 0 ® / ' 0 f a) E / \ U o _01 0) % 7 / b \ H - 0 cC v / / o =\ \ e \ o v * / - o o v U E v t U G@ m g 4 CC -o v ! U CC t 2 c v \ m n r � 3 3\ C a e (NJ / \ 0 0 a TRIM= aw .WELLHEAD FMS 18 0 5A SAr__!NOTES:WELL ANGLE>70°@ 10404'. ACTUATOR= BAKER "`CHROMETBG"` INITIAL KB.Ell 46.5' BF.ELEV= 20.8' ( LI KOP= 1400' 2001' -141/T HES X NP,D=3.813' Max Angle= 93°©12423' Datum M3= 16,038' Datum TVD= 8800'SS L 3221' -19-5/8"X 7"ZXP LW,D=6.24' 13-3/8"CSG,68#,L-80 K-55/72#,D=12.34T --j 3008' f4 .1 3239' X 7"BKR FLEXLOCK �� �,� 1LNRHGR,D=6.30' .. 11j GAS LFT MANDRELS � • # 11 ST MD 1VD DEV TYPE VLV LATCH PORT DATE �/ 1v1 -4 3225 3007 40 KBG2 DOME BK 16 05/03/13 --_- ∎# 1•1 3 5799 4893 41 KBG2 SO BK 20 05/03/13 Minimum ID = 3.725" @ 9873' of ► OW 11 2 7755 6434 35 KBG2 O BK 0 05/02/13 HES XN NIPPLE 1� 1' ,4 1 9554 7859 44 KBG2 OW BK 0 05/02/13 • • 7919-1 9-5/8"X 7"BKR A LNR HGR T SCAB LNR 26#,L-80,D=6.276" 7927' '# 1 ■1 11 9664' -I41/2"HES X NP,D=3.813" 1 o#►_ _�1� 9685' I I T X 4-112"BKR S-3 PKR,ID=3.875" 1� 1• •� ,!� I 9709' H41/2"HES X NP,D=3.813' 44 1 4-1/2"TBG,12.6#,13CR-80 VAM TOP, -I 9772' - ,' �1 9786' -14-1/2"UNIQUE OVERSHOT 0152 bpf,D=3.958" '�� '' �� 1.1 9807' -14-1/2"HES X Imo,D=3.813" I 41/2'TBG STIR(08/31108) H 9777' •4�4 CIA I 9828' H7"X 4-1/2'BKR S-3 PKR,D=3.875' I .4 A 9852' H4-1/2"HES X NP,D=3.813" I o. ' 9873' H4-1/2'HES XN NP,D=3.725' 1 11 111 •1 (• 9865' --17"X 5"BKR ZXP LNT TOP FKR 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958"1-1 9885' rA■ ►i 9885' -14-1I2"WLEG,D=3.958' 9-5/8"CSG,47#,L-80,D=8.681" --I 10264' • • 9926' H0-5/8"X 7-5/8"BKR A LNR HGR WHPSTOCK -1 11622' 9935' H7"BKR?HACK SEAL ASSY I PERFORATION SUNS/ARV FALLOUT WNDOW(18-05A) 11604'-11621' REF LOG: MOD BAR-GR ON 12/06/02 ANGLE AT TOP FERF:84°©12165' 11694' H 41/2"MARKER JOINT Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 12165-12185 0 10/26/13 12699' 41/2'HES CBP 2-7/8" 6 12275-12295 O 10/26/13 � �(02/21/13) 2-7/8' 6 12320-12340 0 03/07/13 2-7/8" 6 12340-12360 0 02/21/13 111111i1 •• 1%/' Ir 2-1/2" 4 12530-12670 O 12/15/02 111111 111111•4 2-1/2" 4 12770-13250 C 12/15/02 11111 1 /� 2-1/T 4 13320-13560 C 12/15/02 •1//111/ I/ 1111111 t 11 FIST FASDRLL -I 13561' A,�� 11111 PLUG PUSHED 11111111 • :•• PM H 13571' I ■■•■•■• 7"LNR,29#,L-80,D=6.184" 12500' :4.421.4.! DOWN(10/09/08) .■ 4-1/2'LW,12.6#,L-80,.0152 bpf,D=3.958"H 13656' 4-1/2"LNR,12.6#,L-80,.0152 bpi,D=3.958' 12965' DATE REV BY COM ENTS DATE COMMU'1T5 PRUD OE BAY UNIT 07/09/86 INITIAL COMPLETION 03/08/13 TAQ/,SA3 ADFERF(03/07/13) WELL: 18-05A 12/16/02 WNW RIG SIDETRACK(18-05A) 03/08/13 JMD GLM ND REVEW PERINT No: 2022190 10/13/08 D14 RWO 03722/13 TBLYJMD GLV C/O(03/14/13) AR No: 50-029-21583-01 07/13/09 AW/JMD DRLG DRAFT CORRECTIONS 05/14/13 CJNJMD GLV CIO(05/02-03/13) SEC 24,T11 N,R14E,952'FNL 8 221'FEL 02/25/13 RWAN PJC ADPERF/CEP(02/21/13) 11/06/13 CRR/JMO ADFERFS(10/25-26/13) 03/08/13 JAI) ADPERF CORRECTIONS BP Exploration(Alaska) STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COM ON i' . . c.0 REPORT OF SUNDRY WELL OPERATIONS AOGGC 1. Operations Abandon U Repair Well U Plug Perforations (J Perforate [ J Other „ C t Q p Performed: Alter Casing ❑ Pull TubingD Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. ShutdownD Stimulate - Other ❑ Re -enter Suspended Wetl❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: BP Exploration (Alaska), Inc Name: Development El Exploratory ❑ 4 202 -219 -0 3. Address: P.O. Box 196612 Stratigraphk❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21583 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028307 * PBU 18 -05A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): P To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 13656 feet Plugs measured 12699 feet true vertical 8764.55 feet Junk measured 13561 feet Effective Depth measured 12699 feet Packer measured See Attachment feet true vertical 8759.22 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 84 20" Conductor 26 - 110 26 - 110 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10240 9 -5/8" 47# L -80 24 - 10264 24 - 8264.16 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12320 - 12340 feet 12340 - 12360 feet 12530 - 12670 feet 12770 - 13250 feet 13320 - 13560 feet True Vertical depth 8762.61 - 8763.36 feet 8763.36 - 8763.87 feet 8760 53 - 8759.49 feet 8758.39 - 8750.07 feet 8752.08 - 8761.25 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCA APR 1 6 2013 Treatment descriptions including volumes used and final pressure: SCANNED 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 580 48422 15 0 1045 Subsequent to operation: 653 8913 7 0 249 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 ` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . El Gas ❑ WDSPt.0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summer Printed Name Nita Summer -ys Title Petrotechnical Data Technician Siva" 402 ' i � 1 j i�...__ Phone 564 -4035 Date 3/27/2013 RBDMS MAR 2 8 2013 • ` \,\ \(1/ Form 10 -404 Revised 10/2012 �7/2 Submit Original Only • • Daily Report of Well Operations ADL0028307 ACTIVITYDATE I SUMMARY - '� TT • 1 . - - Y' pre - e- me - a • pe DRIFT W/ 3.375" x 10' DUMMY GUN. STOP DUE TO DEVIATION @ 10,449' SLM. (no obstructions) TARGET DEPTH = 10,400' SLM. 9/15/2012 ** *WELL S/I ON DEPARTURE, PAD -OP NOTIFIED * ** ***WELL SHUT IN ON ARRIVAL * ** (ELINE TRACTOR / PLUG / PERF) INITIAL T /I /O = 150/0/0 RUN 1: TRACTOR DRIFT WITH 2 -7/8" 20FT DUMMY GUN AND 3.7" GAUGE RING HANG UP IN XN NIP AT 9873'. TRACTOR UP OUT OF IT. TAKE OFF GAUGE RING. FIND COVERED IN TAR AND METAL SHAVINGS. MIC AT 3.726" WITH COVERINGS ON IT. 3.70" CLEANED OFF. WELL LEFT SI ON DEPARTURE. FINAL T /I /O = 150/0/0 2/13/2013 * ** JOB POSTPONED FOR BRUSH AND FLUSH * ** 2/14/2013 Assist SSL with brush & flush (pre E -line) ** *WELL SHUT -IN ON ARRIVAL * ** (profile -mod) RIG UP SWCP 4519 FOR PRE E -LINE WORK 2/14/2013 ** *CONT. WSR ON 2- 15 -13 * ** * * *CONT. WSR FROM 2- 14 -13 * ** (pre -e- line- adpreflset cibp) BRUSH & FLUSH TBG TO DEVIATION AT 10,443' SLM W/ 4 -1/2" BLB & 3.70" G. RING LRS PUMPED 180 BBLS OF 180* DIESEL DOWN TBG DRIFT W/ 3.70" CENT, 3 -3/8" x 20" DMY GUN W /3" SAMPLE BAILER, STOP DUE TO DEVIATION @ 10,292' SLM 2/15/2013 ** *WELL LEFT S/I DSO NOTIFIED ON DEPARTURE * ** T /I /O= 150/50/0 Temp =S1 Assist SSL with brush & f[ush (Pre E -line) Pumped 5 bbls meth spear followed by 180 bbls of 180* diesel down tubing while slickline ran brush. Slickline on 2/15/2013 well upon departure. FWHP's= 700/81/16. ** *JOB IN PROGRESS * ** (E -LINE: TRACTOR DRIFT /PLUG) RUN 1: DRIFT DOWN TO 10400' AND THEN TRACTORED DOWN TO 12850'. RUN 2: SET HALIBURTON 4 -1/2" CIBP. PLUG AT 12700' MID - ELEMENT. CCL TO MID - ELEMENT = 15.67'. TOP OF PLUG = 12699' 2/20/2013 * ** JOB CONTINUED ON 21 -FEB -2013 * ** 2/21/2013 Assist E -Line - Job postponed due weather. * ** JOB CONTINUED FROM 20- FEB -2013 * ** COMPLETE PLUG SETTING. UNSTAB AND REPRESSURE TEST. ARM 1ST GUN AND RIH. RUN 3: PERFORATE INTERVAL BETWEEN 12340' - 12360' WITH 2 -7/8" PJOMEGA CHARGES. CCL TO TOP SHOT = 11.5 FT, CCL STOP DEPTH = 12328.5 FT. CORRELATED TO SPERRY MWD- EWR -GR LOG DATED 06- DEC -02. SHOT CONFIRMED AT SURFACE. OPERATIONS SHUT DOWN DUE TO WEATHER. STANDBY AND MONITOR WEATHER. 2/21/2013 ** *JOB CONTINUED ON 22- FEB - 2013 * ** * ** JOB CONTINUED FROM 21 -FEB -2013 * ** * *JOB STANDBY DUE TO WEATHER ** 2/22/2013 ** *JOB CONTINUED ON 23- FEB - 2013 * ** • • Daily Report of Well Operations ADL0028307 * ** JOB CONTINUED FROM 22- FEB -2013 * ** STANDBY FOR WEATHER DECISION MADE TO RIG DOWN EQUIPMENT AND TAKE BACK TO SHOP DUE TO FIELD GOING TO PHASE 2 CONDITONS * * * ** *WILL RETURN AFTER WEATHER CONDITION IMPROVE TO RUN 2ND AND FINAL GUN RUN * * * * * * ** FINAL T /I /0= 250/40/0 WELL SHUT IN ON DEPARTURE - NOTIFIED DSO OF WELL STATUS 2/23/2013 ** *JOB POSTPONED * ** T /I /O = 393/74/15 Temp = S/I Load & Kill TBG. Unit 42 pumped 15 bbls Dead Crude in 2/28/2013 RDMO. Unit 46 pumped an additional 52 bbls Dead Crude. * * *WSR continued to 3- 1 -13 * ** T71 /0= 200/40/0 Temp= SI Flush Tubing (perfs) Speared into Tbg w/ 3 bbls 60/40 methanol followed by 15 bbls crude. Mechanical issues. Job incomplete. 2/28/2013 FWHP's= 200/40/0 SV, WV, SSV= SI MV= 0 IA & OA= OTG. * * *WSR continued from 2- 2B -13 * ** Pumped an additional 33 bbls Dead Crude to load TBG. Well S/I notified DSO upon departure. FWHP = 1273/123/17 SV/W /SSV = C M = 0 IA/OA = OTG 3/1/2013 ** *WELL SHUT -IN UPON ARRIVAL * ** (ELINE TRACTOR ADPERF) INITIAL T /I /O = 200/75/0 PSI RIH W/ TUFFTRAC TRACTOR, 2.75" JUNK BASKET AND 3.498" GAUGE RING. DRIFT TO 12370'. UNABLE TO TRACTOR FURTHER. RIH W/ TUFFTRAC TRACTOR AND 20' OF 2 -7/8" PJO PERF GUN (6 SPF / 60 DEG GUN). SET DOWN AT 10375' AND BEGAN TRACTORING. 3/6/2013 ** *JOB CONTINUED ON 7- MARCH - 2013 * ** ** *JOB CONTINUED FROM 6- MARCH- 2013 * ** (ELINE TRACTOR ADPERF) CONTINUE TRACTORING W/ TUFFTRAC TRACTOR AND 20' OF 2 -7/8" PJO PERF GUN DOWN TO 12400' SHOT PERFORATION INTERVAL = 12320'- 12340' - CORRELATED TO SLB PLUG /PERFORATION RECORD DATED 21 -FEB -2013. CONFIRMED GOOD SHOT AT SURFACE. POOH. FINAL T /I /O = 220/75/0 PSI 3/7/2013 ** *JOB COMPLETE. WELL SHUT -IN UPON DEPARTURE * ** FLUIDS PUMPED BBLS 186 DIESEL 5 METH 85 DEAD CRUDE 3 60/40 METH 279 TOTAL Casing / Tubing Attachment ADL0028307 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 20" Conductor 26 - 110 26 - 110 LINER 6714 7" 26# L -80 3221 - 9935 3003.65 - 8103.05 7240 5410 LINER 3796 4 -1/2" 12.6# L -80 9860 - 13656 8059.82 - 8764.55 8430 7500 LINER 1686 7" 29# L -80 9935 - 11621 8103.05 - 8634.91 8160 7020 PRODUCTION 10240 9 -5/8" 47# L -80 24 - 10264 24 - 8264.16 6870 4760 SURFACE 38 13 -3/8" 68# L -80 25 - 63 25 - 63 5020 2260 SURFACE 2945 13 -3/8" 68# K -55 63 - 3008 63 - 2838.39 3450 1950 TUBING 9763 4 -1/2" 12.6# 13Cr80 23 - 9786 23 - 8015 8430 7500 TUBING 99 4 -1/2" 12.6# L -80 9786 - 9885 8015 - 8074.48 8430 7500 • . • • Packers and SSV's Attachment ADL0028307 SW Name Type MD TVD Depscription 18 -05A PACKER 3221 2957.2 7" Top Packer 18 -05A PACKER 9685 7903.59 4 -1/2" Baker S -3 Perm Packer 18 -05A PACKER 9852 8008.63 4 -1/2" Baker S -3 Perm Packer 18 -05A PACKER 9865 8016.32 5" Baker ZXP Top Packer TREE= CIW 18-05A S. NOTES: WELL ANGLE> 70° a 10404•. WE3 LHEAD= FMC ACTUATOR = BAKER C *° °CHROMETBG :.« MTIAL KB. 8.1 46.5' F. B. BE _ 20.8' I i l LI KOP= 1400' Max Angle = 93° n 72423' ( 2001' H4 -1/2" FES X NP, D = 3.813" I Datum M = _ 16,038' Datum TVD = 8800' SS 3221' 1.52• X 7" ZXP LIP, D = 6.24° I 13-3/8° CSG, 68#, 1-80 K -55 / 72 #, D = 12.347" H 3008' 3239• I. — 9-5E" X 7" BKR FLEXLOCK • 1� � 1 � LNRHGR D = 6.30" 4 111 GAS UFT MANDRELS 4 1!, 1 ST I MD TVD I DEV TYPE ( VLV LATCH PORT DATE 1'1 4 3225 3007 40 KBG2 DOME BK 16 03/14/13 Minimum ID = 3 °725" ' 9873' i 0.* * m 1i 3 5799 4893 41 KBG2 SO BK 20 03/14/13 4 -'I /2" HES XN NIPPLE o� r11 2 77 6434 35 K MY BG2 D BK 0 10/12/08 9 ' 7 1 9554 7859 44 KBG2 OW BK 0 10/12/08 o i � 1 4 1 7919' H9 -5/8' X 7" BKR A LNR HGR I 17" SCAB LER 20#, L-80, D = 6.276" 7927' 1� / #i A I 9664' H4 -1/2" HES X NP, D= 3.813" I '1►_ • _4/ 1 9685' H7" X 4-1/2" BKR S-3 PKR, D = 3.875" I • o • 1 4 i I ■1 94 t 9709' H 4 -112" FEESXNIP, D= 3.813" r ►1 4-1/2"113G, 12.6#, 13C14,80 VAM TOP, 9772' 'A � • 1 9786' 4-112 UNt2t1EC?VBiSFFOT 0152bpf, D =3.958" � i 1 j � 1�1 ,111 I 9807' I - I4 -1/2' FES X INF, D = 3.813" I (4 -112" TBG STtB (08/31/08) I 977T j ', _.;i� 9828' H r X 4 -1/2" BKR S3 PKR, D = 3.875" I ■ 4 � M 9852° H 4- 112" HES X NP, D = 3.813" I r1 9873' H4-1/2" FES XN NP, D = 3.725" I 9 4 1 • 1 11 9865" Hr xs" BKR ZXP MI TOP A(R I 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" H 9885' �i ' - 1 9885' H4 -1/2" WLEG, D = 3.958" I 9926' — I9 - 5/8" X 7 - 5/8" BKR A L.PR FGR I 19-5/8" CSG, 47#, L-80, 13= 8.681" I-I 10264' I 9935' Hr BM TIEBACK SEAL ASSY I V1FSTOCK 11622' I MLWINDOW LOUT WINDOW (18 -05A) 11604' - 11621' PERFORATION RATION S&JN7MARY 11694' 4-1/2" MARKER Jam I REF LOG: MW) EWR-GR ON 12/06/02 / - __ __ ANGLE AT TOP PERE: 88° a 12320' Note: Refer to Production DB for historical pert data I 1 ( 12699' — 4-1/2" FES f SIZE Sl • . SHOT SC1Z / (02/21/13) \ 2 -7/8' 6 12320 - 12340 0 03/07/13 - 2 -7/8" 6 12340 - 12360 0 02/21/13 . rAy1vi 11111 `� 1 2 -1/2" 12 0 e . 1111' 2 -1/2" 4 12770 - 13250 C 12/15/02 �1111111� •1•1••1• .. 2 -1/2" 4 13320 - 13560 C 12/15/02 1111 �/ 1�1 * * • ■ FISR FASDRLL H 13561' ` . /11 PLUG PUSHED • A•• / V . 41 PBTD 13571 j '�" 17" Wit 29#, L -80, ND= 6.184' 12500' �1�4�� DOWN (10109!08) 4-1/2" LW, 12.6#, L-80_0152 bpf, D = 3.958" I-I 13656° I4 -1/2" LNP; 12.6#, L -80, .0152 bpf, D = 3.958' H 12965' DATE REV BY COMVENTS DATE COMFITS PRUDHOE BAY UNT' 07/09/86 ORIGINAL COMPLETION 03/08/13 JMD ADPERF CORRECTIONS WELL: 18-05A 12/16/02 DOW/KK RIG SIDETRACK (18 -05A) 03/08/13 TAQIJM) ADPE RF (03/07/13) FERMI No: "2022190 10/13/08 014 IMO 03/08/13 JMD GL.MTVDREVEBW API No: 50-029-21583-01 11/10/08 KDC/SV GLV C/O (10/22/08) 03/22/13 TBLYJMO ow CIO (03/14/13) SEC 24, T11N, R14E 952 FNL & 221' FEL 07/13/09 AW/JM) DR..G DRAFT CORRECTIONS 02/25/13 RVVM PJC ADPERF/ CEP(02/21/13) BP Exploration (Alaska) i STATE OF ALASKA '~ ALA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ^Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ~ ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-219 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21583-01-00- 7. KB Elevation (ft): ~ 45, , 9. Well Name and Number: PBU 18-05A 8. Property Designation: 10. Field /Pool(s): ADL 028307 ~ Prudhoe Bay Field / Prudhoe Bay Pooi 11. Present well condition summary Total depth: measured 13656 ~ feet true vertical 8765 ~ feet Plugs (measured) None Effective depth: measured 13571 feet Junk (measured) 11694 true vertical 8762 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2974' 13-3/8" 3008' 2838' 4930 ~ 2670 Intermediate 10232' 9-5/8" 10264' 8264' 6870 4760 Production Liner 3685' 7" 3221' - 11604' 3004' - 8631' 8160 7020 Liner 3791' 4-1/2" 8063' - 8765' 8430 7500 9865' - 1365 6 ' ~~ gg qq ~,,11 acs ~dtlC..S.~ ,~ ~ j ~` ;~ 2QG Perforation Depth MD (ft): 12530' - 13560' Perforation Depth TVD (ft): 8761' - 8761' 4-1/2", 12.6# 13Cr-80 / L-80 9885' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 41/2" Baker'S-3' packers 9685' & 9828' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 9778'. Run 7" (26#, L-80) tieback from 3221' to 7927'. Cement w/ 144 bbls Class 'G' w/Gas-Blok (809 cu ft / 691 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Welt Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras Worthington, 564-4102 307-295 Printed Name Sondra Stewman Title Drilling Technologist 11 tt ~ ~ ],~/ Prepared By Name/Number. - -~ ` S Sig lure ~,/ Phone 564-4750 DateV{ [ bSondra tewman 564-4750 Form 10-404 Revised 04/200- - ~} , ~ ~~' 1.. G _C ~ ~ 2~~8 ~ Submit Original Only ~~ TREE = FMC ~t-°s~r L HEA D = FMc nG I ~1n TQR = AXEL$ON KB. ELEV = 46.5` BF. ELEV.- _ ~D_S' KOP - 1400' Max Angle =~ 93 ~D 12423' [3'alum MD = _ NfA _ ~ _ C?atumTVD= 8800`55 ~ ~ SAQ7'E~: 18-05A ' CSG, 681f, K 55 i 72#, L-80, ID =12.347"' ~ 3Q0$' 7" x 9-5/8" BAKER LNR HGR 3221 MrnrmUm (d = 3.?25" ~ 9$73' ~-'~~~~~ HE5 ~~ N~PpLE 7" SCA B LNR, 26#, L-80, ID = 6.276" 7927 4-1/2" x 7" UNIQUE OVERSHOT, ID = 4.00" ~ 9772 TUBING STUB (08/31/08) 9777' 4-112" TBG, 12.6#; L-80, .0152 bpf, ID = 3.9558" 9-518" CSC, 47#', L-84, ID = 8.681'" ] 10264' UVHIPSTOCK -~ 1 X22' PERFORATION SUNIVtARY REF LOG: MUVt] EWR-GR pN 12106!02 ANGLEATTUPf'ERF: 91 ~ 12530` Piote: Refe[ to Production DB for historical perf data ..... SfLE SPF INTERVAL OpniSgz DATE 2-1 f2" 4 t 2530 - 1 2670 +J 12/15102 2-1 t2" 4 12770 - 13250 O 12115102 2-1 P2" 4 13320 - 13560 C7 12/15/02 7'" LNR, 29#, L-84, ID = 6.i 84" 125Q0' 1l2" LNR, 12.6#, L-80, .0152'. bpf, ID = 3.958" 1'[594' ~-•] MARKER JOINT ~~ -t 13571 i2" LNR., 126#, L-80, ,0152 bpf, ID = 3.958" 1365 DATE. REV BY COMMENTS DATE COIVXVIENTS Q7/08l86 ORIGINAL COMPLETION '/2(15/Q2 DDWIKK WCa 51l~TRACK (1$-OSAy X011310$ Did. RENO ~UDHOE BAY UNIT WELL: 18-45A Pi-~vNltT tdo:1022190 API No: 50-429-21583-01 SEC 24, T11 N, R14E, 952' FNL &:221.' FEL BP Fxploratian (Ataska:y 2001' 4-112" HES X NIP, ID = 3.813" GAS LtFTMANDRELS ST' MD TVD DEV TYPE VLV LATCH PORT' DATE 4 3225' 3007 40 KBG2 ' DCK BK 4 10f1210 3 5799 ' 4893 41 KBG2 DMY BK 4 10t121G8 2 7755 ' F,434 35 KBG2 ' DNIY BK 0 10/12/08 1 9554 7859 44 KBG2 DMY BK 0 10112rD8 79~- 9664 9685 9709 9807` i9-5/8" x /" t3Kl~ A LNI-Z tiUFt 4-1/2" HES X NIP, ID = 3.813" 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 4-1 /2" HES X NIP, ID = 3.813" 9828" 7"X4-112" BKR S-3 F'KR, ID = 3.875.' 9852' - ~ 4-1 t2'" HE5 X NIP, iD = 3.813 X873' 4-1 r2° tl=s XN NIP, ID = 3.75" 9885' - { 4-1 J2" WLEG, to = 3.958" 9855` 7" X 5" BKR ZXP LNR TOP PKR 9926 9-5J8°' X 7-518" BKR A LNR HGf2 99$5" 7'" BKR TIEBACK SEAL ASSY Iv1LLOUT V~IND04V 11604' - 11621' Page 1 `of 3 Well: 18-05 Well History Well Date Summary 18-05A 8/27/2008 T/IA/OA= 0/0/0 Temp=cold PPPOT-T (PASS) PPOT-IC (PASS) (Pre Rig) PPPOT-T RU 2 HP BT onto THA test void, 50 psi to 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment, cycled all LDS "Standard" ran out 1.0" and ran in and torqued, all functioned with no problems. PPPOT-IC RU 2 HP BT onto IC test void, 0 psi in void, flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3400/ 15 minutes, 3350/ 30 minutes. Bled void to 0 psi, RD test equipment, cycled all LDS "Standard" ran out 1.0" and ran in and torqued, all functioned with no problems. 18-05A 8/28/2008 ***WELL S/I ON ARRIVAL*'* (pre rwo) RAN 3.855" GUAGE RING...SD C~ 45' SLM, UNABLE TO WORK PAST. RAN 3.80" CENT., SAMPLE BAILER TO 2130' SLM...NO RECOVERY. RAN 3.805" GUAGE RING TO WRDP-1 C~ 2168' SLM V11/ NO RESTRICTIONS. RAN 3.84" CENT. TO WRDP-1 @ 2168' SLM W/ NO RESTRICTIONS. *'*CONT. JOB ON 08/29/08 WSR*** 18-05A 8/29/2008 T/I/0=1950/0+/0+. Temp=Sl. TBG & IA FL (FB). TBG FL @ 8637' (sta #3, 132 bbl). IA FL ~ 30' (1.6 bbl). SV, WV, SSV=Closed. MV=Open. IA&OA=OTG. NOVP. 18-05A 8/29/2008 ***CONT. JOB FROM 08/28/08 WSR*** (pre rwo) ***LEFT WELL S/I, TURNED WELL OVER TO DSO'** 18-05A 8/31/2008 T/I/0=1850/0/100 Temp=Sl Assist E-line. Load Tbg (Pre RWO). Pumped 3 bbls meth, 303 bbls crude down Tbg to load. Final WHPs 300/0/100 IA/OA casing valves open to gauges, E-line still on well at time of departure. 18-05A 8/31/2008 T/I/0=70/0/80 Temp=Sl Assist E-line, MIT T PASSED to 3500 psi (Pre RWOI Pressured up Tbg to 3500 psi with 3.4 bbls crude. Tbg lost 200 psi in1 st 15 min and 90 psi in 2nd 15 min for total loss of 290 psi in 30 min. Bleed back 2.8 bbls from Tbg. FWHP's=40/20/60. Valve positions at departure: Wing, Companion and Swab are closed, SSV, Master, and Annular valves are open. E-Line still on location at LRS departure. 18-05A 8/31/2008 ***WELL SHUT-IN ON ARRIVAL*** T/I/0= 2000/0/0 LRS LOADED WELL W/ 303 BBLS CRUDE. SET 4-1 /2" HES FASDRI BRIDGE PLUG MI ELEMENT 10 0 ' IN - IT-T TO 3500 PSI PASSED....SEE LRS WSR. JET CUT 4-1/2" TBG @ 9 777' AS PER PROGRAM. ALLY 11-DEC-2002 FOR FASDRIL REFERENCED TBG TALLY 15-DEC-2002 FOR JET CUT. SWAB & WING VLV'S CLOSED, CASING VLV'S OPEN TO GAUGES ON DEPARTURE. FINAL T/I/0= 25/0/100 '**JOB COMPLETE, WELL LEFT S/I*** 18-05A 9/3/2008 T/I/0= Temp=Sl 70/0/100 Circ out, [Pre RWO ]Attempted CIRC out. Started pumping down Tbg with neat meth spear at .5 bpm and pumped 1.89 bbls before reaching a Tbg psi of 2000 psi SD down Pump.and monitored WHPs. 2000/0/100 No communication between Tbg. and IA. call Full bore PE. Resumed pumping at .5 bpm until tubing pressure of 3500 psi was reached with a total of 3.25 bbls pumped. Tbg psi bled off 500 psi to 3000 psi . in 15 minutes. Noticed Control line for SSSV on front of tree tracking with Tbg psi. Bled down Tbg psi to 160 psi and RD off of companion on tree and RU on IA . Pum ed 5 bbls neat down IA at .6 b m reachin a in'ection ressure of 550 si throw h hole in PC. Switched to crude and increased pump rate to 2 pm or 5 s wit a sta a psi o 0 psi into PC leak.with a 90 psi pressure increase on tbg. SD pump and RDMOW FWP's=160/40/100 All annulus casing valves left open to guages. Swab Closed, SSV closed, Master open ,Wing Closed , IA open , OA open 18-05A 9/4/2008 ***WELL SHUT IN ON ARRIVAL*** SET 4.5" SLIP STOP CATCHER C~3 9504' SLM. PULLED STA #1 BK-DGLV @ 9407' SLM, 9419' MD. PULLED 4.5" SS-CATCHER FROM 9504'SLM. LEFT STA #1 EMPTY @ 9419' MD. *** RIG DOWN TURN WELL BACK TO DSO*** Page 2 of 3 18-05A 9/5/2008 18-05A 18-05A 18-05A 18-05A 18-05A 18-05A 18-05A 18-05A • T/I/0= 150/0/100 Temp = SI ,Circ out (Pre RWO) Pumped 1.6 bbls of neat into tubing. Tubing pressured to 2000 psi. and IA did not track.(T/I/0= 2000/0/100) Called PE. Continued pumping a total of 2.9 bbls to 3000 psi.(T/I/0=3000/0/100) Monitored for 15 min. T/I/0= 2780/0/100.Tubing lost 220 psi.. Called PE, continued pumping a total of 4.2 bbls of neat to 3900 psi.(T/I/0=3900/60/100) Monitored after 15 min. T/I/0= 3620/40/100. Bled back 3.6 bbls to Final WHP= 150/20/100. ***swab,wing,ssv,compaion-closed, master-open, IA/OA open to gauges*** 9/5/2008 ***WELL S/I ON ARRIVAL*'* IN THE PROCESS OF RUNNING IN TO SET 4.5" SLIP STOP ***CONT. WSR ON 09/06/08*** 9/6/2008 T/I/0= 450/300/0 Temp=Sl Circ-Out (pre RWO). MIT-OA PASSED to 2000 si. Pressured up OA with 2.8 bbls crude. OA lost 100 psi in 1st 15 min and 20 psi in 2n 15 min for a total loss of 120 psi in 30 min test. Bled OA pressure back to 20 psi. Bullheaded 15 bbls meth, 50 bbls 9.8 brine down Tbg up IA thru open pocket @ 4249' to PC leak. Let fluid/gas swap for 2hr.*** Job continued on 9-6-08 WSR*** 9/6/2008 ***CONT. WSR FROM 09/05/08*'* SET 4.5" SLIP STOP CATCHER @ 7,060' SLM PULL STA. #2 1.5" DGLV (RK LATCH), PRESSURE UP ON TUBING FROM 350 TO 650 PSI. TUBING HOLDING, IA @ 0 PSI. PULL STA. #3 1.5" DGLV (RK LATCH) ,TUBING PRESSURE DROPPED FROM 650 TO 450 PSI. NO CHANGE ON IA. BEGIN PRESSURING UPON TUBING IA BEGAN TO TRACK W/TUBING. IA FROM 0 TO 300 PSI. ********All Three Gas Lift Stations Are Empty.**...**. ***WELL LEFT S/I, DSO NOTIFIED OF STATUS*** 9/7/2008 *** Job continued from 9-6-08**** Circ out (PRE RWO) Pumped 100 bbls 9.8 ppg brine, 2 bbls diesel down the tubing. Bullhead IA w/ 3 bbls neat, 209 bbls 9.8 ppg brine. **Shutdown job due to fluid bubbling and filling up cellar**. Final WHPs= 300/150/0 9/8/2008 9/8/2008 T/I/0=260/130/0. Temp=Sl. Eval bubblino & fluid inflow in cellar (possible SC leak). No AL, Integral installed and loop rigged up to the IA & 5-riser. Rapid bubbling in cellar comming from the 4 O'clock to 7 O'clock position around the well head. Vac truck on location to remove the continuous inflow of fluid into the cellar. SI grove valve, bled S riser from 900 psi to 0 psi in 2 min. SI monitored for 30 min, no change in pressure. Crew change. Continue to bleed TBG to BT from 180 psi for 2 hrs with no change in pressure with approximately 25 bbls returned, SI bleed, monitor for 3.5 hrs, TP increased 30 psi. Bled TBG for another 2.5 hrs, with an increase of 30 psi and 43.3 bbls returned. Bled IAP from 50 psi for 1.5 hrs with an increase of 40 psi to 90 psi and 13 bbls returned. SI bleed, monitor for 6 hrs, during TBG bleed IAP decreased 40 psi to 50 psi and increased to 90 psi after TBG bleed. Bleed OAP from 15 psi to 0 psi in 2 mins (all gas), SI bleed, monitor for 6.5 hrs, OAP increased 10 psi. After the 0230 hr & 0300 hr of vacing out the cellar, the fluid level in cellar fluctuated during this time. Bled TBG for another 30 mins with an increase of 20 psi, with 14.1 bbls return in 30 mins. SI bleed, monitor all pressures. Fluid is still T/I/0=350/100/14 Circ Well MIT-OA PASSED to 2000 psi. (RWO Prep) Loaded tbg w/ 2 bbl Meth spear, 150 bbls 9.8# Brine freeze protected w/ 2 bbls diesel.Bullhead IA w/ 2 bbl meth spear, 438 bbls 9.8# Brine. Freeze protected w/ 7 bbls diesel. After 400 bbls of brine um ed down IA, small amount of water started to come into the cellar. A ox. 8 gallons every 15 mins. H tec was t ere to monitor an vac out ce ar w en necessary. MITOA to 2000 psi passed. Pumped 1.8 bbls crude down OA to reach test pressure.Loss of 40 psi 1st 15 min. Loss of 10 psi 2nd 15 min Continued on 09-09-08 WSR 9/8/2008 T/I/O = 260/90/10. Temp = SI. Monitor fluid influx in cellar. Rapid bubbling and inflow of fluid into cellar still present from 8 O'Clock position to 1 O'Clock position around wellhead. Vac truck on location to remove fluid from cellar. Vac truck removing approx. 14-16gph. Fluid influx into cellar slowly decreased to approx 4-6gph.. Monitored for 7 hrs. TP increased 10 psi, IAP increased 10 psi & OAP increased 3 psi. Fluid influx stopped coming into cellar (2:30 pm). Monitored for an additional 5 hrs. OAP increased 1 psi. Total volume vacced from cellar this shift = 2.5 bbls. Hot Oil arrived on site to Circ out well. Final WHPs = 270/100/14. WV =Closed. SV,SSV,MV =Open. IA & OA = OTG. DHD/Hot oil on well. 9/9/2008 T/I/0= 270/100/14. SI. Monitor fluid influx in cellar.~SGIGt R to load TB -,.IA.OA. Small amount of fluid starting to appear in the sealed conductor around the seam @ the 6 O'Clock position, <30 minutes small stream of fluid starting to enter cellar @ the 9 O'Clock position with 400 bbl down the IA, out of fluid @ 43~b61s oi^ . rine, followed by 7 bbls of diesel, shut down pump. LRS rigging up to OA for MITOA to 2000 psi (see WSR for LRS). Vac out < 10 gallons of fluid during MITOA. 0100 hrs after LRS was rigging down from OA, fluid in cellar increased to - 8 gallons per 15 minutes, (C~ 0400 hrs, small amount of sand is starting to enter cellar around the 9 O'Clock position) with fluid. Fluid continues to inflow with a rate of 8 gallons in 15 minutes for the next 6 hrs_ Bled OAP from 10 psi to 0 psi in 1 minute (all gas), monitor for 3.5 rs, AP increased 8 psi. Total of 5.3 bbls returned from cellar in 6 hrs. Final WHPs= vac/vac/8 Crew change. WV=C SV,SSV,MV=O IA,OA=OTG DHD/Vac Truck on location Page 3 of 3 18-05A 9/9/2008 Continued from 9-08-08 WSR. Freeze protect FL w/ 5 bbls meth, 60 bbls crude followed by 10 bbls diesel. FWHP=O/0/0 Tags hung, casing valves open to gauges 18-05A 9/9/2008 T/I/0= VACNAC/10. Temp= SI. Monitor fluid influx in cellar. Integral on companion. Fluid & sand entering cellar @ 9:00 osition @ 25 allons/hr. Steady bubbling from 6:00 position to 9:00 pose ion. = ppm, H2 = 0 ppm, 02= 20.5%, LEL= 6 ppm (readings taken C~3 7:00 position). At 11:00 AM, fluid is entering cellar C~ 15 gallons/hr. C0= 6 ppm, H2S=0 ppm, 02= 20.5%, LEL= 6 ppm. Bubbling C 3:00, 6:00 - 12:00 positions. Pressures, fluid influx unchanged since 11:00 AM. Vac'ed out 5.5 bbls in 12 hours. AM. Changeout with night crew. Final WHPs= VACNAC/10. WV=C. SV,MV,SSV=O. IA,OA=OTG. Vac truck, DHD on location. 18-05A 9/9/2008 T/I/O =VACNAC/11. Temp = SI. Monitor fluid influx into cellar. Integral on TBG. companion & IA, w/ hardline loop (SI) from IA to S riser. Fluid entering cellar @ 5 gph. Fluid bubbling from the 6 o'clock to 10 o'clock positions. Readings taken C~ 7 o'clock position: C0=7, H2S=0, 02=20.5, LEL=4. Bled OAP from 11 psi to 0 psi in 1 min, OA .Evacuated 5 gph from 1900 until 0001. At the midnight monitor, evacuated 2 gal. No fluid in cellar after 0001 hrs. Readings C~ 7:00 - 10:00 positions, CO=7,H2S=0, 02=20.5, LEL=2, (taken 0001). Bled A to BT, all gas, monitoring every hour for 10 min. OAP build-up less each time Readings between 8:00 and 9:00 position: C0=3, H2S=0, 02=20.4, LEL=O, (taken @ 0400). Shut in OA bleed @ 0600 for 30 min. OAP increased from 0 psi to 1 psi. Continue bleed. Final readings at base of conductor: C0=0, H2S=0, 02=20.5, LEL=O. Final WHPs =VACNAC/0. Crew change out. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 18-05A 9/10/2008 T/I/0= VACNAC/0. Temp= SI. fl i influx in ellar. No visible si n of fluid in cellar at this time. H2S= 0 ppm. 02= 20.5 %. C0= 0 ppm. LELs= 0 %. Readings taken at 8:00 am. Checked rea ings again at 3 pm and all remained unchanged. Bled OAP from 4 psi to 0 psi in 30 seconds at 4:30 pm. Final WHPs= VACNAC/0 psi. SV, WV=Closed. SSV, MV= Open. IA, OA= OTG. NOVP. 18-05A 9/11/2008 T/I/0=0/0/0; Set 5-1/8" FMC ISA BPV #520 thru tree pre Doyon 14; 1-2' ext. used, tagged C~ 96"; ***Complete*** (Best/Fraker) 18-05A 9/12/2008 T/I/0=?NAC/10. SI. Monitor WHP's post FB load and kill (pre-RWO). IAP unchanged and OAP increased 10 psi overnight. No scaffolding on well. SV,WV=?. MV,SSV=O. IA & OA=OTG 18-05A 9/13/2008 T/I/0=5/0/0; Pull 5-1/8" FMC ISA BPV #520 thru tree for Doyon 14 De-completion; 1-2' ext. used, tagged C~? 84"; (Beal/Wortham) 18-05A 9/15/2008 T/I/O Vac/0/0 Pull 5 1/8 FMC ISA BPV #519, Thru Stack 4-5' EXT !-Centralizer Tagged @84" 18-05A 10/11/2008 ***RIG JOB DOYON 14*** PULLED 4-1/2" RHC PLUG BODY @ 9735' SLM/ 9710' MD,. RAN 3.80" G-RING PASSED TBG STUB TO XN-NIP ~ 9872' SLM/9873' MD. CURRENTLY RUNNING IN HOLE TO RE-SET 4-1/2" RHC PLUG BODY IN PROGRESS. *'*CONTINUE ON 10/12/08 WSR*** 18-05A 10/12/2008 ***DOYON 14 RIG JOB CONTINUED*** SET 4-1/2" RHC-M PLUG BODY IN X-NIP @ 9735' SLM. ***JOB COMPLETED*** 18-05A 10/13/2008 T/I/0=0/0/0. Pull 4-1/8" CIW H TWC thru tree, post tree test. 1-2' ext used, tagged @ 98". No problems. Set 4-1/8" CIW H BPV #145 thru tree w/ T-Bar for rig to move off well. 18-05A 10/18/2008 T/I/0=0/0/0. Pull 4" CIW H BPV. Post Rig. 18-05A 10/22/2008 ***WELL S/I ON ARRIVAL***(post rwo PULLED BALL & ROD FROM RHC @ 9699' SLM PULLED BK-DGLV FROM S # SET BK- LGLV IN STA #4 @ 3209' SLM, SET BK- S/O IN STA #4 @ 5797' SLM , PULLED 3 1/2" RHC PLUG BODY @ 9709' SLM RIFT W 3.50 10060' LM, STOPPED DUE TO DEV. (NO SAMPLE) *** WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** Print Date: 10/31/2008 Page 1 of 1 • BP EXPLORATION Operations Summary Report Legal Well Name: 18-05 Common Wel! Name: 18-05A Event Name: WORKOVER Start: 9/12/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Page 1 of 31 Spud Date: 4/21/1986 End: 10/13/2008 Date From - To 'Hours Task Code NPT ' Phase ~ Description of Operations 9/12/2008 00:00 - 02:00 2.00 MOB P`~ PRE Rig down. 02:00 - 06:00 I 4.001 MOB I P I I PRE 06:00 - 07:30 1.50 MOB P PRE 07:30 - 09:30 2.00 MOB P PRE 09:30 - 10:00 0.50 MOB P PRE 10:00 - 11:30 1.50 MOB P PRE 11:30 - 13:00 1.50 MOB P PRE 13:00 - 15:00 2.00 MOB P PRE 15:00 - 19:30 4.50 MOB P PRE 19:30 - 00:00 4.50 MOB P PRE 9/13/2008 00:00 - 02:00 2.00 MOB P PRE 02:00 - 04:30 2.50 MOB P PRE 04:30 - 09:00 4.50 MOB P PRE 09:00 - 10:30 1.50 MOB P PRE 10:30 - 12;00 1.50 MOB P PRE 12:00 - 16;00 4.00 MOB P PRE 16:00 - 17:00 1.00 ~ MOB ~ P ~ ~ PRE 17:00 - 17:30 0.501 MOB P PRE 17:30 - 20:00 I 2.501 MOB I P I I PRE -Pull back #2 conveyor. -Unhook power to envirovac and shop. -Set mats for front booster. Rig down. -Install front rack. -Install front booster. -Test boosters. Rig down. -Skid rig floor to moving position. Rig down. -Install rear boosters. -Test boosters. Move. -Move to H pad access road. Move. -Move rig from H pad access to GC2. Move. -Pick up rig mats and move them ahead of rig. Move. -Move rig from GC2 to J pad access. Move. -Wait on rig mats to be moved. Move. -Move rig from J pad access to GC3. Continue to move rig to DS -18. -Move from GC3 to Oxbow turn off on Spine road. Wait to travel on Oxbow road due to a broke down forklift. (CH2MHill loader) -Forklift is needed to move and set Rig mats. Continue move rig to DS 18. -Move across Oxbow road to DS-18 turn off. Continue to move rig to DS-18. -Wait for rig mats to be spotted to pad. Continue to move rig to DS-18. -Move from DS-18 turn off onto DS-18 pad. Rig up BOP. -Put together Hydril, Double stack, Mud Cross, and Lower rams. -Pull conveyor out. -Hang choke hose. Move rig. -Hold PJSM. -Spot rig over well, DS 18-05A. T/I/O = 0/0/0 Rig up. -Hold PJSM. -Skid rig floor to working position. Continue to rig up. -Spot rockwasher. -Hook up service lines to floor. -Ria acceoted ~ 20:00 hrs. Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Page 2 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: i ~ I '~ Description of Operations Date !From - To Hours Task i Code NPT Phase. 9/13/2008 20:00 - 00:00 4.00 RIGU P - DECOMP Continue to rig up. -Rig up rock washer. -Remove blanking flange. -Install pumping flange. -Ri u DSM test lubricator and test to 500 si for 5 min. -Take on 9.8 ppg brine into pits. -Hang cellar doors. 9/14/2008 00:00 - 01:00 1.00 WHSUR P DECOMP Rig up over well. -DSM pulled BPV. - ubricator. 01:00 - 03:30 2.50 WHSUR P DECOMP Rig up to circulate out diesel freeze protection. -DSM crew R/U hardline from slop tank to cellar. -Test hard line to 3500 psi. PASS. 03:30 - 05:00 1.50 WHSUR P DECOMP Circulate out diesel freeze rotection, -Pump 20 bbls of 9.8 ppg NaCI brine down Ann & up Tbg. -Pump rate C~ 3 bpm and 310 psi. -Blow down lines. -Swap hoses on tree. -Pump 40 bbls of 9.8 ppg NaCI brine down Tbg & up Annulus. -Pump rate C~3 5 bpm and 650 psi. 05:00 - 05:30 0.50 WHSUR P DECOMP Circulate out freeze protection. -Wait 30 minutes for diesel migration. 05:30 - 06:30 1.00 WHSUR P DECOMP Circulate out freeze protect. -Pump 10 bbls of 9.8 ppg NaCI brine down Tbg & up Annulus. -Blow down lines. 06:30 - 07:30 1.00 WHSUR P DECOMP FMC Rep. RU & install BPV., -RD dry rod assembly. 07:30 - 08:30 1.00 WHSUR P DECOMP RU to test BPV from below. -Attempt to test w/ no success. -Pum in fluid awa ~ 4.5 bpm 1100 psi. -Establish injection rate: -w/ 4.5 bpm 1100 psi f/ 10 minutes on chart. rv BPV durin um in o s - No leaks. 08:30 - 11:00 2.50 WHSUR P DECOMP PJSM on ND / NU operations. -Prep BOPE equip and spacer spool to minimize exsposure time. -Ex re ti ritical d e to sin I mech ni I i r. -MU 5 1/2" L.H. ACME XO to floor valve. -ND tree and adapter flange. -FMC install blankin lu 11.5 turns . 11:00 - 12:00 1.00 BOPSU P DECOMP N/U BOPE. -Spot mouse hole. -P/U spacer spool. 12:00 - 17:00 5.00 BOPSU P DECOMP N/U BOPE. -PJSM sim opps, on nipple up BOPE stack. -Install choke line. -Install double annular valve on the IA. -Rig up Top Drive. -RU kelly hose. -Check torque on stack breaks. 17:00 - 19:00 2.00 BOPSU P DECOMP Action item follow up: -Weld under floor. -New pollution pan cover racks & securement chains. Printed: 10/20/2008 12:29:13 PM • • BP EXPLORATION Page 3 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: i Date 'I From - To ;Hours Task ..,Code NPT '; Phase Description of Operations 9/14/2008 19:00 - 21:00 2.00 BOPSU P DECOMP N/U BOPE. -Install bell nipple. -Install Flow line. -Center stack. -Install turn buckles. -Install bleed off line. -Install hole fill line. -Install mouse hole. 21:00 - 22:30 1.50 BOPSU P DECOMP RU for ROPE testing. -PU Floor valves. -RU Top Drive. -RU choke manifold. 22:30 - 00:00 1.50 BOPSU P DECOMP Test BOPE. -Hold PJSM on testing BOPE. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. , -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Spacer spool C~ 18" Test BOP and related equipment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3,500 psi high x 5 min each on chart. -Test Hydril w/ 4" test jt. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test bottom rams w/ 4" test joint and 4-1/2" test joint. -Perform accumulator test. Test witnessed by WSL and Toolpusher. -Test witness waived by Jeff Jones AOGCC. 9/15/2008 00:00 - 08:00 8.00 BOPSU P DECOMP Continue to test BOP equipment. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Spacer spool C~ 18" Test BOP and related equipment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3,500 psi high x 5 min each on chart. -Test Hydril w/ 4" test jt. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Repair and re-test choke valve #7 -Good test -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 4 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To ~ Hours I Task ~I Code ~ NPT ~ Phase ~ Description of Operations 9/15/2008 00:00 - 08:00 8.00 BOPSU P DECOMP -Test bottom rams w/ 4" test joint and 4-1/2" test joint. -All tests -Pass. -Perform accumulator test. Test witnessed by WSL and Toolpusher. -Test witness waived by Jeff Jones AOGCC. 08:00 - 10:30 2.50 BOPSU P DECOMP Trouble shoot accumulator. -Replace valves & springs in electric pump. -Retest accumulator -Good Test. -4 Bottles ~ 2100 psi. 10:30 - 11:30 1.00 BOPSU P DECOMP Pull Blanking plug w/ test jt. -LD test jt. 11:30 - 15:00 3.50 BOPSU P DECOMP RU 6" lubricator extension. -RU DSM lubricator -Test to 500 si on chart -Pass. -Retrieve FMC ISA 100 BPV. -RD DSM -Break apart extension. -LD same. 15:00 - 16:00 1.00 PULL P DECOMP RU Bales & 4" Elevators. -PU joint of 4" DP & XO's. -BOLDS. -Screw into hanger w/ 5 1/2" L.H ACME (11.5 turns). 16:00 - 21:30 5.50 PULL P DECOMP Pull hanger free w/ 105k. -Pull up to 230 80% o tensile) w/ no movement. -Work pipe from 175k-280k (including blocks 50k). -Wait on Schlumberger W.L. for free oint and 'et cutter. -Continue to work pipe periodically 175k-280k. 21:30 - 00:00 2.50 PULL P DECOMP RU wireline. -PJSM. -MOB wireline equipment to floor. -MU 1 Jt. 4" DP, XO, Y block, XO. -Screw into Top Drive. -Hang Sheave. -RU wireline. 9/16/2008 00:00 - 00:30 0.50 PULL P DECOMP Rig up SWS. -Continue to RU SWS Free point tool. 00:30 - 06:00 5.50 PULL P DECOMP RIH with SWS to find Free Point. -100% Free ~ 3,000' md. -100% Free ~ 6,000' md. -100% Free (~ 6,700' md. -100% Free ~ 6,943' md. -100%Free ~ 7,479' md. - 85% Free C~ 7,600' md. - 60% Free C~ 7,760' md. - 50% Free ~ 7,970' md. 06:00 - 07:00 1.00 PULL P DECOMP POH w/ Free point tools. -RD "Y" block. -Remove Sheave from Derrick. 07:00 - 12:00 5.00 PULL P DECOMP RU 6" lubricator extension. -PJSM w/ E-line group. -Hang Sheave in Elevators. -RU double Packoff w/ ability to grease in between. -RU SLB BOP's. -RU Lubricator &Packoff. 12:00 - 14:30 2.50 PULL P DECOMP Test all components to 500 psi f/ 5 min. on chart -Good test. Printed: 10/20/2008 12:29:13 PM • BP' EXPLORATfON Page 5 of 31 Operations Summary Report Legal Well Name: 1 8-05 Common W ell Name: 1 8-05A Spud Date: 4/21/1986 Event Nam e: WORKO VER Start : 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLIN G INC . Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To ~~, Hours Task 'I Code I, NPT III .Phase Description of Operations 9/16/2008 12:00 - 14:30 2.50 PULL P DECOMP -Remove head f/ stack. -Attach head to wire. -MU head to Stack. -Pressure test seal. 14:30 - 17:00 2.50 PULL P DECOMP RIH w/Jet cutter for 4 1/2" 12.6# tubing to 8,600' md. -Log up and locate collar at 8,386' md. -Re-log to verify. -S of cutter at 8 406' and CCL at 8 394' and . -Fire cutter -Good indication of firing. - w cutter. 17:00 - 19:30 2.50 PULL P DECOMP POH w/first cutting assemby. -LD SWS tools and reload head. 19:30 - 21:30 2.00 PULL P DECOMP RIH w/ second cutter for 4 1/2" 12.6# tubino to 7,500' md. -Log up and locate collars at 7,461' md. 7,421' md. 7,382' md. -S of Cutter C~ 7,388' md. -Fire Cutter -Good indication of firin . -POH w/ Cutter. 21:30 - 22:30 1.00 PULL P DECOMP RD SWS tools. -RD riser f/SWS and LD. -RD SLB BOP's, ext. and set to side. -Brew into Top Drive and Hanger. 22:30 - 00:00 1.50 PULL P DECOMP PU on tubing. -Engage Hanger. -PU 230k. Slack off. (w/ 50K block weight) -PU 250k several times & slack off. -Pulled 260k and let set 5 minutes. -PU 280k & slack o . -Continue to work pipe f/ 230k to 260k. -Hold tension for 1 minute after the up stroke. 9/17/2008 00:00 - 02:00 2.00 PULL P DECOMP RU SLB Tools. -PJSM. -RU 6" Lubricator extension. -RU SLB BOP's. -RU SLB Pack-off. -Sim-ops -Table top Man down drill. 02:00 - 06:00 4.00 PULL P DECOMP SLB repair Pack-Off. -Replace leaking Tree cap O-Ring. -C/O grease Head, (problematic pressure test). 06:00 - 07:00 1.00 PULL P DECOMP Test lubricator and components to 500 psi on chart -Good test. -MU firing head. -PU cutter to rig floor. 07:00 - 10:00 3.00 PULL P DECOMP RIH w/ cutter to 7,100' md. -Log up and locate Collar at 6,934' and -Collar in first full joint below GLM #2. -RIH and log up to verify. -Spot cutter at 6,950' and (CCL at 6,938' md). -Fire cutter -Good indication at unit. -POH - utter fired. 10:00 - 12:00 2.00 PULL P DECOMP LD Jet cutting tools. -Reload head. -Losses for tour = 9 bbls of 9.8 ppg NaCI brine. Printed: 10/20/2008 12:29:13 PM ! s BP EXPLORATION Page 6 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: i Date ,From - To Hours 'i Task 'Code NPT Phase Description of Operations 9/17/2008 12:00 - 13:00 1.00 PULL P DECOMP PJSM at crew change. -Reload head. -Pull tools to rig floor - MU same. -Pressure test Lubricator to 500 psi on chart -Good test. 13:00 - 15:00 2.00 PULL P DECOMP RIH w/Jet cutter to 6,900' md. -Log up and locate Collar at 6,800' md. -RIH -Log up to verify. -Spot cutter at 6,780' and (CCL at 6,768' md). -Firs r•i iMcr _ Nn inrlicatinn _ Rafira anrf wait ~ min -POH. 15:00 - 17:00 2.00 PULL P DECOMP PJSM. -Inspect cutter -Did not fire. -Disarm cutter. -LD tools. -Break down cutter assembly and inspect. -Did not fire due to "O" ring failure in detonator. -Because of "O" ring failure Brine got into firing head. 17:00 - 20:00 3.00 PULL P DECOMP Assemble cutter & arm. -PJSM. -PU to rig floor. -RIH w/Jet cutter to 6,900' md. -Log up and locate Collar at 6,800' md. -RIH -Log up to verify. -Spot cutter at 6,780' and (CCL at 6,768' md). -Fire cutter -Good indication at Unit. 20:00 - 20:30 0.50 PULL P DECOMP LD Jet cutting tools. -Inspect cutter -Fired. -LD SLB tools. -SIM OPS -Table top Rig Evacuation Drill. 20:30 - 21:00 0.50 PULL P DECOMP PU on Tubing: -PU 1 jt. 4" Drill Pipe. -PU XO's. -Screw into Tubing Hanger. -Pull 116K to free. 21:00 - 23:30 I 2.50 I PULL I P 23:30 - 00:00 I 0.50 I PULL I P 9/18/2008 100:00 - 01:00 I 1.001 PULL I P DECOMP ~SIM Opps -Clear rig floor. -Pump 40 bbls SafeKleen Pill. -Pump 50 bbls 9.8 ppg NaCI Brine. -Pump 40 bbls Safe Scav. Pill. -Chase Pills out of hole with 9.8 ppg NaCI Brine. -MOB Control Line Spooler. -MOB Csg Equipment, Elevators, Slips, Tongs. DECOMP RU Casing Equipment. -RU Csg Tongs. -RU Elevators. -Remove Control Lines. -Remove Hanger. Fluid Loss for this Tour = 18 bbls of 9.8 NaC DECOMP RD from pulling Tubing free: -LD 1 jt. of DP, XO's. -LD Tubing Hanger. Printed: 10/20/2008 12:29:13 PM ~~ B'P EXPLORATION Page 7 of 31 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 8-05 8-05A WORKO DOYON DOYON Hours VER DRILLIN 14 ' Task INC Code' . NPT Start Rig Rig ' Phase ' Spud Date: 4/21/1986 : 9/12/2008 End: 10/13/2008 Release: 10/13/2008 Number: Description of Operations 9/18/2008 00:00 - 01:00 1.00 PULL P DECOMP -Blow down Top Drive. -Change out Elevators. 01:00 - 03:30 2.50 PULL P DECOMP POH LD 4 1/2" 12.6 # L-80 IBT Tubing. -POH LD Tubing w/ Control line. 03:30 - 04:00 0.50 PULL P DECOMP POH LD 4 1/2" 12.6 # L-80 IBT Tubing. -LD Control Line Spool. -RU Air Slips. 04:00 - 05:30 1.50 PULL P DECOMP POH LD 4 1/2" 12.6 # L-80 i8T Tubing. -Continue to LD Tubing. 05:30 - 07:00 1.50 PULL P DECOMP Adjust Pipe Skate. -Fine tune Skate -control speed settings. 07:00 - 09:30 2.50 PULL P DECOMP POH LD 4 1/2" 12.6 # L-80 IBT Tubing. -Continue to LD Tubing. -Count of recovered equipment: -Total Joints - 163 JTS. -Total Cut Joints - 1 Cut JT ~ 18.71'. -Total SS Bands - 37 SS Bands. -Total Pup Joints - 6 (1.94', 2.28', 5.70', 7.77', 9.30', 9.75'). -Total Hangers - 1 Hanger. -Total GLM's - 1 GLM, -Total SSSV - 1 SSSV. 09:30 - 10:00 0.50 PULL P DECOMP POH LD 4 1/2" 12.6 # L-80 IBT Tubing. -RD Tubing handling Equipment. -Clear and Clean Rig floor. 10:00 - 10:30 0.50 PULL P DECOMP Rig up for Fishing Operations: -Install Wear Ring. 10:30 - 11:00 0.50 PULL P DECOMP Ri u for Fishin O erations: -MOB BHA and Handling tools to Floor. 11:00 - 13:30 2.50 PULL P DECOMP Rig up for Fishing Operations: -PU BHA. -MU BHA as follows: -1) 4 1/2" XHX 4 1/2" IF Pin. -9) 6 1/4" Drill Collars -1) 4 1/2" Box X 4 1/2" XH Pin. -1) 6 1/4" Intensifire. -1) Pump out Sub. -1) 4 1/2" iF Pin X 4" HT 38 Box. -Losses during Tour - 15 bbls 9.8 ppg NaCI Brine. 13:30 - 17:00 3.50 PULL P DECOMP PU 4" Drill Pipe. -PU 4" DP from Pipe Shed. -From 319' to 6,675'. 17:00 - 21:30 4.50 PULL P DECOMP Obtain following Parameters: -PUW - 152k. -SOW - 128k. -ROT WT - 140k. -Tagged Top of Fish C~ 6,779' and -52 SPM - 360 psi. -60 RPM - 4k torque WOB - 5k. -80 RPM - 4k torque WOB - 2k. -33 SPM - 170 psi. -Circulate Hi-Vis sweep. (no notable increase in sand) Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Page 8 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours 'I Task Code ~ NPT 1 Phase Description of Operations 9/18/2008 17:00 - 21:30 4.50 PULL P DECOMP -POH w/ Fish - No Overpull. 21:30 - 22:00 0.50 PULL P DECOMP LD 1 joint 4" Drill pipe. -LD 1 JT DP. -Blow down Top Drive. -Install Stripping Rubber. 22:00 - 23:30 1.50 PULL P DECOMP Cut and Slip. -Cut and slip drilling line. -Service Top Drive. 23:30 - 00:00 0.50 PULL P DECOMP POH racking back 4" Drill Pipe. -POH from 6,747'to 6,100' -Losses during Tour - 17 bbls 9.8 ppg NaCI Brine. -Total losses for the past 24 hrs. - 32 bbls 9.8 ppg NaCI Brine. -Cummulative losses for the well. - 59 bbls 9.8 ooa NaCI Brine 9/19/2008 100:00 - 02:00 I 2.001 PULL I P 02:00 - 03:30 I 1.501 PULL I P 03:30 - 05:00 I 1.501 PULL I P 05:00 - 07:00 I 2.001 PULL I P 07:00 - 10:30 3.50 PULL P 10:30 - 11:00 ~ 0.50 ~ PULL i P 11:00 - 12:00 1.00 PULL P 12:00 - 12:30 0.50 PULL P 12:30 - 14:30 ~ 2.00 ~ PULL ~ P DECOMP POH racking back 4" Drill Pipe. -POH from 6,100'to 319' DECOMP POH w/ BHA. -LD accelerator Jar, Pump out Sub. -Rack back DC's. -Release Fish. -LD Jars, Bumper Sub, & Overshot. DECOMP PJSM. -RU Tongs, Elevators. -LD 4 1/2" 12.6# L-80 IBT Tubin . -Puncture GLM. -Recovered 3 jts., 2 cut jts. (jt# 164-20.29', jt# 168-16.52') -Recovered GLM #2. DECOMP PU BHA. -PU 8 1/8" O.S. assembly. -4 1/2" HMC and 4 1/2" Basket Grapple. -RIH w/ DC's. -PU acceleratorJar. DECOMP RIH on 4" DP to 6,575' md. -PU 7 singles from Pipeshed to 6,798' md. DECOMP Screw in T.D. -Obtain parameters as follows: - PUW 158k -SOW 126k -ROW 140k w/ 4k tq. -Break circ. w/ 5 bpm, 330 psi. DECOMP Pump H.V sweep around. -7.5 bpm, 700 psi. -No si ns of hea sands/silts on BU. DECOMP Rotate and wash down w/ 60 rpm 4k'tq. -3 bpm @ 150 psi. -Tag and dress off T.O.F. for 1/2 foot -Weight fell off. -Stop rotary, slide over fish 7' and set down 10k. -No Pump PSI change was seen. -PU to 185k (25k over) and bleed jars. -PU to 340k (180k over) and ipe broke free. -Pull up 15' w/ 4-5k over pull. -OA = 0 psi. DECOMP Pump H.V. sweep surface -surface. Printed: 10/20/2008 12:29:13 PM s BP EXPLORATION Page 9 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT- Phase Description of Operations 9/19/2008 12:30 - 14:30 2.00 PULL P DECOMP -7.5 bpm, 330 psi. -No signs of heavy sands/silts. 14:30 - 17:30 3.00 PULL P DECOMP POH w/ Fish. -Monitor well. -Blow down Top Drive. -POH f/ 6,966' t/ 319'. 17:30 - 18:30 1.00 PULL P DECOMP Change out Elevators. -Rack Back 6 1/4" DC's. -LD Jars and Overshot. -C/O Elevators. -RU Csg Tongs. -Actual Hole Fill = 43.5 bbls. -Calculated Hole Fill = 45.5 bbls. 18:30 - 19:30 1.00 PULL P DECOMP LD 4 1/2" Tubing L-80 12.6# IBT. -LD 10 Jts tubing. -Top cut Jt. = 22.32'. -Bottom cut Jt. = 18.98' w/ Flare of 5 1/16". 19:30 - 21:30 2.00 PULL P DECOMP Attempt to remove Grapple from top cut. -LD Grapple and top jt. all together. -Clean and clear Rig Floor. -MOB tools from Baker. 21:30 - 23:00 1.50 PULL P DECOMP PU BHA. -PU 8 1/8" O.S. assembly. -4 1/2" HMC and 4 1/2" Basket Grapple. -RIH w/ DC's. -PU acceleratorJar. 23:00 - 00:00 1.00 PULL P DECOMP RIH w/ Drill Pipe. -RIH f/ 319' U 3,500'. -Daily losses = 7 bbls 9.8 ppg NaCI Brine. -Cummulative losses = 66 bbls 9.8 p NaCI Brine. -OA = 0 psi. 9/20/2008 00:00 - 01:00 1.00 PULL P DECOMP RIH w/ 4" Drill pipe. -RIH f/ 3,500' U 6,766' md. 01:00 - 01:30 0.50 PULL P DECOMP PU Drill pipe. -PU 4" Drill pipe f/ 6,766' t/ 7,218' md. 01:30 - 02:00 0.50 PULL P DECOMP Obtain Parameters as follows: -PUW = 165k, SOW = 125k, ROTW = 148k. -RPM = 60, TRO = 4k. -126 gpm = 130 psi. -Wash down. -Tag Fish ~ 7,405' md. 02:00 - 02:30 0.50 PULL P DECOMP ump .sweep. -Surface to surface ~ 420 GPM = 1,450 psi. -Small amounts of sand on BU. 02:30 - 03:00 0.50 PULL P DECOMP Tag and dress off T.O.F. -Weight fell off. -Burn over stub @ 60 RPM's 4-8k Torque. -WOB = 2-4k. -Swallowed 7'. (f/ 7,405' - t 7,412' md) -Set down 15k. 03:00 - 04:00 1.00 PULL P DECOMP Jar Fish free. -Pull 225k and Jar. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 10 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date ,From - To Hours Task Gode NPT 'Phase. Description of Operations 9/20/200803:00 - 04:00 1.00 PULL P DECOMP -Work down. -Pull 350k and maintained 500 psi on tubing. -Rack back 1 stand. 04:00 - 07:00 3.00 PULL P DECOMP Pump H.V. Sweep surface to surface. -Pump sweep ~ 336 GPM ~ 1,150 psi. -Continue to work Pipe. -increase rate to 420 GPM C~3 1,530 psi. -Heavy amounts sand/silt on BU. -Pump H.V. sweep #2. -Trace amount of sand/silt on BU. 07:00 - 10:30 3.50 PULL P DECOMP Monitor Well for 10 minutes -Static. -Blow down Top Drive. -POH f/ 7,325' U 319' md. -No problems noted pulling out of 7" Liner. 10:30 - 11:30 1.00 PULL P DECOMP LD BHA. -Stand back 6 1/4" DC's. -LD Intensifire, Bumper sub, Jars. 11:30 - 12:00 0.50 PULL P DECOMP LD 4 1/2" 12.6# L-80 IBT Tubing. -RU to LD Tubing. OA= 25 psi. Retrieved 1 stainless steel Band. 12:00 - 15:00 3.00 PULL P DECOMP LD 4 1/2" 12.6# L-80 IBT Tubing. -PJSM. -LD Tubing break down as follows: -24 jts. 2 cut jts. -Bottom cut jt. 20.48' Flare 4 7/8". -RIH and LD 9- 6 1/4" Drill Collars. -PU Overshot and make service breaks. -LD fish. -Top cut jt. 20.43'. 15:00 - 18:00 3.00 PULL P DECOMP MOB BHA to floor. -MU Spear -MU Packoff, Pump out Sub. -MU Bumper Sub, Oil Jars. -MU XO, 4 Stands - 4 3/4" DC's. -MU XO, Intensifire, XO. 18:00 - 20:30 2.50 PULL P DECOMP RIH with 4" Drill Pipe. -RIH f/ 411' U 7,332' md. 20:30 - 21:30 1.00 PULL P DECOMP PU 4" Drill Pipe. -PU Pipe from Pipe Shed f/ 7,332' U 8,281' md. 21:30 - 22:30 1.00 PULL P DECOMP Wash down to top of Fish. -Wash down f/ 8,281' U 8,415' and (No fill observed). -Tap fish ~ 8,415 md. -Obtain Parameters: -336 GPM = 1,740 psi. -PUW 175k, SOW 128k. 22:30 - 00:00 1.50 PULL P DECOMP Circulate H.V. Sweep from Surface to Surface. -Pump H.V. Sweep C~ 336 GPM = 1,680 psi. -Small amounts of sand on BU. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 11 of 31 Operations Summary Report Lega! Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: i Date .From - To Hours , Task Code NPT ~ Phase Qescription of Operations PULL P -~ DECOMP OA= 0 psi. 9/20/2008 22:30 - 00:00 1.50 9/21/2008 100:00 - 05:00 I 5.001 PULL I P 05:00 - 12:30 7.501 PULL P 12:30 - 13:30 I 1.001 PULL I P 13:30 - 17:00 I 3.501 PULL I P 17:00 - 18:00 I 1.00 I PULL I P 18:00 - 19:30 I 1.501 PULL I P 19:30 - 20:30 I 1.001 PULL I P 20:30 - 00:00 ~ 3.501 PULL ~ P Cummulative losses = 66 bbls 9.8 ppg NaCI Brine. DECOMP Jar on fish w/ 75k-100k over pull. -PUW, 175k -SOW 126k. -Max pull of 400k (225k over). -Good returns thru fish noted ~ 01:30. -Attempt to Hydraulic Tubing loose, continously working Pipe. -Pump H.V. sweeps. (YP=48,60,78) Small amounts of sands. -Pump Lube pill (8% v/v). -Spot Lube pill around fish while working pipe. DECOMP ~ Continue to Jar w/ 100k over _Makinn nrnnracc - iF-iR' fra -Pull to 410k (235k over) -Increase pump rate to 294 gpm @ 3,200 psi. -Pipe moved uphole 1 foot -free travel was lost. -Continue working and jarring w/ 100k over pull and jarring down. -Grapple slipped and released while larrinq. -Attempt to re-set Grapple w/ no success, OA = 0 psi. DECOMP Stand back 1 stand. -Perform Derrick inspection. -Circulating while doing Derrick inspection ~ 252 gpm = 740 psi. DECOMP Monitor Well -Well Static. -Blow Down Top Drive. -POH f/ 8,377' and V 411' md. -Gave 24 hr notice to Chuck Shieve of upcoming BOPE test. -Chuck Shieve waived witness to BOPE test ~ 16:OOhrs. DECOMP LD BHA. -Rack back 4" heavy weight / 4 3/4" DC combinations. -Break down and LD Intensifire and Oil Jars. -LD Pump out Sub, Bumper Sub, and Spear assembly. -Fish was moved u the hole -26' md. -Spear assembly noted to be Damaged: -Missin Gra le and small amount of rubber from ack DECOMP MU BHA: -MU Reverse Basket, Bit Sub, and Pump out Sub. -MU Oil Jars, XO, and 4" heavy weight w/ 4 3/4" DC's combo. DECOMP Slip and cut 59 1/2' of 1 1/4" Drilling Line. -PJSM. -Serviced Top Drive. DECOMP RIH with 4" DP. -RIH f/ 399' and t/ 7,507' md. OA = 0 psi. Daily losses = 0 Cummulative losses = 66 bbls 9.8 NaCI Brine. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 12 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: i Date From - To Hours ~ Task Code NPT Phase Description of Operations 9/22/2008 00:00 - 01:00 1.00 PULL P DECOMP RIH w/ 4" DP f/ 7,507' and t/ 7,919' md. -MU Top Drive. -Rotate ~ 20 RPM and enter 7" Liner. -RIH f/ 7,919' and t/ 8,366' md. 01:00 - 01:30 0.50 PULL P DECOMP Wash down and tag 4 1/2" Tubin stub ~ 8,390' md. -Pump 336 gpm ~ 1,330 psi. -Obtain Parameters: -PUW - 175k, SOW - 130k, ROW - 150k. -RPM - 20, Torque - 3k. -Circulate on top of Tubin Stub. 01:30 - 04:30 3.00 PULL P DECOMP POH f/ 8,366' and t/ 399' md: -Rack Back 1 stand. -Monitor Well for 10 Min. -Well Static. -POH. 04:30 - 06:00 1.50 PULL P DECOMP Stand back 4 3/4" DC's. -LD RCJB. -Clean RCJB -Recovered 1 SS band. 06:00 - 06:30 0.50 PULL P DECOMP Clear /Clean rig floor. -RU PowerTongs. 06:30 - 10:00 3.50 PULL P DECOMP MU 3 3/4" Mill and Bit Sub. -PU 47 jts 2 7/8" PAC DP. -Change Elevators. -PU XO's P.O.S., Bumper sub, Jars. -RIH w/ 4 3/4" DC's 10:00 - 13:00 3.00 PULL P DECOMP RIH w/ 4" DP: -RIH f/ 1,805' and t/ 8,377' md. 13:00 - 13:30 0.50 PULL P DECOMP Screw in TD -Obtain parameters: -PUW 165k -SOW 127k -ROW 145k 40 rpm, 3k tq. -Break circulation w/ 126 gpm / 540 psi. -Tag Top fish at 8,390' md. -PU -Rotate w/ 40 rpm. -Enter 4 1/2" Tubing Stub w/ no issues. -Wash own to 8,472 m . 13:30 - 17:00 3.50 PULL P DECOMP Continue RIH w/ 4" DP. -Ta 'unk at 8 494' md. -Push down -Rotate down. -Tagging up occasionally. -Exit bottom of Fish at 9,751' md. 17:00 - 17:30 0.50 PULL P DECOMP Wash & ream through 7" Casing from 9,751' - 9,777' md. -Enter 4 1/2" Tubing Stub at 9,777' md. -Rotate down and tag Junk at 9,798' md. 17:30 - 19:00 1.50 PULL P DECOMP ump . sweep ~ 252 gpm 2000 psi. -Pull up to 9,740' and after sweep clears Mill. 19:00 - 22:00 3.00 PULL P DECOMP Monitor Well -Well Static. -Drop Dart. -Pump Dry Job. -POH f/ 9,730' U 1,805' md. 22:00 - 23:00 1.00 PULL P DECOMP LD BHA: -LD Jars, Bumper Sub, Pump out Sub. -Rack Back 2 7/8" PAC Pipe. -LD Bit Sub, Junk Mill. 23:00 - 23:30 0.50 PULL P DECOMP Pull Wear ring. -Install Test Plug. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 13 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: ~ NPT ', Phase Description of Operations Date From - To Hours ', Task Code 9/22/2008 23:00 - 23:30 0.50 PULL P DECOMP -RU Test Equipment. 23:30 - 00:00 0.50 BOPSU P DECOMP BOPE Test: -PJSM for testing BOPE's. -Begin testing BOPE's. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Spacer spool C~3 18". Test BOP and related equipment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3,500 psi high x 5 min each on chart. -Test Hydril w/ 4" test jt. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test choke valve #7. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Top & bottom Rams w/ 4" test joint and 4-1/2" test joint: -Test witness waived by Chuck Shieve AOGCC. OA = 0 psi. Daily losses = 0 Cummulative losses = 66 bbls 9.8 ppg NaCI Brine. 9/23/2008 00:00 - 07:00 7.00 BOPSU P DECOMP Continue to test BOP equipment: ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Spacer spool ~ 18" Test BOP and related equipment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3,500 psi high x 5 min each on chart. -Test Hydril w/ 4" test jt. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test HCR choke. -Test Manual Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test top & bottom Rams w/ 4" test joint and 4-1/2" test joint. -Perform accumulator test 1. System pressure: 3250 psi 2. Pressure after close: 1950 psi 3. 200 psi attained ~ 44 sec 4. Full pressure attained ~ 3 min 11 sec 5. Nitrogen: 4 bolt. x 2100 psi avg. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 14 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date 'From - To Hours Task Code NPT Phase Description of Operations 9/23/2008 00:00 - 07:00 7.00 BOPSU P DECOMP -Test witnessed by WSL and Tourpusher. -Test witness waived by Chuck Scheve, AOGCC Rep. 07:00 - 08:00 1.00 BOPSU P DECOMP -RD testing equipment and clear rig floor. -Blow down choke line, kill line and top drive. 08:00 - 09:30 1.50 FISH P DECOMP -Mobilize lubricator extension to rig floor. 09:30 - 10:30 i 1.001 FISH I P 10:30 - 12:00 I 1.501 FISH I P 12:00 - 18:00 I 6.001 FISH I P 18:00 - 00:00 6.001 FISH P 9/24/2008 00:00 - 01:00 1.00 FISH P 01:00 - 03:00 2.00 FISH P 03:00 - 04:30 1.50 FISH P 04:30 - 05:00 0.50 FISH P 05:00 - 06:00 1.00 FISH P 06:00 - 08:30 2.50 FISH P 08:30 - 11:00 I 2.501 FISH I P 11:00 - 12:00 I 1.001 FISH I P -MU lubricator extension and install in BOP stack. Close top rams. set slips and install dog collar. DECOMP -PU 2-7/8" DP single. Break out 3-3/4"junk mill and LD. -Clean rig floor mats. -Repair air line in draw works. DECOMP -Mobilize Schlumberger wireline pressure control equipment to rig floor. -Start RU Schlumberger a-line. 0 fluid losses for tour. DECOMP -Cont RU wireline pressure control equipment w/ wireline BOP, flow tubes and grease, lubricator and packoff. -Attempt to test wireline pressure control. Redress lubricator grease head. Test to 500 psi x 5 min. -MU cutter/CCL ass . DECOMP -Run jet cutter/CCL assy into BOP stack. Pressure test seal to 500 psi. -RIH w/jet cutter/CCL on e-line to top of tubing stump C~ +/- 8390'. Enter tubing stump after several attempts. -Cont. running a-line w/jet cutter/CCL inside tubing stump. Locate GLM assy. and correlate up to 4 full tubing joints below GLM. -Position jet cutter ~ 9430' WLM (middle of first full tubing joint below -Fire jet cutter and cut tubin @ 9430' WLM. Good indication of firin in unit. -POOH a-line w/jet cutter/CCL. Fluid losses for tour: 13 bbls 9.8 ppg brine. DECOMP Cont POOH a-line w/jet cutter/CCL assy. DECOMP -PJSM -Pull jet cutter to rig floor. Confirm jet cutter fired. -RD Schlumberger a-line egipment and pressure control. DECOMP -PU 24 jts 4" DP 1x1 and rack back on driller side. -Move 15 stands 2-7/8" DP from off driller side to driller side. DECOMP -Mobilize spear assy. to rig floor -Inspect and service top drive DECOMP MU fishing BHA w/spear + spear extensions + stop sub + pump out sub. PU bumper sub and jars. DECOMP -RIH to 7922'. MU top drive and enter top of 7" liner. -Cont. RIH to 8297'. Check parameters: PUW 175k /SOW: 130k DECOMP -MU top drive and wash down to 8390'. -Enga a fish. PU 25k over string weight and confirm fish engaged. -Attempt to circulate through fish. No success. -Attempt to pull fish free, jarring C~ 100k overpull and pulling max to 225k overpull. No success. DECOMP -Release spear. Rack back 2 stands. Drop dart and open Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 15 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: I s Date From - To Hours ~ Task Code` NPT'~ Phase ~ Description of Qperations 9/24/2008 11:00 - 12:00 1.00 FISH P DECOMP pump out sub. -Blow down top drive -POOH to 7530' 12:00 - 12:30 0.50 FISH P DECOMP -Inspect derrick. -Service rig. 12:30 - 15:30 3.00 FISH P DECOMP Cont. POOH f/ 7530' to BHA. 15:30 - 16:30 1.00 FISH P DECOMP LD intensifier. Rack back DCs. LD jars, bumper sub, pump out sub, spear extensions and spear assy. 16:30 - 20:30 4.00 FISH P DECOMP -Mobilize Schlumberger a-line equipment to rig floor. -MU lubricator extension and set in BOP stack. Close top rams. RU a-line pressure control equipment: wireline BOPs, flow tubes and grease, lubricator and packoff. Test pressure control equipment to 500 psi x 5 min. -MU jet cutter/CCL assy. 20:30 - 00:00 3.50 FISH P DECOMP -RIH w/jet cutter/CCL on e-line to 8600' W LM (inside tubing stump). Observe top of tubing stump @ 8400' WLM. -Tight spot inside tubing ~ 8600' WLM. Tool got stuck. Work and pull free w/ 1600 Ibs pull on a-line. -Attem t to run tool ast 8600'. Got stuck. Work and ull free w/ 2100 Ibs pull on a-line. -POOH 'et cutter/CCL to run junk basket and ring gauge. 9/25/2008 00:00 - 02:00 2.00 FISH P DECOMP Cont. POOH e-line w/jet cutter/CCL 02:00 - 03:30 1.50 FISH P DECOMP -Disarm and LD jet cutter. -MU 3.7" ring gauge +wireline junk basket +CCL 03:30 - 07:30 4.00 FISH P DECOMP -RIH w/ 3.7" ring gauge/funk baskeUCCL assy. on a-line to F 8390' (top of tubing stump). -Attem t to enter tubin No success -POOH a-line w/ ring gauge/junk baskeUCCL assy. 07:30 - 09:00 1.50 FISH P DECOMP RD Schlumberger a-line and pressure control equipment. 09:00 - 09:30 0.50 FISH P DECOMP -RU to run 2-7/8" PAC DP: change elevators, install power tongs. -Blow down kill line. 09:30 - 11:30 2.00 FISH P DECOMP MU BHA w/ 3-3/4" iunk mill + 47 its 2-7/8" PAC DP + Pump Out Sub + Bumper Sub and Jars. 11:30 - 12:00 0.50 FISH P DECOMP RIH w/ BHA on 4" DP to 2785' 12:00 - 13:30 1.50 FISH P DECOMP -Slip and cut drilling line (59.5') -Service top drive and blocks. 13:30 - 15:00 1.50 FISH P DECOMP -Cont. RIH w/ BHA on 4" DP to 7920'. Tag top of 7" liner. MU to drive and rotate to enter lin r. -Cont RIH to 8379'. 15:00 - 19:30 4.50 FISH P DECOMP -MU top drive and obtain parameters: PUW 165k /SOW 125k -Tag top of tubing stump ~ 8390'. Enter tubing stump. -Wash down in tubing to 8616'. Observe restriction. Set down with 8k WOB -Work and clean restriction ~ 8616' until free. 2-3k WOB / 50 RPM ~ 4k torque / 210 gpm C~ 940 psi. -Cont. washing down in tubin f/ 8616' to 9800'. No restrictions observed. 19:30 - 23:00 3.50 FISH P DECOMP -Pump Hi-vis sweep and circulate surface-surface. 336 gpm ~ 2600 psi. Observe large amount of sand in returns. Continue getting sand returns after sweep out of well. -Pump another Hi-vis sweep and circulate surface-surface until returns clean. 336 gpm C~ 2600 psi. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 16 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date ii From - To Hours Task Code NPT Phase Description of Operations 9/25/2008 23:00 - 23:30 0.50 FISH P DECOMP POOH f/ 9800' to 8379' (above top of tubing stump). Check area ~ 8616' when POOH and run through it free. 23:30 - 00:00 0.50 FISH P DECOMP Pump Hi-vis sweep. Circulate surface-surface. 357 gpm ~ 2500 psi. 9/26/2008 00:00 - 01:00 1.00 FISH P DECOMP -Cont. circulating hi-vis sweep surface-surface. 357 gpm ~ 01:00 - 04:00 3.00 FISH P 04:00 - 06:00 2.00 FISH P 06:00 - 06:30 0.50 FISH P 06:30 - 09:00 2.50 FISH P 09:00 - 12:00 3.00 FISH ~ P 12:00 - 14:00 2.00 FISH P 14:00 - 15:30 1.50 FISH P 15:30 - 18:30 3.00 FISH P 18:30 - 20:30 2.00 FISH P 20:30 - 00:00 3.50 FISH P 9/27/2008 00:00 - 01:00 1.00 FISH P 01:00 - 01:30 0.50 FISH P 01:30 - 04:30 I 3.001 FISH I P 04:30 - 09:00 I 4.501 FISH I P 2500 psi. Returns clean. -Drop dart and open pump out sub. Pump dry job. DECOMP -Blow down top drive. -POOH f/ 8379' to 1837' (BHA) DECOMP -Rack back 4-3/4" DCs and 2-7/8" DP. -LD rest of BHA. DECOMP -Clear rig floor. -C/O elevators DECOMP -Mobilize Schlumberger a-line and pressure control equipment to rig floor. -Install lubricator extension in BOP stack. Close top rams. -RU a-line pressure control: wireline BOPS, flow tubes and grease, lubricator and packoff. Test to 500 psi x 5min. -Arm jet cutter. DECOMP -RIH w/jet cutter/CCL on e-line to top of tubin stum ~ 8390 - nter to ing stump and run to 9421'. Correlate w/ GLM - osition cutter and cut tubing ~ 9365' (middle of first full tba i -POOH a-line w/jet cutter/CCL DECOMP RD Schlumberger a-line equipment and pressure control. DECOMP MU fishing BHA w/ spear dress to catch in 4-1/2" tubing + spear extensions + stop sub + pump out sub + bumper sub + jars + intensifier. DECOMP RIH w/fishing BHA to 8387'. Check parameters; PUW 178k / SOW 130k. DECOMP -PU DP single and MU top drive. Break circulation w/ 160 gpm 420 psi. Shut down pumps. -Ta to of fish ~ 8390'. En a e fish. -Attempt to jar fish free f/ cut ~ 9365'. Jar ~ 100k over PUW. Pulling max. 200k over PUW. No success. Attempt to circulate while workin fish. No circulation. Hold 2000 psi while jarring. DECOMP -Release spear. LD DP single. -Drop dart and open pump out sub. -Perform post-jarring derrick and top drive inspection prior to POOH. -POOH with fishing BHA DECOMP -Rack back DCs. -LD intensifier, jars, bumper sub and spear assy. DECOMP -Clear rig floor. -PU and install lubricator extension in BOP stack and close top rams. DECOMP -Mobilize Schlumberger a-line and pressure control equipment to rig floor -RU a-line pressure control: wireline BOPs, flow tubes and grease, lubricator and packoff. Test to 500 psi x 5min. -Arm jet cutter DECOMP -RIH w/jet cutter/CCL to 9240' and correlate. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 17 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code' NPT Phase Description of Operations 9/27/2008 04:30 - 09:00 4.50 FISH P DECOMP -Pull to position cutter at cutting depth. Tool stuck ~ 9146' (CCL depth). Not able to run down or up. -Position CCL at 9146', jet cutter at 9158'. Cut tubing ~ 9158' while keeping 1000 Ibs overpull on a-line. Tool pulled free after firing jet cutter. -POOH w/jet cutter/CCL 09:00 - 11:00 2.00 FISH P DECOMP -Pull jet cutter to rig floor. Jet cutter fired. LD cutter. -Arm and MU new jet cutter. 11:00 - 15:00 4.00 FISH P DECOMP -RIH w/jet cutter/CCL. Correlate and position jet cutter in tubing. Cut tubing ~ 8715'. -POOH w/jet cutter/CCL 15:00 - 16:30 1.50 FISH P DECOMP -Pull jet cutter to rig floor and LD same. Jet cutter fired. -RD Schlumberger a-line and pressure control equipment. 16:30 - 18:00 1.50 FISH P DECOMP MU fishing BHA w/ spear dress to catch in 4-1/2" tubing + spear extensions + stop sub + pump out sub + bumper sub + jars + intensifier. 18:00 - 18:30 0.50 FISH P DECOMP Lubricate rig. Inspect top drive. 18:30 - 21:00 2.50 FISH P DECOMP RIH w/fishing BHA to 8387'. 21:00 - 22:30 1.50 FISH P DECOMP -MU top drive and obtain parameters: PUW 175k /SOW 130k. Break circulation w/ 190 gpm ~ 600 psi. Shut pumps. -Tag fish (~ 8390' and engage spear. Pull 25k over PUW and confirm spear engaged. Attempt to break circulation through _ fish. Presssure up to 2500 psi and hold. No returns. -Set jars. Attempt to jar fish free. Jar ~ 100k over PUW and pull max. 200k over PUW. No success after working on fish for 1 hr. 22:30 - 00:00 1.50 FISH P DECOMP -Release spear. LD DP single. -Drop dart and open pump out sub. -Perform post-jarring derrick inspection prior to POOH. -POOH with fishing BHA to 8000' 9/28/2008 00:00 - 00:30 0.50 FISH P DECOMP -Pump dry job. -Blow down and inspect top drive. 00:30 - 03:30 3.00 FISH P DECOMP Cont. POOH f/ 8000' to 421' (BHA) 03:30 - 04:00 0.50 FISH P DECOMP -Rack back DCs. -LD intensifier, jars, bumper sub and spear assy. 04:00 - 05:00 1.00 FISH P DECOMP -Clear rig floor. -PU and install lubricator extension in BOP stack and close top rams. 05:00 - 07:30 2.50 FISH P DECOMP -Mobilize Schlumberger a-line and pressure control equipment to rig floor. -RU a-line pressure control: wireline BOPS, flow tubes and grease, lubricator and packoff. Test to 500 psi x 5 min. -Arm and MU jet cutter. 07:30 - 10:30 3.00 FISH P DECOMP -RIH w/jet cutter/CCL on a-line to 8585' and correlate (in tubing). Position cutter and cut tubing ~ 8550'., -POOH a-line w/jet cutter/CCL. Jet cutter fired. 10:30 - 12:00 1.50 FISH P DECOMP -LD jet cutter. -RD Schlumberger a-line equipment and pressure control. 12:00 - 12:30 0.50 FISH P DECOMP Lubricate rig and inspect top drive. 12:30 - 13:30 1.00 FISH P DECOMP MU fishing BHA w/ spear dress to catch in 4-1/2" tubing + spear extensions + stop sub + pump out sub + bumper sub + jars + intensifier. 13:30 - 15:30 2.00 FISH P DECOMP RIH w/fishing BHA to 8300' Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Page 18 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 9/28/2008 15:30 - 17:00 1.50 FISH P DECOMP Slip and cut drilling line (59.5'). 17:00 - 17:30 0.50 FISH P DECOMP -MU top drive and obtain parameters: PUW 178k /SOW 130k. Break circulation w/ 150 gpm @ 350 psi. Shut pumps. -Tag fish ~ 8390' and en a e s ear. Set 'ars and 'ar ~ 100 over PUW, pulling max. 200k over PUW. Observed progress. Repeat iarrina until fish null free. Establish circulation throuoh 17:30 - 19:00 i 1.501 FISH I P 19:00 - 22:30 I 3.501 FISH I P 22:30 - 23:00 0.501 FISH P 23:00 - 00:00 I 1.001 FISH I P 9/29/2008 100:00 - 00:30 I 0.501 FISH I P 00:30 - 01:30 I 1.001 FISH I P 01:30 - 05:00 3.501 FISH P 05:00 - 08:00 3.001 FISH P 08:00 - 08:30 0.50 FISH P 08:30 - 09:30 1.00 FISH P 09:30 - 12:00 2.50 FISH P 12:00 - 12:30 0.50 FISH P 12:30 - 13:30 1.00 FISH P 13:30 - 16:30 3.00 FISH P DECOMP -Pump hi-vis sweep and circulate surface-surface through fish. 405 gpm @ 2500 psi. -Observed some returns of sand and shale with sweep. DECOMP -LD DP single. POOH until fish above top of 7" liner (7 stands). -Drop dart and open pump out sub. Pump dry job. -Cont POOH w/ fish to BHA. DECOMP -Rack back DCs. -LD rest of fishing BHA. -Fish on surface. DECOMP -RU to LD fish. -LD fish (4-1/2" 12.6# L-80 IBT tubing): recover 21.15' top cutoff jt (cutoff jt #204) + 3 full jts (#205, #206 and #207) + 21.95' bottom cutoff jt (cutoff jt#208). LD spear w/ top cutoff (could not disengage). -Jet cut clean, flare to +/- 5" OD -Top cutoff is deformed and has a hole at +/- 3' from top. This is same area of fish where spear engaged and grapple broke during jarring job on 9/21/08. DECOMP -Inspect and service top drive, blocks and draw works. -Blow down choke line. DECOMP MU washover BHA w/ 6" x 5" washover shoe + 5-3/4" washpipe and washpipe extensions (total swallow of +/- 177') + pump out sub + bumper sub + jars. DECOMP -RIH f/ 573' to 8538'. -Obtain parameters: PUW 185k /SOW: 127k DECOMP -PU stand #85 and MU top drive. -Break circulation w/ 210 gpm ~ 530 psi. Check ROTW 148k C~ 60 RPM (free torque 5k). -Wash down and tag T.O F ~ 8558'. -Washover fish f/ 8558'-8610'. 60 RPM / 5-8k torque, 2-5k WOB. Cont. washover f/ 8610'-8618'. Increase WOB in this interval to 6-8k. 60 RPM / 5-10k torque. Washover f/ 8618'-8642' w/ 2k WOB. 60 RPM / 5-8k torque. No more progress after 8642'. Increase WOB to 25k, torque stays at 5k DECOMP Pump out of hole f/ 8642' to 8442'. DECOMP Pump Hi-vis sweep and circulate surface-surface, 525 gpm ~ 2780 psi. Rotate and reciprocate while circulating. Observe sand in returns. DECOMP -POOH f/ 8442' to 7000'. -Pump dry job. Cont. POOH f/ 7000' to 2277' DECOMP Lubricate rig and inspect top drive. DECOMP Cont. POOH f/ 2277' to 573' (BHA) DECOMP -Rack back DCs. -LD washover BHA. Washover shoe still w/ usable cutting structure. Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Page 19 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description. of Operations 9/29/2008 13:30 - 16:30 3.00 FISH P DECOMP -Clean boot basket: recover +/-15 Ibs metal trash. Piece of spear grapple recovered in basket (+/- 1" x 2"). -Clear rig floor. 16:30 - 18:30 2.00 FISH P DECOMP MU fishin BHA w/ s ear dress to catch in 4-1/2" tubin + pump out sub + bumper sub +jars + intensifier. RIH on 4-3/4" DCs to 411'. 18:30 - 21:00 2.50 FISH P DECOMP RIH w/fishing BHA f/ 411' to 8500'. 21:00 - 21:30 0.50 FISH P DECOMP -MU top drive and obtain parameters: PUW 180k /SOW 130k. Break circulation w/ 155 gpm C~? 400 psi. Shut down pumps. -Tap fish ~ 8584' (26' deeper than expected per prior tag with Pull fish free (no 21:30 - 22:30 1.00 FISH P DECOMP Break circulation through fish. CBU C~? 420 gpm / 2330 psi. Returns clean. 22:30 - 00:00 1.50 FISH P DECOMP -POOH 10 stands until fish above top of 7" liner. -Drop dart and open pump out sub. Pump dry job. -Cont. POOH to 5900' 9/30/2008 00:00 - 00:30 0.50 FISH P DECOMP Service blocks, draw works and crown. Service and inspect top drive. 00:30 - 02:30 2.00 FISH P DECOMP Cont. POOH w/fish f/ 5900' to 411' (BHA). 02:30 - 03:00 0.50 FISH P DECOMP -Rack back DCs. -LD jars, bumper sub, pump out sub and spear. 03:00 - 03:30 0.50 FISH P DECOMP -LD fish (4-1/2" tubing). Recover 19.78' cutoff jt Qt #208 cutoff) + 1 full jt (#209). Total length recovered: 59.01'. Full jt popped out of bottom connection when collar was shaved with washovershoe. -Collar between cutoff and full 't recovered artiall shaved. Bottom end of full it shaved on one side and cracked. Pin damaged. 03:30 - 04:30 1.00 FISH P DECOMP MU fishin BHA w/ spear dress to catch in 4-1/2" tubing + spear extensions + stop sub + pump out sub + bumper sub + jars + intensifier. RIH on 4-3/4" DCs to 421' 04:30 - 07:00 2.50 FISH P DECOMP RIH w/fishing BHA f/ 421' to 7550' 07:00 - 08:30 1.50 FISH P DECOMP -Slip and cut drilling line (59.5') -Inspect and service top drive, draw works, blocks and crown. 08:30 - 09:00 0.50 FISH P DECOMP Cont. RIH f/ 7550' to 8582'. 09:00 - 09:30 0.50 FISH P DECOMP -MU top drive and obtain parameters: PUW 185k /SOW 130k. -Break circulation w/ 189 gpm C~3 550 psi. Shut down pumps. -Tao fish ~ 8643'. Attemp to enter fish. No success. -Pump C~ 63 gpm and enter fish. Engage spear. -Pull fish free w/ 25k over PUW. _ 09:30 - 10:30 1.00 FISH P DECOMP CBU through fish ~ 441 gpm / 2900 psi. 10:30 - 12:00 1.50 FISH P DECOMP -POOH w/fish from 8643' to 7246'. -Drop dart and open pump out sub. -Observe well and pump dry job. 12:00 - 12:30 0.50 FISH P DECOMP Lubricate rig and inspect top drive. 12:30 - 15:00 2.50 FISH P DECOMP Cont. POOH w/fish from 7246' to 421' BHA. 15:00 - 15:30 0.50 FISH P DECOMP -Rack back DCs. -LD intensifier, jars, bumper sub, pump out sub and spear assy. 15:30 - 18:30 3.00 FISH P DECOMP -LD fish (4-1/2" tubin :recover 2 full jts (#210 & #211) + 21.52' cutoff jt (#212 jt cutoff). Total length of this section: 105.07'. Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Page 20 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date 'From - To Hours ' Task Code 9/30/2008 15:30 - 18:30 3.00 FISH P 18:30 - 19:30 1.00 BOPSU P NPT (, Phase ~ Description of Operations DECOMP -When pulling bottom cutoff observe that another section of fis was coming with first one. Bottom cutoff had intruded in top cutoff of next section and both sections were pulled together. -LD next section recovered: 17.07' cutoff jt (rest of jt #212) + 10 full jts Qts #213-#222) + 13.95' cutoff jt (jt #223 cutoff). Total lenght of this section: 440.40'. Total recovered in this trip: 545.47' of 4-1/2" tubin . DECOMP -Pull wear bushing. Install test plug. -RU to test BOP. 0/1/2008 19:30 - 00:00 0:00 - 03:00 4.50 .00 BOPSU OPSU P P DECOMP ECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high x 5min each on chart. Test annular preventer to 250 psi low - 3500 psi high x 5min each on chart. Testing w/ 4" test jt. Test witnessed by WSL, Tourpusher and AOGCC Rep. (John Crisp). Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high x 5min each on chart. Test annular preventer to 250 psi low - 3500 psi high x 5min each on chart. Test components w/ 4" test jt. Test to rams and bottom rams w/ 4" and 4-1/2" testis. Test witnessed by WSL, Tourpusher and AOGCC Rep (John Crisp). -Perform koomey test: 1. System Pressure: 3175 psi 2. Pressure after close: 2000 psi 3. 200 psi attained at 36 sec 4. Full pressure attained at 2 min 46 sec 5. Nitrogen bottles: 4 x 2200 psi avg. -Tested 29 components: 1.13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. Inside BOP, FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) 03:00 - 03:30 0.50 BOPSU P DECOMP -RD testing equipment. Pull test plug. -Blow down kill line, choke line and top drive. 03:30 - 04:00 0.50 FISH P DECOMP -Install wear bushing. -Mobilize spear assy. and BHA tools. 04:00 - 05:00 1.00 FISH P DECOMP MU fishing BHA w/ spear dress to catch in 4-1/2" tubing + spear extensions + stop sub + pump out sub + bumper sub + jars + intensifier. RIH on 4-3/4" DCs to 421' 05:00 - 08:30 3.50 FISH P DECOMP -RIH w/fishing BHA to 7920' -MU top drive, rotate and enter 7" liner. -Cont. RIH to top of fish ~ 9188'. 08:30 - 09:00 0.50 FISH P DECOMP -MU top drive and obtain parameters: PUW 190k /SOW 140k. Break circulation w/ 84 gpm @ 170 psi. Shut down pumps. -Enter fish ~ 9188' and engage spear. -Pull fish free w/ 30k over PUW. Establish circulation through fish w/ 336 gpm ~ 1780 psi. Printed: 10/20/2008 12:29:13 PM U BP EXPLORATION Page 21 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date 'From = To ~, Hours Task Cade NPT Phase Description of Operations 10/1/2008 09:00 - 10:00 1.00 FISH P DECOMP -Pump hi-vis sweep and circulate surface-surface. 420 gpm ~ 2700 psi. Reciprocate pipe while circulating -Observe little sand and scale in returns. 10:00 - 12:00 2.00 FISH P DECOMP -POOH w/fish f/ 9188' to 7900' -Drop dart and open pump out sub. Pump dry job. -Cont. POOH w/fish f/ 7900' to 6650' 12:00 - 12:30 0.50 FISH P DECOMP Lubricate rig and inspect top drive. 12:30 - 15:00 2.50 FISH P DECOMP Cont. POOH w/fish f/ 6650' to 421' (BHA). 15:00 - 15:30 0.50 FISH P DECOMP -Rack back DCs. -LD intensifier, jars, bumper sub, pump out sub and spear assy. 15:30 - 16:30 1.00 FISH P DECOMP -LD fish: recover 27.77' cutoff jt (rest of jt #223) + 4 full jts (jts #224-#227) + 20.60' cutoff jt Qt #228 cutoff). Total lenght of this section: 207.60'. 16:30 - 17:30 1.00 FISH P DECOMP MU fishin BHA w/ s ear dress to catch in 4-1/2" tubing + spear extensions + stop sub + pump out sub + bumper sub + jars + intensifier. RIH on 4-3/4" DCs to 421' 17:30 - 20:00 2.50 FISH P DECOMP RIH w/fishing BHA to 9300' 20:00 - 20:30 0.50 FISH P DECOMP -MU top drive and obtain parameters: PUW 195k /SOW 135k. Break circulation w/ 160 gpm ~ 450 psi. Shut down pumps. -Tag fish C~ 9396'. Attempt to enter fish w/ pumps off. Start pumps ~ 84 gpm / 150 psi and work on top of fish until enter same with spear. -Engage spear. Pull fish free w/ 30k over PUW. 20:30 - 22:00 1.50 FISH P DECOMP -Pump hi-vis sweep and circulate surface-surface. 290-400gpm ~ 1260-2500 psi. Reciprocate pipe while circulating. -Clean returns with sweep. 22:00 - 00:00 2.00 FISH P DECOMP -POOH w/fish f/ 9396' to 7800' -Drop dart and open pump out sub. Pump dry job. -Cont. POOH w/fish f/ 7800' to 6770' 10/2/2008 00:00 - 00:30 0.50 FISH P DECOMP Inspect and service top drive, blocks and draw works. 00:30 - 02:30 2.00 FISH P DECOMP Cont. POOH w/fish f/ 6770' to 421' (BHA). 02:30 - 03:00 0.50 FISH P DECOMP -Rack back DCs. -LD intensifier, jars, bumper sub, pump out sub and spear assy. 03:00 - 03:30 0.50 FISH P DECOMP - h: recover 18.58' cutoff jt (rest of jt #228) + pup jt +GLM + pup jt + 20.00' cutoff jt Qt #229 cutoff). Total lenght of this section: 65.17'. 03:30 - 04:30 1.00 FISH P DECOMP -Clear rig floor. -C/O elevators. -C/O spear grapple and spear packoff rubber. 04:30 - 05:00 0.50 FISH P DECOMP -MU fishin BHA w/ s ear dress to catch in 4-1/2" tubing + spear extensions + stop sub + pump out sub + bumper sub + jars + intensifier. RIH on 4-3/4" DCs to 421' -PU 1 stand 4" DP 05:00 - 06:00 1.00 FISH P DECOMP Slip and cut drilling line (59.5'). 06:00 - 09:00 3.00 FISH P DECOMP Cont. RIH w/fishing BHA f/ 510' to 9420'. 09:00 - 09:30 0.50 FISH P DECOMP -MU top drive and obtain parameters: PUW 200k /SOW: 135k. Break circulation w/ 105 gpm ~ 230 psi. Shut down pumps. -Taq fish ~ 9457'. Pull fish free w/ 20k over PUW. -Attempt to pump through fish. Cont. pulling with 20k drag to 9410'. Establish circulation. Increase pump to 336 gpm ~ Printed: 10/20/2008 12:29:13 PM U BP EXPLORATION Page 22 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: ~ Date From - To Hours Task Code NPT Phase Description of Operations 10/2/2008 09:00 - 09:30 0.50 FISH P DECOMP 1880 psi and work pipe down to 9450' (free). 09:30 - 11:00 1.50 FISH P DECOMP CBU, 450 gpm ~ 2950 psi. Observe sand in returns. 11:00 - 12:00 1.00 FISH P DECOMP POOH until fish above 7" liner. 12:00 - 12:30 0.50 FISH P DECOMP -Inspect top drive -Drop dart and open pump out sub. Pump dry job. 12:30 - 15:00 2.50 FISH P DECOMP Cont POOH w/ fish to 421' (BHA) 15:00 - 15:30 0.50 FISH P DECOMP -Rack back DCs. -LD intensifier, jars, bumper sub, pump out sub and spear assy. 15:30 - 16:00 0.50 FISH P DECOMP -Conduct table top evacuation drill. -PJSM on LD tubing. 16:00 - 17:00 1.00 FISH P DECOMP -RU to LD fish (4-1/2" tubing). -LD fish: recover 19.11' cutoff jt (rest of jt #229) + 7 full jts Qts #230-#236) + 20.62' cutoff jt Qt #237 cutoff). Total length of fish recovered: 321.18' (last section of fish). 17:00 - 18:30 1.50 FISH P DECOMP -Service break spear. Mobilize fishing BHA tools off rig floor. -Mobilize tools for dress off BHA to rig floor. 18:30 - 20:00 1.50 CLEAN P DECOMP MU dress off BHA w/ 6" x 4-9/16" washover shoe +washpipe extensions + 4-3/4" dress off mill (inside washpipe extensions). RIH on 4-3/4" DCs to 420' 20:00 - 23:30 3.50 CLEAN P DECOMP RIH w/dress off BHA f/ 420' to 9712'. 23:30 - 00:00 0.50 CLEAN P DECOMP -MU top drive and obtain parameters: PUW 215k /SOW 130k / ROTW 165k. Free torque 7k ~ 60 RPM. -Establish circulation w/ 210 gpm @ 600 psi. -Wash down and tag top of tubing stump ~ 9777'. 10/3/2008 00:00 - 01:00 1.00 CLEAN P DECOMP -Work on top of stub w/ washover shoe. Washover tubing stump and swallow 17' in washpipe extensions (bottom of washover shoe ~ 9794') until tag top of stump w/dress off mill. 210 gpm C~ 600-700 psi. 60 RPM ~ 7-10k torque. -Dress off 1' top of tubing stump. New top of tubing stump C~3 9778'. -Work over tubing stump with pumps and without rotation. OK. 01:00 - 03:00 2.00 CLEAN P DECOMP -Pump hi-vis sweep and circulate surface-surface w/ 462 gpm ~ 2850 psi, while reciprocating pipe. Returns clean. -Swallow tubing stump in washpipe extensions without rotation and pumps. OK 03:00 - 07:30 4.50 CLEAN P DECOMP -POOH w/dress off BHA f/ 9795' to 7860'. -Drop dart and open pump out sub. Pump dry job. -Cont POOH w/dress off BHA f/ 7860' to 420' (BHA) 07:30 - 09:30 2.00 CLEAN P DECOMP -Rack back 4 stands 4-3/4" DCs -LD pump out sub, bumper sub, jars, washpipe extensions and washover shoe. Clean boot basket: piece of grapple, pieces of SS bands, other metallic cuttings. 09:30 - 10:00 0.50 CLEAN P DECOMP Mobilize BHA tools off rig floor. 10:00 - 10:30 0.50 CLEAN P DECOMP Lubricate rig. Inspect top drive. 10:30 - 11:30 1.00 CLEAN P DECOMP Wait on 9-5/8" RTTS packer. 11:30 - 12:30 1.00 CLEAN P DECOMP -Mobilize 9-5/8" RTTS to rig floor. -MU RTTS to 1 stand of 4" DP. 12:30 - 15:30 3.00 CLEAN P DECOMP RIH w/ 9-5/8" RTTS on 4" DP to 7200' 15:30 - 16:30 1.00 CLEAN P DECOMP -Set RTTS ~ 7212' COE -RU to test 7" liner below RTTS. -Test below RTTS to 3500 psi x 30 min on chart. Test good. -RD testing egwpment. Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Page 23 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code ! NPT Phase Description of Operations 10/3/2008 16:30 - 19:00 2.50 CLEAN P DECOMP -Unseat RTTS -POOH w/ RTTS to 3500'.: 19:00 - 20:30 1.50 CLEAN P DECOMP -Set RTTS ~ 3510' (COE) -RU to test 9-5/8" casin above RTTS. -Test above RTTS to 3500 psi x 30 min on chart. Test good. - testing egwpment. ow own choke and kill line. 20:30 - 21:30 1.00 CLEAN P DECOMP -Unseat RTTS -POOH w/ RTTS to surface. 21:30 - 22:00 0.50 CLEAN P DECOMP LD RTTS and mobilize off rig floor. 22:00 - 00:00 2.00 DHB P DECOMP -MU 7" RBP w/ running tool. -RIH w/ 7" RBP on 4" DP to 4000'. 10/4/2008 00:00 - 01:30 1.50 DHB P DECOMP Cont. RIH w/ 7" RBP f/ 4000' to 7881'. 01:30 - 02:30 1.00 DHB P DECOMP -Enter 7" liner. Check parameters: PUW 165k /SOW 120k. -Set 7" RBP ~ 8040' (COE) per HES rep. Top of tool (F.N) ~ 6, 02:30 - 05:00 2.50 DHB P DECOMP -POOH 1 stand to 7940'. -Dump 1200# (24 sacks) of 20/40 mesh sand down drill pipe. - ump ri pipe s ring vo ume s 05:00 - 06:00 1.00 DHB P DECOMP -Wait for sand to settle. -Lubricate rig and inspect top drive while waiting. 06:00 - 06:30 0.50 DHB P DECOMP RIH and tag top of sand @ 7994'. 06:30 - 09:30 3.00 DHB P DECOMP POOH and LD RBP running tool. 09:30 - 10:00 0.50 CLEAN P DECOMP -Clear rig floor. -Mobilize tools for next BHA to rig floor. 10:00 - 11:00 1.00 CLEAN P DECOMP MU BHA w/ 7" bull nose mill + 9-5/8" casin scra er + pump out sub + bumper sub. RIH on 4-3/4" DCs to 393'. 11:00 - 12;00 1.00 CLEAN P DECOMP -RIH on 4" DP f/ 393' to 3150'. -Reciprocate 9-5/8" casing scraper in interval 3150' - 3250' 4x . -Cont. RIH on 4" DP f/ 3250' to 4180'. 12:00 - 12:30 0.50 CLEAN P DECOMP Lubricate rig. Service top drive. 12:30 - 13:30 1.00 CLEAN P DECOMP Cont. RIH f/ 4180' to 7900'. 13:30 - 14:30 1.00 CLEAN P DECOMP -MU top drive and obtain parameters: PUW 175k /SOW 120k. Torque (free): 5k ~ 50 RPM. -Enter to of liner C~3 7919'. Tag ~ 7922'. Condition inside tie ba k rece tacle f/ 7922' to 7930. 1 gpm ~ 420 psi. 50 (~ 8-12k torque. 0-3k WOB. 14:30 - 15:30 1.00 CLEAN P DECOMP Circulate hi-vis sweep surface-surtace. 565 gpm ~ 2550 psi. Rotate and reciprocate pipe while circulating. 15:30 - 18:30 3.00 CLEAN P DECOMP POOH f/ 7900' to 393' (BHA). 18:30 - 20:00 1.50 CLEAN P DECOMP -Rack back DCs. -LD bumper sub, pump out sub, casing scraper and bull nose (mill). -Clear rig floor. 20:00 - 21:00 1.00 CASE P DECOMP RU to run 7" liner tie back: C/O elevators, install power tongs. 21:00 - 23:00 2.00 CASE N WAIT DECOMP -While RU to run liner tie back, fishing hand verify at the shop OD in bull nose mill ran in previous BHA to condition tie back receptacle. OD found to be 6-3/4" on bottom to 6-7/8" in base of bull nose (f/original OD of 7"). Obtained information about tie back receptacle specs, determining that receptacle has 6. 844" ID. -Review options with ODE. Decide to machine out OD in 7" mule shoe to 6-3/4" at machine shop. Printed: 10/20/2008 12:29:13 PM • ~ BP EXPLORATION Page 24 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: i Hours Task Code NPT Phase Description of Operations Date From - To 10/4/2008 23:00 - 00:00 1.00 CASE N WAIT DECOMP Order truck to transport 7" mule shoe to Baker Machine Shop. Wait on truck. 10/5/2008 00:00 - 00:30 0.50 CASE P DECOMP Lubricate rig. Service and inspect top drive. 00:30 - 06:00 5.50 CASE N WAIT DECOMP -Sent 7" mule shoe to Baker machine shop. -Machine out mule shoe OD to 6-3/4". -Receive tool back in rig. Verify OD and drift to 6.151 ". Re-strap. 06:00 - 11:30 5.50 CASE P DECOMP -MU 6-3/4" OD mule shoe (6.276" ID / 6.151" drift) w/ 8.25" OD collar and ported (4 ea 1 "ports) 7" 26# pup jt. -Run 7" 26# L-80 BTC-M liner tie back per running order, Total jts run: 116. Install one floating straight centralizer per jt on jts #2-116 (total 115 centralizers). Fill every 5 jts. -MU 7" x 9-5/8" Liner Hanger -Top Packer Assy. 11:30 - 13:00 1.50 CASE P DECOMP -RIH w/ 7" liner tie back on 1 stand 4" DP. -Circulate liner volume: 168 gpm C~3 140 psi. -Verify liner weight C~? 95k 13:00 - 14:30 1.50 CASE P DECOMP RIH w/ 7" liner tie back on 4" DP to 7820'. 14:30 - 15:30 1.00 CASE P DECOMP -MU top drive and cement head. Break circulation w/ 170 gpm C~ 250 psi. -Wash down and tag top of 7" liner w/mule shoe ~ 7919'. Run mule shoe into tie back receptacle until No-Go collar tag on top of liner. PU 2'. -PUW 212k /SOW 145k. 15:30 - 16:00 0.50 CASE P DECOMP Circulate w/ 212 gpm C~ 380 psi. 16:00 - 16:30 0.50 CASE P DECOMP Give it to Schlumberger: -Pressure test lines to 4500 psi. -Pum 144 bbls 15.8 cement w/ GASBLOK. -Drop dart and kick same out w/ 5bbls water. 16:30 - 17:30 1.00 CASE P DECOMP -Displace cement w/ 9.8 ppg brine using rig pumps. 6-7.5 bpm. Slow pump rate to 1 bpm last 10 bbls displaced before bumping plug. ICP: 120 psi. FCP: 1925 psi. -Bump plug and increase pressure to 3000 si. Hold pressure and slac off to 110k to set liner hanger. -Increase ressure to 4000 si and set to acker. -Bleed off pressure and check floats. Rotate 15 turns to the right and release running tool. Pressure up to 1000 psi and pull running tool out of hanger. Observe pressure drop as running tool is out. -CIP ~ 17:30 -Observe 35 bbls lost Burin dis lacement. Had returns all time during displacement. -Top of liner tie back C~3 3221'. Landing collar ~ 7855'. Float collar ~ 7897'. Bottom of mule shoe ~ 7927'. 17:30 - 18:30 1.00 CASE P DECOMP Circulate on top of liner w/ 550 gpm ~ 930 psi. No cement returns to surface. 18:30 - 19:30 1.00 CASE P DECOMP -LD cement head. -Pump nut plug sweep and circulate surface-surface. 370 gpm / 400 psi. 19:30 - 21:00 1.50 CASE P DECOMP POOH 4" DP w/ liner running tool. 21:00 - 21:30 0.50 CASE P DECOMP -LD liner running tool. -Clear rig floor of liner running equipment. -Mobilize tools for cleanout BHA to rig floor. 21:30 - 22:00 0.50 CLEAN P DECOMP MU cleanout BHA w/ 6" bit + 2 boot baskets + pump out sub + Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Page 25 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours ~' Task Code N'PT 10/5/2008 21:30 - 22:00 0.50 CLEAN P 22:00 - 23:00 1.00 CLEAN P 23:00 - 00:00 1.00 CLEAN P 10/6/2008 00:00 - 00:30 0.50 CLEAN P 00:30 - 02:00 1.50 CLEAN P 02:00 - 03:00 I 1.001 CLEAN I P Spud Date: 4/21 /1986 Start: 9/12/2008 End: 10/13/2008 Rig Release: 10/13/2008 Rig Number: Phase Description of Operations DECOMP 4-3/4" DCs. DECOMP RIH w/ cleanout BHA on 4" DP to 2400'. DECOMP Slip and cut drilling line (59.5'). DECOMP Lubricate rig. Service and inspect top drive. DECOMP WOC to develop 500 psi compressive strength prior to testing casing-liner tie back. (RU to test casing and liner tie back) -Per Schlumberger cement test: 500 psi develops ~ 7.5 hrs. Gave total 8.5 hrs from CIP ~ 17:30 10-5-08. DECOMP -Test 9-5/8" casing and 7" liner tie back to 3500 psi x 30 min ~ 03:00 - 04:00 1.00 DHB P DECOMP -Mobilize 9-5/8" storm packer w/ running tool to rig floor. -MU 9-5/8" storm packer. RIH and set ~ 100' (COEI. -rseiease running roa ana rvun. -RU testing equipment -Test storm packer f/ above to 3500 psi x 10 min on -RD testing equipment. 04:00 - 06:00 2.00 BOPSU P DECOMP -Blow down kill and choke line. -Pull wear bushing. -Suck out BOP stack. -ND BOP 06:00 - 07:00 1.00 WHSUR P DECOMP -Remove secondary IA valve from tubing spool. -Remove tubing spool and move it off cellar. -Pull old 9-5/8" mandrel packoff 07:00 - 09:30 2.50 WHSUR P DECOMP -Install new 9-5/8" mandrel packoff and new tubing spool. -Test packoff to 5000 psi x 30 min per FMC rep. Test good. 09:30 - 11:00 1.50 BOPSU P DECOMP -NU BOP, choke hose, riser and flow line. -Install secondary IA valve on tubing spool. 11:00 - 12:00 1.00 BOPSU P DECOMP -Install test plug and RU to test. -Test breaks at BOP stack and choke line to 250 psi low - 3500 psipsi hig~ h x 5 min each on chart. -RD testing equipment and pull test plug 12:00 - 12:30 0.50 WHSUR P DECOMP Install wear bushing. 12:30 - 13:00 0.50 DHB P DECOMP -RIH w/ running tool and release storm packer. -POOH and LD storm packer. 13:00 - 13:30 0.50 CLEAN P DECOMP RIH f/ 2400'. Enter top of liner ~ 3221'. Tag on bottom of tie back sleeve ~ 3232'. 13:30 - 15:00 1.50 CLEAN P DECOMP -Attempt to circulate past 3232'. No success. -237 gpm ~ 260 psi. 40 RPM ~ 1-5k torque. 5k WOB. PUW 95k /SOW 95k / ROTW 95k. 15:00 - 16:00 1.00 CLEAN P DECOMP POOH w/ cleanout BHA 16:00 - 16:30 0.50 CLEAN P DECOMP -LD 6" bit. -MU 5-1/2" bladed junk mill, 16:30 - 17:00 0.50 CLEAN P DECOMP RIH to 3200'. 17:00 - 18:00 1.00 CLEAN P DECOMP -Enter liner ~ 3221' and tag @ 3232'. -Mill through spot ~ 3232' (5x) until can get by without rotation. -Cont RIH to 3300'. -235 gpm ~ 360 psi. 40 RPM ~ 1-4k toruge. WOB 1-5k. PUW 95k /SOW 95k / ROTW 95k. 18:00 - 19:30 1.50 CLEAN P DECOMP POOH w/ bladed junk mill. Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Page 26 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours ' Task ~ Code NPT Phase Description of Operations 10/6/2008 19:30 - 20:30 1.00 CLEAN P DECOMP -LD 5-1/2" bladed mill. No wear observed in face of junk mill. Wear observed on gauge. -MU 3-3/4" x 6" tapered mill and 6.151" upper whipstock (watermelon) mill. PU bumper sub and jars. 20:30 - 21:30 1.00 CLEAN P DECOMP RIH to 3200' 21:30 - 23:30 2.00 CLEAN P DECOMP -Enter liner and tag ~ 3232'. mill. Ream (up and dowm) through it 23:30 - 00:00 0.501 CLEAN P 10/7/2008 100:00 - 00:30 I 0.50 I CLEAN I P 00:30 - 01:30 I 1.00 I CLEAN I P 01:30 - 02:00 0.501 CLEAN P 02:00 - 03:00 1.00 CLEAN P 03:00 - 04:00 1.00 CLEAN P 04:00 - 04:30 0.50 CLEAN P 04:30 - 05:00 I 0.50 I CLEAN I P 05:00 - 08:00 3.00 CLEAN P 08:00 - 09:30 1.50 CLEAN P 09:30 - 15:30 ~ 6.00 CLEAN ~ P 15:30 - 16:30 I 1.00 I CLEAN I P 16:30 - 20:00 3.50 CLEAN P 20:00 - 21:00 1.00 CLEAN P -225 gpm @ 260 psi. WOB 1-5k. 60-100 RPm ~ 1-8k toque. PUW 100k /SOW 100k / ROTW 100k. DECOMP -Attem ted to free mill hitting down several times. No success. -Started jarring up. Jar C~ 50k over PUW and pull to 75-100k over PUW. DECOMP Continue jarring on pipe ~ 3,232' and (just inside the TOL). -Jar ~ 75k over PUW and pull to 100 over PUW. -Pipe came free. Pull above top of liner. DECOMP Re-enter liner and work mills through spot ~ 3,232' md. -Pull back above TOL. Run down again and verify spot clear. -Wash down to 3,343' md. DECOMP -Pull up to 3,155' and (above TOL). -No drag when pulling mills through area milled ~ 3,232' and - -CBU. 420 gpm / 850 psi DECOMP -RU to test casing. -Test 9-5/8" casing and 7" liner. -Test to 3500 six 30 min on chart. Pass. -RD testing equipment. DECOMP POOH w/ 4" DP f/ 3,155' to 411' and (BHA) DECOMP -Rack back DCs. -LD Junk baskets, upper Whipstock Mill and Tapered Mill. -No wear observed on Tapered Mill or upper Whipstock Mill. -Clean Junk baskets (+/- 1 Ib of metallic cuttings). DECOMP -MU new 6" Bit (w/ no jets) and Junk baskets. -Bit = 6", ATJ-4, Ser # 5150269 -RIH on 4-3/4" DCs to 401' md. DECOMP RIH w/ 6" Bit & Junk baskets f/ 401' to 7,794' md. DECOMP Obtain parameters: -PUW 173k, SOW 125k, ROT wt 145k, -RPM 60 ~ 5k Tq, 287 gpm / 900 psi. -Tag Cmt ~ 7,798' md. -Drill Cmt f/ 7,798' to 7,852' md. WOB 5-15k. DECOMP Drill Landing collar l~ 7,852' md. -Drill Cmt. Drill Float collar ~ 7,897' md. -Drill Cmt to 7,989' md. Ta Sand ~ 7,994' md. PUW 176k, SOW 125k, ROT wt 145k. -RPM 100 ~ 5k Tq. 300 gpm / 1130 psi. -WOB 20k DECOMP Dry drill 3' of Sand f/ 7,994' and t/ 7,997' md. -Kick on pumps & wash down to 8,004' md. - ump i is weep gpm psi. -Rotate & reciprocate w/ circulation. DECOMP POH w/ Cleanout BHA on 4" DP f/ 8,004' md. DECOMP Break off 6" Bit. Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Page 27 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: I Description of Operations Date From - To Hours ', Task Code NPT Phase 10/7/2008 20:00 - 21:00 1.00 CLEAN P DECOMP -Empty Junk baskets of Cmt & 1 Ot of metal shavings. -MU 7" Csg scraper & RCJB to 410' md. -RIH. 21:00 - 23:30 2.50 CLEAN P DECOMP RIH w/ RCJB on 4" DP f/ 410' to 7,797' and 23:30 - 00:00 0.50 CLEAN P DECOMP Wash down f/ 7,797' to 7,898' md. -PUW 175k, SOW 125k, 210 gpm / 750 psi. 10/8/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Continue to wash down f/ 7,898' to 8,004' md. -PUW 172k, SOW 125k, 210 gpm / 750 psi. -Wash & Rotate on sand to 8,014' md. 00:30 - 02:30 2.00 CLEAN P DECOMP Circulate. Pump Hi Vis Sweep surface to surface. -326 gpm / 2380 psi. -Drop Dart and open Pump out Sub. 02:30 - 05:00 2.50 CLEAN P DECOMP POH w/ RCJB BHA. -POH f/ 7,992' to 410' md. 05:00 - 05:30 0.50 CLEAN P DECOMP LD RCJB BHA: -Stand back Drill Collars. -Clean out Junk Baskets (4 small pieces of Metal 1 " X 1 ") 05:30 - 06:00 0.50 CLEAN P DECOMP Clean and clear Rig Floor: -LD vendor tools. 06:00 - 06:30 0.50 CLEAN P DECOMP Service rig: -Lubricate Rig. -Inspect Top Drive. 06:30 - 09:30 3.00 CLEAN P DECOMP MU BHA and RIH: -MU RBP retrieval Tool. -RIH w/ 4" DP to 7,974' md. 09:30 - 10:00 0.50 CLEAN P DECOMP Washover and latch onto RBP ~ 8,040' md. -Obtain parameters of PUW 165k, SOW 125k, 210 gpm, 600 psi. 10:00 - 11:00 1.00 CLEAN P DECOMP Circulate Hi Vis sweep surface to surface. -420 gpm = 2320 psi. -40 bbls Hi Vis seep ~ 63 YP. 11:00 - 12:00 1.00 CLEAN P DECOMP Unseat RBP. -Monitor well -Well static. -POH f/ 8,040' and to 6,100' md. 12:00 - 12:30 0.50 CLEAN P DECOMP Service rig: -Lubricate rig. -Inspect Top Drive. 12:30 - 15:00 2.50 CLEAN P DECOMP POH. -POH f/ 6,100' and to 410' md. 15:00 - 15:30 0.50 CLEAN P DECOMP LD RBP. -LD RBP retrieving tool. 15:30 - 16:30 1.00 CLEAN P DECOMP RU to test BOPE: -Pull wear ring. -Clean and clear rig floor. -RU test equipment. 16:30 - 22:30 6.00 BOPSU P DECOMP BOPE Test: -PJSM for testing BOPE's. -Begin testing BOPE's. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. Printed: 10/20/2008 12:29:13 PM • BP EXPLORATION Operations Summary Report iLegal Well Name: 18-05 Common Well Name: 18-05A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date I From.. - To Hours ~ Task Code NPT 10/8/2008 16:30 - 22:30 6.001 BOPSU 22:30 - 23:00 I 0.501 CLEAN I P 23:00 - 00:00 I 1.00 I CLEAN I P 10/9/2008 100:00 - 00:30 I 0.501 CLEAN I P 00:30 - 01:00 I 0.50 I CLEAN I P 01:00 - 07:00 6.00 CLEAN P 07:00 - 09:30 I 2.501 CLEAN I P 09:30 - 10:30 I 1.001 CLEAN I P 10:30 - 12:00 I 1.501 CLEAN I P 12:00 - 14:30 I 2.50 I CLEAN I P Start: 9/12/2008 Rig Release: 10/13/2008 Rig Number: Page 28 of 31 Spud Date: 4/21 /1986 End: 10/13/2008 Phase Description of Operations DECOMP -2 7/8" X 5" Variables. -Spacer spool C~3 18". Test BOP and related equipment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3,500 psi high x 5 min each on chart. -Test Hydril w/ 4" test jt. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test choke valve #7. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Top & bottom Rams w/ 4" test joint and 4-1/2" test jo -All tests area ass. Accumulator: -36 seconds for 200 psi increase. -2 minutes 46 seconds for full pressure. -Bottles 4 X 2200 psi. -Test witness waived by Jeff Jones AOGCC. DECOMP Clean and clear rig floor. -Install wear ring. DECOMP RU for next BHA. -MOB BHA to rig Floor. DECOMP RU and test 4" Dart valve -5 min ~ 250 psi low test. (pass) -5 min C~ 3500 psi high test. (pass) DECOMP Service rig: -Lubricate rig. -Inspect Top Drive. DECOMP MU next BHA: -3 5/8" mill. -Bit Sub. -Bumper sub and Jar. -XO, Pump out Sub. -(8) 3 1/8" Collars. -117 jts of 2 7/8" PAC DP. -XO's and 4 stds of 4 3/4" Drill collars. DECOMP RIH w/ 4" DP. -RIH with DP out of derrick to 9,727' md. DECOMP Obtain parameters as follows: -PUW 178k, SOW 130k, ROW 150k. -TO 5k ~ 50 RPM, 142 gpm / 2090 psi. -Wash and rotate into Tubing top ~ 9,777' md._ -Continue to wash down to 9,798' md. DECOMP Mill on sunk ~ 9,798' md. -128 gpm / 1360 psi. -170 gpm / 2510 psi. -3 to 8k WOB. DECOMP Mill on 'unk to 9,800' md. -50 rpm @ 5-8k torque. -200 gpm / 2600 psi. -PUW 175k, SOW 125k, ROW 150k. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 29 of 31 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 8-05 8-05A WORKO DOYON DOYON Hours VER DRILLIN 14 ' -Task INC ' Code . ~ NPT Start Rig Rig Phase Spud Date: 4/21/1986 : 9/12/2008 End: 10/13/2008 Release: 10/13/2008 Number: Description of Operations li 10/9/2008 12:00 - 14:30 2.50 CLEAN P DECOMP -While milling Junk: -Dis lace well from 9.8 NaCI to 8.5 Seawater. 14:30 - 16:30 2.00 CLEAN P DECOMP Wash Junk to to of Fasdrill Plug (~ 10,014' md. -50 rpm ~ 5-8k torque. -200 gpm / 2600 psi. -PUW 175k, SOW 125k, ROW 150k. 16:30 - 18:00 1.50 CLEAN P DECOMP Mill out Fasdrill Plug. -Torq. 5-8k, WOB 5-8k. -Pump rates: -105 gpm / 910 psi. Increase to 212 gpm / 2620 psi. -PUW 175k, SOW 125k, ROW 150k. 18:00 - 21:00 3.00 CLEAN P DECOMP RIH, push to 13,561' md. -Push Fasdrill & any Junk to 13,561' md. 21:00 - 22:00 1.00 CLEAN P DECOMP Pump a DP volume (128 bbls) plus (22 bbls) of seawater. -Monitor well for losses = 30 b h static. 22:00 - 00:00 2.00 CLEAN P DECOMP POH w/ 4" DP f/ 13,561' md. -POH Laying Down 4" DP. 10/10/2008 00:00 - 02:00 2.00 CLEAN P DECOMP POH w/ Milling assembly on 4" DP. -POH laying down 4" DP f/ 13,561' and to 9,100' md. 02:00 - 02:30 0.50 CLEAN P DECOMP Service Rig: -Lubricate Rig. -Inspect Top Drive. 02:30 - 05:30 3.00 CLEAN P DECOMP POH w/ 4" DP. -POH laying down 4" DP f/ 9,100' and to 4,230' md. 05:30 - 06:00 0.50 CLEAN P DECOMP RIH w/ 4" DP. -RIH w/ 4" DP out of Derrick to 4,900' md. 06:00 - 07:00 1.00 CLEAN P DECOMP POH w/ 4" DP. -POH laying down 4" DP. -POH laying down 4 3/4" DC's. 07:00 - 11:00 4.00 CLEAN P DECOMP POH w/ 2 7/8" PAC DP. -POH laying down PAC DP F/ 3,850' and to 230' md.. 11:00 - 12:00 1.00 CLEAN P DECOMP POH LD Milling BHA. -LD 3 1/8" DC's, POS, Jars. -LD Bumper Sub, Bit Sub, Mill Mill was heavily worn. Fluid Losses for Tour = 188 bbls of 8.5 ppg Seawater. 12:00 - 12:30 0.50 CLEAN P DECOMP Clean and clear rig Floor. -LD Vendor tools. 12:30 - 13:00 0.50 BUNCO RUNCMP RU to run Completion. -Pull Wear Ring. 13:00 - 14:30 1.50 BUNCO RUNCMP RU to run 4 1/2" Tubing Completion: -MOB Torque Turn Equipment to Rig Floor. -Change out Bales. 14:30 - 00:00 9.50 BUNCO RUNCMP RIH w/ 4 1/2" 12.6# 13CR Vam Top Tubing to 6,540' md. -Hold PJSM. -RIH w/ 4 1/2" 12.6# 13Cr Tubing per Tubing Detail: Used Jet Lube Seal Guard thead compound. Optimum make up torque = 4,440 ft-Ibs. Fluid Losses for Tour = 117 bbls of 8.5 ppg Seawater. 10/11/2008 00:00 - 02:00 2.00 BUNCO RUNCMP RIH w/ 4 1/2" 12.6# 13CR Vam Top Tubing f/ 6,540' to 7,320' Printed: 10/20/2008 12:29:13 PM • BP EXPLO'RATlON Page 30 of 31 Operations Summary Report Legal Well Name: 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/11/2008 00:00 - 02:00 2.00 BUNCO RUNCMP md. -RIH w/ 4 1/2" 12.6# 13Cr Tubing per Tubing Detail: Used Jet Lube Seal Guard thead compound. Optimum make up torque = 4,440 ft-Ibs. 02:00 - 02:30 0.50 BUNCO RUNCMP Service Rig: -Lubricate rig. Service Top Drive. 02:30 - 07:00 4.50 BUNCO RUNCMP RIH w/ 4 1/2" 12.6# 13CR Vam Top Tubing f/ 7,320' to 9,745' md. -RIH w/ 4 1/2" 12.6# 13Cr Tubing per Tubing Detail: 07:00 - 11:00 4.00 BUNCO RUNCMP Ta Tubin Stub C~3 9,778' md.e -Obtain following parameters: -PUW = 175k, SOW = 117k, 120 psi C~ 84 gpm. -Work over Tubing Stub ~ 9,778' to 9,792' md. -Noted pressure increase 30-40 psi as wash over Tubing Stub. -Noted possible indication of first set of Shears. -Washing over Tubing was Ratty. -Could not see indication of second of Shears or no go due to Hole conditions. 11:00 - 12:00 1.00 BUNCO RUNCMP Space out to land 4 1/2" Tubing. -PU 2 pup jts 4 1/2" tubing (9.90', 7.83'). For Space out. Losses for tour = 77 bbls 8.5 ppg seawater. 12:00 - 14:30 2.50 BUNCO RUNCMP PU FMC Tubing Hanger. -MU TCII Landing Jt, XO's. -Land Hanger. -PU 3' to circulate. 14:30 - 15:30 1.00 BUNCO RUNCMP Circulate at following parameters: -230 psi ~ 84 gpm. While waiting on Slick Line. 15:30 - 16:30 1.00 BUNCO RUNCMP RD circulation equipment. -MU XO's to 7" Otis connection. 16:30 - 20:00 3.50 BUNCO RUNCMP Spot Slick Line Unit. -PJSM. -MOB SWS tools to floor. -MU SWS with full pressure control. 20:00 - 00:00 4.00 BUNCO RUNCMP RIH with Slick Line: -RIH w/ RHC removal tool to 9,731' md. H. -Second run: -RIH w/ 3.80" Guage ring to 9,872' md. {Ensuring location of O- hot -POH. -Third run. -RIH and to RHC. Losses for tour = 46 bbls 8.5 ppg seawater. 10/12/2008 00:00 - 02:00 2.00 BUNCO RUNCMP RI wit lick ine: -RIH w/ RHC plug and set @ 9,731' md. 02:00 - 03:30 1.50 BUNCO RUNCMP RD is ine oo s: -RD Lubricator. 03:30 - 07:00 3.50 BUNCO RUNCMP Circulate in corrosion Inhibitor: -Pull Tubing hanger free C~ 180k PUW. Printed: 10/20/2008 12:29:13 PM BP EXPLORATION Page 31 of 31 Operations Summary Report Legal Well Name; 18-05 Common Well Name: 18-05A Spud Date: 4/21/1986 Event Name: WORKOVER Start: 9/12/2008 End: 10/13/2008 Contractor Name; DOYON DRILLING INC. Rig Release: 10/13/2008 Rig Name: DOYON 14 Rig Number: I ' Date ; From - To 'Hours Task Code NPT Phase Description of Operations 10/12/2008 03:30 - 07:00 3.50 - BUNCO RUNCMP -- - -PU 1' aboveTubing Stump C~ 9,778' md. -RU to circulate corrosion Inhibitor ~ 240 psi - 126 gpm. -Pump 150 bbls Seawater & 340 bbls of Inhibited Seawater. 07:00 - 07:30 0.50 BUNCO RUNCMP Land Tubing. -Dro Ball & Rod. ~ 07:30 - 09:30 2.00 BUNCO RUNCMP Set Pkr & Test 4 1/2" Tbg to 3500 psi_/ 30 minutes -Pass. 09:30 - 11:00 I 1.50 11:00 - 12:00 ~ 1.00 12:00 - 17:00 I 5.001 BOPSUp P 17:00 - 19:00 2.00 WHSUR P 19:00 - 20:30 1.50 WHSUR P 20:30 - 21:00 0.50 WHSUR P 21:00 - 22:30 1.50 WHSUR P 22:30 - 00:00 I 1.501 WHSUR I P 10/13/2008 00:00 - 00:30 0.50 WHSUR P 00:30 - 01:30 1.00 WHSUR P 01:30 - 02:00 0.50 WHSUR P 02:00 - 03:00 1.00 WHSUR P -Test IA to 3500 psi / 10 minutes -Pass. -Bleed off Tbg. Shear DCK shear valve. -Pump down Tbg 800 psi / 84 gpm. -Pump down IA 700 psi / 84 gpm. RUNCMP Suck out Stack. -FMC set TWC. Test from below 1000 psi / 10 minutes -Pass. -Test from above 3500 psi / 10 minutes -Pass. RUNCMP Blow down lines. Suck out Stack. -LD Mouse hole. -ND Flow line & Riser. Losses for tour = 46 bbls. RUNCMP PJSM. Nipple down Stack. -NU Tree. Test Adaptor flange to 5000 psi / 15 minutes -Pass. -Install Pump in flange. Sim-ops RD Top drive. -Slip on more Drlg line to lay down Derrick (40 wraps). RUNCMP Fill Tree w/ Diesel. -Test Tree to 5000 psi / 5 minutes -Pass. RUNCMP PJSM. Test Lubricator to 500 si / 5 minutes -Pass. -Pull TWC. -LD Lubricator on Rig floor. RUNCMP RU lines to Freeze protect. -RU Hot Oil. RUNCMP PJSM. -Pump 140 bbls of diesel to freeze protect. -84 gpm / 1500 psi. FCP 1200 psi. -RD Kelly hose & Mud manifold. RUNCMP Let well U-tube. -RD Rig floor. -Remove sheave for Mud bucket. RUNCMP After freeze protect by Hot Oil. -Suck out lines of diesel. RD hoses. RUNCMP DSM install BPV. -Test from below to 1000 si / 15 minutes -Pass. RUNCMP Suck out lines. RD Hot Oil. RUNCMP Remove double valve & 1502 flange. -Install Blank flanges on Tree. -Secure well. T/I/O = 0/0/0 Printed: 10/20/2008 12:29:13 PM 09/29/08 Sch[umbergcr Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jnh # S. ~F~~ ~A ~{~ ~m~~i l:~ w ~ ~`~ ~. a. boa. - ., ~ v. . I nn nncrrinfinn N0.4908 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n..~.. o~ 17-12 11978484 PRODUCTION PROFILE 09/19/08 1 1 P2-27 12017505 PRODUCTION PROFILE ~ _ 09/08/08 1 1 18-05A 11999048 FREE POINT INDICATOR LOG 09/16/08 1 1 E-36 12034922 SCMT 09/13/08 1 1 06-13A 12066547 MEM PROD PROFILE b(p- /C7 09/05/08 1 1 12-09 12083409 MEM DENSITY LOG ~ _ ( 09/06/08 1 1 13-14 11978482 PROD PROFILE ~~ - ~ 09/13/08 1 1 L-214A 11970843 INJECTION PROFILE a ~ C~~~ 09/05/08 1 1 L-210 12031511 INJECTION PROFILE 09/02/08 1 1 L-216 11970842 INJECTION PROFILE ~ 09/04/08 1 1 V-221 12034920 INJECTION PROFILE ~ 09/09/08 1 1 L-205L4 40016965 OH MWDlLWD EDIT 06/26/08 (2 PRINTS & 1 CD HAND DELIVERED SEPARATELY) ___..___.________._.._~_ ~. ............. ...... ...., v..,.n.v v...-vvr. ~na.n .v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~(,, 3 i s 'i, f ~)+,~~ 1 Alaska Data & Consulting Services 2525 Gambell Street, Sui 400 Anchorage, AK 9 03-2 8 ATTN: Beth Received by: _ • • !.~ SARAH PALIN, GOVERNOR .caaaCa-78~ Oaw ~ ~ 333 W. 7th AVENUE, SUITE 100 C011TSERQ~~'I011T COM>•II-rlSI011T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. ~,~.~ ~ ~ ~~~-~ PO Box 196612 ~~ ~ ~;~~ Anchorage, AK 99519-6612 ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-05A Sundry Number: 307-295 Dear Mr. Reem: 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. DATED this ~~ay of September, 2007 Encl. per, ~, Z -,.,, U'~ ~ STATE OF ALASKA • ~~7~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~a~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension "'•`~t%~I~t~~s ^ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska} Inc. ®Development ^ Exploratory 202-219 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21583-01-00 ` 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-05A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): - ADL 028307 - 46.45' ~ Prudhoe Bay Field / Prudhoe Bay Pool 72. > PRESENT 1NELL COND{TION SUM MARY Total Depth MD (ft): Total Depth TVD (ft}: Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured}: Junk (measured): 13656- 8765 ~ 13571 8762 None None asin en th Size MD TVD Burt Colla se Structural C nd ct r 110' 20" 110' 110' 1490 470 Surfac 2974' 13-3l8" 3008' 2838' 4930 2670 Intermediate 10232' 9-5/8" 10264' 8264' 6870 4760 ro uc ion Liner 3685' 7" 7919' - 11604' 6570' - 8631' 8160 7020 Liner 3791' 4-1/2" 9865' - 13656' 8063' - 8765' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12530' - 13560' 8761' - 8761' 4-1/2", 12.6# L-80 9885' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 9828' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O orations: October 7, 2007 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed Na David Reem Title Engineering Team Leader Prepared By NamelNumber Signature Phone 564-5743 Date Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~ Gl Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~ ©~ ~ t ~`~~ ~ -{-cam Subsequent Form Required: ~il.~ APPROVED BY i ~~~D A roved B ISSIONER THE COMMISSION Date f/ Form 10-403 Revised 06/2006 ~ i~'os~Af,± ~~ ,~.~~ ~ ~, 9lafl7 ORIGIN ~~ ~~ ~~~ ~ z~o~ l~ .~I~ ..":j ~ F' 2 4 200 20 AAC 25.280 ''A ;° :' ~?;` ~~ has Canso CrammissiUrt Submit I Duplicate ~/.~~~ • by GPc,~,iaa~ DS 18-O5A Rig Workover • Scope of Work: Pull 4'/z" L-80 completion, Run 7" scab liner from 3200' to 7920' and and cement. Run 4'h" 13Cr-80 completion. i MASP: 2400 psi ~ ,,,a, ~.~ i ~~ ` ~~~1 4~~ ~~~ Well Type: Ivishak Producer Estimated Start Date: October 7, 2007 ~~~a; ~~ SZ~~« rcC:~c~~~c ~-~~'~ Pre-riq prep work: - ~,~~ S 1 Set XX lu in ni le 9807' MD. Dum bail 10' of slu its on to of plu . F 2 MITT to 3500 si. MITOA to 2000 psi. W 3 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well should be secured at this time with an XX plu PPPOT-T & IC. DONE 09/21/07 E 4 String shot and chemical cut @ 9767' md, in the top of the first full joint above the production packer. Ref: 12/15/02 tubin tall F 5 Circulate well with seawater and then 9.8 ppg brine. FP w/ diesel thru the cut. Bleed WHP's to 0 psi. O 6 Set a BPV. Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE. Pressure test to 3500 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 2. Pull and LD 4 %2" tubing string to the cut. 3. Run and fully cement 7" scab liner from 3200' to 7920' and (will tie back into existing 7" scab liner via tieback seal stem). 4. Drill out shoe-track and PT casing to 3500 psi f/30-minutes. 5. Run 4-'/2" 13Cr-80 completion with 7" x 4'h" packer. 6. Displace the IA to packer fluid and set the packer. 7. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 8. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = FMC WELLHEAD = FMC ACTUATOR = AXFISON KB. ELEV = 46.5' BF. ELEV - 20.8' KOP = 1400' Max Angle _ 93 @ 12423' Datum MD = ~ N/A Datum ND = 8800' SS I 13-318" CSG, 68#, K-55 / 72#, L-80, ID = 12.347" Minimum ID = 3.725" @ 9873' 4-1/2" HES XN NIPPLE -0 5A SAFETY NOTES: 2191' -~ 4-1/2" BAL-O SVLN, ID = 3.812" GAS LIFT MANDRELS ST MD ND DEV NPE VLV LATCH PORT DATE 3 4246 3760 43 MMG-M DMY RK - 10/05/03 2 6926 5770 37 MMG-M DMY RK - 10/05/03 1 9419 7759 41 KBG2 DMY BK - 12!16102 7919' I--~ 9-5/8" X 7" BKR A LNR HGR 79~ BTM OF BKR TIEBACK EXTENSION ~ 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I-~ 9884' 9-518" CSG, 47#, L-80, ID = 8.681" ~ 10264' WHIPSTOCK 11622' PERFORATION SUMMARY REF LOG: MWD EWR-GR ON 12/06/02 ANGLE AT TOP PERF; 91 @ 1253D' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 12530 - 12670 O 12/15/02 2-1/2" 4 12770 - 13250 O 12!15(02 2-1/2" 4 13320 - 13560 O 12/15/02 7" LNR, 29#, L-80, ID = 6.184" --~ 1 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I-j 12965` 9807' 4-1/2" HES X NIP, ID = 3.813" 9828' 7" X 4-112" BKR S-3 PKR ID = 3.875" 9852` 4-112" HES X NIP, ID = 3.813" 9873' 4-1/2" HES XN NIP, ID = 3.725" 9885` 4-1/2" WLEG, ID = 3.958" 9865` 7" X 5" BKR ZXP LNR TOP PKR 9926' 9-5/8" X 7-5/8" BKR A LNR HGR 9935` 7" BKR TIEBACK SEAL ASSY MILLOIlT WINDOW 11604' - 11621' 11694' I-1 MARKERJOINT PBTD 13571' 1 /2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 13656' DATE REV BY COMMENTS DATE COMMENTS 07/09/86 ORIGINAL COMPLETION 05/29/06 DFR/DTM CSG CORRECTIONS (11/24/04) 12/16/02 DDW/KK RIG SIgETRACK(18-05A) 12/20/02 DTR/KK GLV GO 06/13/03 CMO/TLP KB ELEVATION CORRECTION 09!13(03 CMOITLP DATUM MDlTVD & PERF ANGL 10/05/03 JCM/TLP GLV GO PRUDHOE BAY UNIT WELL: 18-05A PERMfT No: F2022190 API No: 50-029-21583-01 SEC 24, T11 N, R14E, 952' FNL & 221' FEL BP Exploration (Alaska) FMC 'UP,TOR = AXELSON 18 -0 5A Propose d ELEV = 46.5' ELEV = 20.8' ' = 1400' Angle = 93 ~ 12423' im MD = N1A im ND = 88011' SS 13-3/8" CSG, 68#, K-55 / 72#, L-80, ID = 12.34T' ~-~ 7" X 95/8" ZXP LINER HANGER Minimum ID = 3.725" ~ 9873' 4-1/2" HES XN NIPPLE T' SCAB LNR, 26#, L-80 ID = 6.27E' BAKER TIEBACK STEM BTM OF BKR TIEBACK EXTENSION 7919' I 7" x 4 12" G Unique Overshot 41/2" TBG, 12.6#, L-80, .0152 bpf, ~ = 3.958" I--I 9884' 9-5l8" CSG, 47#, L-80, ID = 8.681" ~ 10264' WHIPSTOCK 11622' PERFORATION SUMMARY REF LOG: MWD EWR GR ON 12/06102 ANGLEAT TOP PERF: 91 ~ 12530' Note: Refer to Productan DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-1 /2" 4 125 - 12670 O 12/15J02 2-1/2" 4 12770-13250 O 12115/02 2-12" 4 13320 - 13560 O 12/15/02 { T' LNR, 29#, L-80, ID = 8.184" { 41/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 12965' NOTES: I 4-12" HES X NIP, ~ = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3216 3000 43 KBG2 DCK BK - 3 5808 4900 37 KBG2 DMY BK 2 7774 6450 41 KBG2 DMY BK - 1 9542 7850 41 KBG2 DMY BK -' H 9807' 4112" HES X NIP, ID = 3.813" 7" X 412" BKR S-3 PKR ID = 3.875 41/2" HES X NIP, ID = 3.813" 41/2" HES X NIP, ID = 3.813" 9828' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9852' 41 /7' HES X NIP, ID = 3.813" 9873' 4-12" HES XN NIP, ID = 3.725" 9885' 41/2" WLEG, ID = 3.958" 9865' 7" X 5" BKR ZXP LNR TOP PKR 9926' 9-5/8" X 7-5/8" BKR A LNR HGR 9935' 7" BKR TIEBACK SEAL ASSY MILLOUT WINDOW 11604' - 11621' 11694' H MARKERJOINT ~('~ PBTD 13571' /2/ LNR, 12.6# L-80, .0152 b f, ID = 3.958" 1 656' DATE REV BY COMMENTS DIATE COMMENTS 07109!88 ORIdNAL COMPLETION 0529106 DFR/DTM CSG CORRECTIONS (11124104) 12N6102 DDWtIdC RIG SIDETRACK(18-OSA) 1220/ DTRIKK GLV GO 06/13/03 CMOlRP KB ELEVATION CORRECTION 09/13/03 CMOlRP DATUM MD/TVD & PERF ANGL 10/05/03 JCMITLP GLV GO PRUDHOE BAY UNIT WELL: 18-05A PERMIT No:'Z022190 API No: 50-029-21583-01 SEC 24, T11 N, R14E, 952' FNL &221' FEL BP 6cploration (Alaska) . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _In.serts\Microfilm _ Marker.doc Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well . MPI-09 MPI-09.ÁÙ(J -(\:.,)] ___ ,~~~~~~¡-: 01:L1 NK-08A 18-34 . G\S-" it, 11 04-05A í ('¡3 w 13 ~~ 18-05A '1(. ~ - 2. t C{ 07-36 ; q"7 - ( ~ C{ 14-36 IF J - - I (3 C-13A Ie¡ 7 - ì'1) U-12 185--1 j...l... R-21 i S3 -. Il.·t R-12 í93-· OJ)'" E-16 /sa - c, J J-23 I 8 7... 9 J , F-31 I..~ ~ - 15"7 H-35 I (j ') .... J 4 q Job# 10563225 10980572 10772241 10560316 10703956 10564525 10703939 10563112 10866557 10564527 11075900 10674388 10687647 10564529 10663003 10703943 10563217 10563216 Log Description INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PSP GLS PPROF W/DEFT PSP LDL PRODUCTION PROFILE LEAK DETECTION LOG LEAK DETECTION LOG INJECTION PROFILE MEM PROD & INJECTION PROFILE LDL PRODUCTION PROFILE PSP PPROF W/GHOST/DEFT PRODUCTION PROFILE SBHP SURVEY SBHP SURVEY PPROF W/GHOST PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ) ( c.~).V Vu \/) ì t<\" .- v\v(,'(") " SCANr~ED SEP Ü Date 10/05/03 06/09/05 04/04/04 10/22/03 11/27/03 09/27/03 10/24/03 10/13/03 07/14/04 09/29103 07/05/05 10/27/07 09/20/03 10/01/03 03/10/04 10/28/03 09/28/03 09/27/03 Q ?o íl!-~ Db Uti 07/20105 NO. 3438 ~ð ~-9,Jq Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD -...-' ~. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ...1 }' J '\k if ! ! ! . ("\ /í ¡ Received by: lfí~ ~- L) v~" ) ') ;{o~ .-:2// WELL LOG TRANSM1TTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 25, 2004 RE:MWD Formation Evaluation Logs: 18-05A, AK-MW-22191 18-05A: Digital Log Images: 50-029-21583-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF TIlE 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: ip~ li/ !rL /....-- 1/ I ¡ / / . / S~~d: ~/';: Cl~ "'..: '¡.: '\~i'-"", f\ r' ¡'1' ", : 'Jont:: ;,)l/d~Nr~t:J, t-, r' ¡( .!c. ~,L J v,j {Co J~ ~r- DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 5 {? ud- I (j /J ~ ,{ ð úÀ API No. 50-029-21583-01-00 Permit to Drill 2022190 Well Name/No. PRUDHOE BAY UNIT 18-05A Operator BP EXPLORATION (ALASKA) INC MD 13656/ --~~._~-~--_._------~- ---~-'---"------ TVD 8765 / Completion Date 12/16/2002 ./ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No DATA INFORMATION -------~--_._~._._-- --~._----~----------_._~-----~~--- Types Electric or Other Logs Run: Well Log Information: MWD, DIR, GR, RES,EDN, NEU (data taken from Logs Portion of Master Well Data Maint) Electr Dataset Number Name v-6irectional Survey t/(ÍS Verification ¿A'1689 LIS Verification .,/Directional Survey Log/ Data Digital Typ,e Med/Frmt -~-------- ~- £0 ~~--- . Well Cores/Samples Information: .~ Interval OH / Start Stop CH 11537 13656 Open 11600 13598 Open 11600 13598 Open 11537 13656 Open Log Log Run Scale Media No 1 Received Comments 1/3/2003 4/17/2003 ~) a... £, \JJ y\ Y c:r\fI fi S t--. ~ yZ 13 Y' 4/17/2003 1/3/2003 MWD Name Interval Start Stop Sample Set Number Comments Sent Received Well Cored? ADDITIONAL INFORMATION y~ Daily History Received? ~.!/N C!JN ^-~ Chips Received? .-"r'"t"N-' Analysis Received? Formation Tops 'f-H.J- Comments: -.~~_._-~---------------._----~--~-- c¿mJt' ~J. ~e IUIIJ ~¿,~. ~~' J;Jh Ä ð/{ /~ - --.-----_.__.__._.__._--------~ ----- ,~" ;(lD ~)~.. ~~- Compliance Reviewed By: Date: ) STATE OF ALASKA ) DEC.. .E... ~\ .<~~,' ALASKA OIL AND GAS CONSERVATION COMMISSIOf\1'- ,..' I'~ REPORT OF SUNDRY WELL OPERATIONSo72004. 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Suspend D Repair Well ŒJ Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate I&iÞska Oil iJßö Cþns. (,tw,¡i..OtherD Stimulate D Time Exte~age Re-enter Suspended Well 0 5. Permit to Drill Number: 202-2190 Name: BP Exploration (Alaska), Inc. Development I]] 46.45 8. Property Designation: ADL-0028307 11. Present Well Condition Summary: StratigraphicD 9. Well Name and Number: 18-05A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service D 6. API Number 50-029-21583-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 13656 feet measured 13571 feet true vertical 8761.6 feet Plugs (measured) Junk (measured) None true vertical 8764.6 feet Effective Depth None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 32 112 32.0 112.0 1490 470 Liner 3685 7" 29# L-80 7919 - 11604 6569.6 - 8630.6 8160 7020 Liner 3789 4-1/2" 12.6# L-80 9865 - 13654 8062.8 - 8764.5 8430 7500 Production 10232 9-5/8" 47# L-80 29 - 10261 29.0 - 8262.9 6870 4760 Surface 32 13-3/8" 72# J-55 31 63 31.0 63.0 3700 2230 Surface 2942 13-3/8" 72# L-80 63 - 3005 63.0 - 2836.0 4930 2670 Perforation deDth: Measured depth: 12530 - 12670, 12770 - 13250, 13320 - 13560 True vertical depth: 8760.53 - 8759.49,8758.39 - 8750.07,8752.08 - 8761.25 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 24 9885 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer @ 9828 @ 9865 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 26 14 128 13 Well Shut-In 32 Tubing Pressure 1867 588 Prior to well operation: Subsequent to operation: Oil-Bbl 721 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ) Service 0 Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown D Oil I]] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations - ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron .!d~ r~ Form 1 0-404 Revised 12/2003 Title Production Technical Assistant Signature Phone 564-4657 Date 6/4/04 OklGINAL 188Bfl JUN08 '""",¡; -) ) 18-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/18/04 FREEZE PROTECT IA WI 5 BBLS NEAT. (POST MARC IT GEL) 04/18/04 TIO=NA/128/0 PERFORM IA MARC IT GEL SQUEEZE. PUMP 280 BBLS MARC IT GEL INTO PC LEAK @ 63101 AND PLACE 338 BBLS MARC IT GEL IN INNER ANNULUS. WELL LEFT SHUT IN. PAD OPERATOR NOTIFIED. 04/23/04 TIIIO = SSV/60/40. LNFT - IA INCONCLUSIVE. MIT - OA TO 3000 PSI PASSED. (EVAL FOR PC LEAK WAIVER). IA FL @ SURFACE. BLED IA FROM 60 PSI TO 10 PSI IN 45 MIN. BLED APPROX 5 BBLS OF METHANOL. MARC IT GEL TO SURFACE. PLUGGED OFF BLEED HOSE AND IA PRESSURE INCREASED TO 45 PSI. COULD NOT BLEED. MONITORED lAP FOR 30 MIN. lAP DROPPED TO 32 PSI. MONITORED FOR AN ADDITIONAL 1 HR AND lAP REMAINED AT 32 PSI. MIT - OA TO 3000 PSI PASSED. OA FL @ 601. PRESSURED OA TO 3000 PSI WITH 7 BBLS OF DIESEL. STARTED 30 MIN TEST. OA LOST 50 PSI IN THE 1 ST 15 MIN AND 10 PSI IN THE 2ND 15 MIN FOR A TOTAL LOSS OF 60 PSI. BLED OA TO 40 PSI. FINAL WHp1S = S1/32/40. 04/23/04 TIIIO = SSV/60/40. LNFT - IA INCONCLUSIVE. MIT - OA TO 3000 PSI PASSED. (EVAL FOR PC LEAK WAIVER). IA FL @ SURFACE. BLED IA FROM 60 PSI TO 10 PSI IN 45 MIN. BLED APPROX 5 BBLS OF METHANOL. MARC IT GEL TO SURFACE. PLUGGED OFF BLEED HOSE AND IA PRESSURE INCREASED TO 45 PSI. COULD NOT BLEED. MONITORED lAP FOR 30 MIN. lAP DROPPED TO 32 PSI. MONITORED FOR AN ADDITIONAL 1 HR AND lAP REMAINED AT 32 PSI. MIT - OA TO 3000 PSI PASSED. OA FL @ 601. PRESSURED OA TO 3000 PSI WITH 7 BBLS OF DIESEL. STARTED 30 MIN TEST. OA LOST 50 PSI IN THE 1ST 15 MIN AND 10 PSI IN THE 2ND 15 MIN FOR A TOTAL LOSS OF 60 PSI. BLED OA TO 40 PSI. FINAL WHP'S = S1/32/40. FLUIDS PUMPED BBLS 580 1160 609 5 7 2361 9.8# Brine Gals 50/50 Polymer/Diesel Marcit Gel Neat Methonal Diesel TOTAL Page 1 ') TRæ = FMC WELLHEA D = FMC Ä cWÄro,f;' m umÄxËij§oÑ K-I3.'"ÈL ÈV.;_"^~~^mVNNv~~'~46^]' BF~I~[EV^;;m~'."^mN^m___'N2(r:î:f 'Kop-;---,----_v--'-1400' Max"Ãnglë^;"H"^^§á'(@^"f2'42'f 'õäTûiìî"M5^;^^^--'^^^"_M""_^"ÑÎà """"","""'"""^~",,'..'~~..m"""''''''''''''''''^''';Y^"'"'',,,".....'h..h..,,-......^.," Datum lV D = 8800' SS 18-05A I 13-318" CSG, 72#, L-80, ID = 12.34 7" H 3008' ~ Minimum ID = 3.725" @ 9873' 4-1/2" HES XN NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID =3.958" 1--1 9884' 1 9-518" CSG, 47#, L-80, ID = 8.681" H 10264' J-----AI 1 WHIPSTOCK H 11622' 1 ÆRFORA llON SUv1MARY REF LOG: MWD BNR-GR ON 12/06/02 A NGLE AT TOP ÆRF: 91 @ 12530' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 12530-12670 0 12/15/02 2-1/2" 4 12770 - 13250 0 12/15/02 2-1/2" 4 13320 - 13560 0 12/15/02 17" LNR 29#, L-80, ID = 6.184" H 12500' 1 14-1/2" LNR 12.6#, L-80, .0152 bpf ,ID = 3.958" H 12965' 1 DATE 07/09/86 . 12/16/02 12/20/02 06/13/03 09/13/03 10/05/03 COMI'vENTS ORIGINAL COMPLETION IDW/KK RIG SIDETRACK (18-OSA) DTRlKK Gl V C/O 0v10ITLP KB B..EV A llON CORRECllON Ov101TLP [)A. TLM tvI)!TV D & PERF ANGl~ JCM'TLP GL V C/O REV BY [)A. TE . I 2191' 1-1 4-1/2" BAL-O SVLN,ID = 3.812" 1 ~ GAS LIFT tv1ANDRB..S ST MD TVD DEV lYÆ VLV LATCH FORT DATE 3 4246 3760 43 1'vfv1G- M DMY RK - 10/05/03 2 6926 5770 37 MV1G- M DMY RK - 10/05/03 1 9419 7759 41 KBG2 DMY BK - 12/16/02 ;m I 7919' H 9-5/8" X 7" BKR A LNR I-K3R 1 7932' H BTM OF BKR llEBAa< EXTf3\JSON 1 I 9807 H 4-1/2" I-ES X NIP, ID = 3.813" 1 1 9828' H 7" X 4-1/2" BKR &3 A<R ID = 3.875" 1 1 9852' H 4-1/2" I-ES X NIP, ID = 3.813" 1 I 9873' H 4-1/2" res XN NIP, ID = 3.725" 1 1 9885' H 4-1/2" WLEG, ID = 3.958" 1 1 9865' H 7" X 5" BKR ZXP LNR TOP A<R I 121--1 9926' H 9-5/8" X 7-5/8" BKR A LNR I-K3R I 1 9935' H 7" BKR TIEBA a< SEAL ASSY I ~ X ~w~ IZ A L U) I SAFETY NOTES: ~ MLLOUTWINDOW 11604'-11621' I 11694' H tv1A RKER JOINT I ~ ~ IPBTD H 13571' [4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID=3.958"H 13656' I COMV1f3\JTS ffiuœOE SA Y UNT WB..L: 18-05A ÆRMIT No: 2022190 API No: 50-029-21583-01 SEC24, T11N, R14E, 952' FNL & 221' FB.. 8P Exploration (Alaska) ) AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION Maureen Johnson Greater Prudhoe Bay Perfonnance Unit Leader PO Box 196612 Anchorage, AK 99519 February 3, 2004 Notice of Violation Prudhoe Bay Drill Site 18, Well. 18-05 It ~O ~_. :¡ ~ Dear Ms. Johnson: Re: ) FRANK H. MURKOWSKI, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 This letter is to infonn you that the BP Exploration (Alaska). Inc. response on January 12, 2004 adequately addresses the Alaska Oil and Gas Conservation Commission's ("Commission") concerns regarding the discovery of the defeated surface safety valve (SSV) on the ab ve mentioned well. The Commission will take no further action on this matter. Ó au Sincerely, ~ Daniel T. Seamount, Jr. Commissioner j, ~.-< BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519~6612 (907) 561-5111 January 12, 2004 RECEIVED Ms. Sarah Palin, Chair State of Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Ak 99501-9539 JAN 1 4 2004 A811118'88ra - .. I .lad ~ I RE: Notice of Violation Dated December 22, 2003 (Prudhoe Bay Drill Site 18, Well 18-05) Dear Ms. Palin BP Exploration (Alaska) Inc. (BPXA) provides the following information in response to the Alaska Oil and Gas Conservation Commission's Notice of Violation (NOV) dated December 22, 2003 regarding the discovery of the defeated surface safety valve (SSV) on Well 18-05A. Pursuant to the NOV, BPXA herein explains how this event happened and what BPXA will do in the future to prevent its occurrence in BPXA operated fields. What happened: Based upon our investigation, it appears that on December 5, 2003, the BPXA operator was performing routine inspection and maintenance work, as well as clearing snow from well houses that accumulated during recent severe weather. During this work, the operator closed the valve for the SSV hydraulic line as part a procedure to check the pilot. Then, in accordance with accepted procedures, the operator "flagged" the closed valve by tying a piece of fluorescent ribbon on the handle to indicate that it was not in its normal position. The "flagging" of a valve is to remind the operator that the valve is not in its normal position and must be returned to its normal position at the completion of the work and before the operator leaves the immediate location. In this case, the operator completed his work but inadvertently left the valve flagged and in the closed position. When questioned about this later, the operator admitted that he was fully aware of the importance and necessity of re-opening the valve but simply forgot to do so. Preventative Actions: As noted in your letter, there were other occurrences of defeated SSVs on BPXA's operated fields last year. It is beneficial to view our preventative ~ . Ms. Sarah Palin, Chair January 12, 2004 Page 2 ') . actions within the larger context of the ongoing actions that we've taken to prevent these events from re-occurring. Follow up action plans from a prior NOV last summer included 3 actions (detailed in our letter of July 24, 2003); . Complete toolbox training to all BP XA -operated field workforces to ensure that they understand the importance of following procedures designed to facilitate SVS integrity. Status - All team leaders and operators have been fully trained on proper SSV procedures either through toolbox or team leader sessions. BPXA' s expectations regarding the importance of adhering to these procedures have been thoroughly reinforced and are explicitly detailed in Greater Prudhoe Bay's P- Pilots, SSSV sand SSV s Procedure. . Initiate an MPU Field Operations Well Pad Procedures Review Group to determine whether changes to written procedures or whether additional procedures are required to avoid the same or other SVS failures. Status- Completed. All procedures relevant to SVS operation were reviewed but no changes were made as the procedures contained the appropriate instructions and expectations regarding SVS operation. . Coordinate response to the Group's findings with other BP XA -operated fields to ensure consistency of approach across BPXA-operated assets. Status- Completed. We have concluded that the root cause of the failure in this specific case is behavioral and not procedural, mechanical or training related. In this instance, we have determined that - disciplinary action for the operator involved is the appropriate response. We believe that administration of disciplinary action will most effectively reinforce BPXA's expectations to employees and prevent reoccurrence of similar events in the future. This emphasis on accountability is clearly stated in our P-Pilot, SSSVs and SSVs Procedure, where it states "the consequences of failing to follow appropriate procedures could result in disciplinary action ". Our immediate action plan to prevent re-occurrence is; . Administer appropriate disciplinary action for the operator involved in the incident. Completed. . Confirm that all SVS valves are currently in the proper position for all wells currently on production and reinforce with the Prudhoe Bay workforce the requirement to verify the proper operation of the SVS' s on a daily basis. This exercise was completed on 1/12/04 and confirmed that all valves were properly positioned. . In accordance with Prudhoe Bay policy, Operations Team Leaders are performing periodic audits of the SVS to ensure proper operation. We intend to conduct additional audits by team leaders over the next quarter to provide continued assurance of our compliance on this issue. Ms. Sarah Palili, Chair) January 12, 2004 Page 3 Should you have any questions regarding this letter or require additional information, please call me at 564-5671 or Bruce Williams at 564-4632. Maureen J 0 on Greater Prudhoe Bay Performance Unit Leader ) ) STIPULATION FOR EXTENSION OF TIME STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Re: Notice of Violation re Surface Safety Valve Prudhoe Bay Unit Well 18-05A By a letter dated December 22, 2003, the Alaska Oil and Gas Conservation Commission (Commission) notified BP Exploration (Alaska) Inc. (BP) that a routine inspection had disclosed that the surface safety valve (SSV) on Prudhoe Bay Unit Well 18-05A had been defeated some time prior to the inspection. BP was given 14 days from the date of receipt of the letter in which to provide the Commission with an explanation. Due to intervening holidays, BP requested and is granted an extension of time in which to respond to the letter until January 16, 2004. . æ~QI~~ ~~~g Attorney BP Exploration (Alaska) Inc. ALAS::ll- AND.,.G.~~lCO:;RVATION CO~.f;~~...)ION~.Z/. ß;~#. ,/ ~-----~ ,/ I . I / . Jí\/ 'I r/ / ~¡t,cbL./t--~'\-4i". C~<,~- '- . . {Sarah Palin/ ( ) Daniel T. Seamount, Jr. ''C~ \, ) Commissioner January 8, 2004 . t} -,. ) ) . ... ... c~rrJ ¡~'\ C¡"'fJ rT~> (r'YI .I-[~ (¡l\\. n íJ\\.. ((~} f¡"t7 .~\'\ l! ! t \ \ I! .:~) I! ¡ ri II \ \ I I I ¡ \'-, '\ t \ l '. I' t ~-"'- '¡ ! ¡ r '\ l..! ¡ ¡ / '::, \ :L' \ 1, ..:::'; \ r~')) ¡ 1\ \ ! r'~::, \ ~ j Lr\j LJ L~:'j \,~.:.,) U L) \J ~:.J j lJ ¡~..... U \j L \.) FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION December 22, 2003 333 W. -,rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 CERTIFIED MAIL - RETURN RECEIPT REQUESTED 70023150000535211164 Ms. Maureen Johnson BP Exploration Alaska, Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Subject: Notice of Violation Dear Ms. Johnson: On December 6, 2003, Alaska Oil and Gas Conservation COlnmission ("Commission") Inspector Jeff Jones, accompanied by a BPXA representative, perfonned safety valve system (SVS) inspections at Prudhoe Bay Drill Site 18. Mr. Jones noted that the surface safety valve (SSV) on Well 18-05A had been defeated some time prior to the inspection - the hydraulic line was blocked, preventing the SSV from operating with a low-pressure pilot trip or emergency shutdown of the SVS. A copy of his inspection report is attached. You are reminded that Conservation Order 363 (Prudhoe Bay Oil Pool), Rule 5 modifies the requirements of 20 AAC 25.265 ("Automatic Shut-in Equipment") as follows: (a) Each well shall be equipped with a Commission approved fail-safe automatic surface safety valve s}'stem (SVS) capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an over pressure of equipment may occur. (b) The safety valve system (SVS) shall not be deactivated except during repairs, while engaged in active well work, or if the pad is manned. If the SVS cannot be returned to service within 24 hours, the well must be shut in at the wellhead and at the manifold building. J. Wells with a deactivated SVS shall be identified by a sign on the wellhead stating that the SVS has been deactivated and the date it was deactivated. 2. A list of wells with the SVS deactivated, the dates and reasons for deactivating, and the estimated re-activation dates must be maintained current and available for Commission inspection on request. CO 363 replaced the requirements of earlier CO 341 (Prudhoe Bay Oil Pool) field rules by providing for the elimination of subsurface safety valves (SSSV) in certain wells. The eliInination of the SSSV in Prudhoe Bay wells increases the reliance on the surface safety Ms. 'Maureen Johnson J December 22, 2003 Page 2 of2 ) ) equipment. The Commission is concerned with the recent increased numbers of defeated safety valve systems discovered during routine inspections on the North Slope. Failure to maintain an operable SVS is a violation of State regulations. Within 14 days of receipt of this letter, you must provide the Commission with an explanation of how this event happened and what will be done in the future to prevent its OCCUlTence in BPXA-operated fields. Should you have any questions regarding this correspondence, please contact Mr. James Regg at (907) 793-1236. Sincerel~) /'/::1"&7 < <:::: ,. L/ / .~ i /- , ,.,.---~ .,' --- . {....---"" .' I (,..,._/' . ! -.,...-,.-.-'" . 1~ Sarah Palin \J Chair Attachment - ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPXA Submitted By: Jeff Jones Date: 12/6/2003 Operator Rep: Bill Palmer FieldlUnitlPad: PBF / PBU / 18 AOGCC Rep: Jeff Jones Separator psi: LPsl 1601 HPsl 6811 Well Data . : Pilots:. . SSV. SSSV Test/RetestlSJ Date Weli Type. Well Permit Separ Set L/P Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI 18-01 A 1960100 18-03B 2030860 160 150 150 43 4 P S/I 12/6/03 OIL 18-05A 2022190 681 600 570 P 5 Passed R/T 12/6/03 OIL 18-06A 1972470 681 600 540 P P OIL 18-1 OB 2020350 681 600 550 P P P OIL 18-11 D 1870870 160 200 180 P 4 P Passed RJT 12/6/03 OIL 18-16B 1970990 160 200 180 P P OIL 18-1 7 1871200 681 600 220 3 P P Passed R/T 12/6/03 OIL 18-18B 2021210 OIL 18~20 1881410 681 600 510 P P P OIL 18-21A 1961980 681 600 520 P P P OIL 18-24A 1950330 160 150 150 43 P P Passed R/T 12/6/03 OIL 18-27C 2001540 681 600 460 43 P P Passed R/T 12/6/03 OIL 18-30 1950910 681 600 460 P P P OIL L2-03A 1980620 OIL L2-07 1981650 OIL Wells: 12 Components: 33 Failures: 7 F ailu14e Rate: 21.21°/E] 90 Day Remarks: 18-03B pilot setting low (1596 FTP) & SSV failed pressure test; well S/I for repair. 18-05A SSV failed to close, hydraulic line to SSV blocked; unblocked & passed retest. 18-11D SSV failed pressure test; serviced & passed retest. 18-17, 18-24(948 FTP), 18-27C( 1061 FTP) pilots tripped low; replaced & passed retest. RJF 09/19/01 P:H7p, 1 of 1 ?001-1 JOt; ~v~ PRTT n~ 1 R 11 Y 1 C' '1¡ } ) ¿;¡Od-aJt] 1/ to 19 WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 1 0, 2003 RE: MWD Formation Evaluation Logs 18-05A, AK-MW-22191 1 LDWG formatted Disc with verification listing. API#: 50-029-21583-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2- I 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ~~.fJ Si~Ä&~ RECEIVED APR 1 7 2003 Alaska Oti & Gas Cons. Commlssion Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ') 1. Status of Well Ii Oil D Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 951' SNL, 221' WEL, SEC. 24, T11N, R14E, UM At top of productive interval 4224' SNL, 1247' WEL, SEC. 23, T11N, R14E, UM At total depth 4518' SNL, 2900' WEL, SEC. 23, T11 N, R14E, UM x = 683674, Y = 5957147 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 46.45' ADL 028307 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 12/10/2002 . 12/12/2002 ,) 12/16/2002 ' 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13656 8765 FT 13571 8762 FT Ii Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, DEN, NEU Classification of Service Well ~".. I. '.;:..,' -.I."-.'è"-..'.'.¡...'-.'tf'~. '\ '~'. ,t;. ."'.f...'. ~"::~::. .'."':¡'.';n.~"~....""'.:.i....,.' :rl: .,~¡ ~ ;5;U. . - ...,'. '" Ìì: iL~ ~ . !iff ! ~.,1[ "~,~:' 'Ii,(,.. 'r" . .,,' ~''':"):''~''::'~""~~,:'~':'1ki>:t',,,t:,~:'';.':<"\~)::t x = 691539, Y = 5960912 7. Permit Number 202-219 8. API Number 50- 029-21583-01 9. Unit or Lease Name Prudhoe Bay Unit x = 685319, Y = 5957481 10. Well Number 18-0SA 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2191' MD 1900' (Approx.) 1/~~~ I/~o'-l /nþ &' Go 3<::> TV':b 23. CASING SIZE 20" 13-3/8" 9-5/8" 7" WT. PER FT. 91.5# 72# 47# 29# 12.6# GRADE H-40 L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 30" 2156# Poleset 34' 3008' 17-1/2" 3000 sx CS III, 400 sx Class 'G' 32' 10264' 12-1/4" 500 sx Class 'G' 7919' 11604' 8-1/2" 970 sx Class 'G' 9865' 13656' 6" 259 sx Class 'G' AMOUNT PULLED 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf MD TVD 12530' - 12670' 8761' - 8759' 12770' - 13250' 8758' - 8751' 13320' - 13560' 8752' - 8761' 25. SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 9885' PACKER SET (MD) 9828' MD TVD 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 23, 2002 Flowing . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF 1/18/2003 6 TEST PERIOD 1608 22066 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF Press. 439 24-HoUR RATE WATER-BBL -0- WATER-BBL CHOKE SIZE 45° OIL GRAVITY-API (CORR) GAS-OIL RATIO 13720 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Ch~.:, No core samples were taken. (1Y Form 10-407 Rev. 07-01-80 RBDMS BFl 28 Submit In Duplicate ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 2 11696' 8654' Zone 1 B 11955' 8716' Zone 1 A 12170' 8753' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ . ~ Title Technical Assistant Date 0 l . ~ L( , 0 "3 18-05A 202-219 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Dave Wesley, 564-5773 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 (OF, 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 Legal Name: 18-05 Common Name: 18-05A Test Date 11/30/2002 12/8/2002 0 FIT Test Type Test Depth (TMD) (ft) 11,630.0 (ft) BP EXPLORATION Lcàéíl<~Gff"~$t....~Ur:l1rnary Test Depth (TVD) (ft) 8,630.0 (ft) AMW (ppg) 8.60 (ppg) Page 1 of 1 Surface Pressure (psi) 629 (psi) Leak Off Pressure (BHP) (psi) 4,484 (psi) EMW 11.00 (ppg) 10.00 (ppg) -/ Printed: 12/26/2002 10:13:37 AM ) ') BPE~PI...ORATION (]). ~l~t~~i()~~$>l.Iï1nl'l1êÎrý~~PQI:1: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-05 18-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/2/2002 Rig Release: 12/16/2002 Rig Number: 2ES Spud Date: 4/21/1986 End: 12/16/2002 Date FrÖIl1"iTo Hours Task' Codè NPT' .lJêsq "jþtiOriöf()þ~råtions 11/30/2002 13:00 - 00:00 11.00 MOB P PRE 12/1/2002 00:00 - 01 :00 01 :00 - 22:30 1.00 MOB 21.50 MOB P N PRE WAIT PRE 22:30 - 00:00 1.50 MOB P PRE 12/2/2002 00:00 - 02:00 2.00 MOB P PRE 02:00 - 03:00 1.00 MOB P PRE 03:00 - 04:30 1.50 MOB P PRE 04:30 - 06:00 1.50 RIGU P PRE 06:00 - 13:00 7.00 RIGU P PRE 13:00 - 15:00 2.00 BOPSURP PRE 15:00 - 17:00 2.00 BOPSUR P PRE 17:00 -17:30 0.50 BOPSUR P PRE 17:30 - 21 :00 3.50 BOPSUR P PRE 21 :00 - 21 :30 0.50 BOPSURP PRE 21 :30 - 22:00 0.50 BOPSUR P DECOMP 22:00 - 23:00 1.00 BOPSUR P DECOMP 23:00 - 00:00 1.00 BOPSUR P DECOMP 12/3/2002 00:00 - 01 :00 1.00 PULL P DECOMP 01 :00 - 05:00 4.00 PULL P DECOMP 05:00 - 05:30 05:30 - 07:30 07:30 - 11 :00 0.50 PULL P 2.00 PULL P 3.50 PULL P DECOMP DECOMP DECOMP 11 :00 - 12:30 1.50 PULL P DECOMP Bridal up blocks. Move camp and pits to OS 18. Move sub base off well. Remove derrick pins. Lower cattle chute. Lay down derrick. Move sub base to OS 18. Raise and pin derrick. Pin cattle chute. Hook top drive to blocks. Hang bridal lines. Hang bridal lines and rig up floor. Rig on standby due to wells group prep. work on 18-05. Coil tubing service unit rigged up on 18-05. Circulated tubing to hot diesel. Attempted to circulate down tubing, out IA. Unable to circulate. RD coil tubing. RU slickline. Pull lower dummy GLV. Able to circulate through lower GLM. Install DV in lower station. RD slickline. Remove flow lines and well house. Grade and level pad. Perform rig service while waiting on well. Install strainer on mud pump. Adjust length of top drive blower hose, service top drive. Change oil in centrifugal pumps. Inspect crown section. Work on BOP landings. Grease choke manifold. Slip new spool of drilling line onto drum and blocks. Lay mats. Spread herculite. Lay rig mats. Move and spot sub base over 18-05. Move pit complex and camp. Hook up lines in interconnect. Take on seawater. Lay herculite and spot pit complex. Spot cuttings tank, mud shack, and geologist shack. Berm rig. Hook up lines. Lay walkways. Spot camp. Move and spot shop. Hook up geronimo line. Accept rig at 04:30. Hold pre spud meeting and install secondary annulus valve. Bleed 220 psi off inner annulus. Suck fluid out of tree. NO adapter flange and tree. Verify tubing hanger threads and MU 5 3/4" RH ACME XO, 9 turns. NU BOP. RU to test BOP. Test BOPE to 250 psi /3,500 psi. Witness of BOP test waived by Chuck Sheve of AOGCC. RD test equipment. Pull blanking plug. RU lubricator and pull BPV. MU XOs and screw landing joint into tubing hanger. Attempt to screw into tubing hanger. Bottom thread on XO gald. Dress threads and attempt to screw into hanger. Not able to screw into hanger. MU spear with double grapple and packoff. Spear tubing. Unseat tubing hanger. Attempt to circulate. Pressure up to 1,500 psi. No circulation. Attempt to pull tubing. Work up to max pull of 235 K. Tubing did not pull free. Work tubing and attempt to gain circulation. Release spear and LD spear assembly. RU eline and lubricator and test to 500 psi. RIH with tubing punch and shoot holes at 11,250'. Atempt to circulate. Pressure up to 1,000 psi. No circulation. Bleed pressure off and POH w/ gun, all shots fired. MU gun #2 and start RIH. POH. Attempt to circulate down tubing with 3,000 psi. No circulation. Surge pressure on tubing. Swap hoses and attempt to Printed: 12/26/2002 10:13:47 AM ) " ) BPEXPLORATI0N èllpf!~~~iQI1~SlJrorJ1~rylRgp.ør-t Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-05 18-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/2/2002 Rig Release: 12/16/2002 Rig Number: 2ES Spud Date: 4/21/1986 End: 12/16/2002 Task Codè NPT Phase 12/3/2002 11 :00 - 12:30 1.50 PULL P DECOMP reverse circulate up to 3,000 psi. No circulation. 12:30 - 15:00 2.50 PULL P DECOMP RIH wI tubing punch (2" gun, 9 shots, 0 phasing) and fire gun at 11,021'to 11,023'. 15:00 - 19:00 4.00 PULL P DECOMP Pressure up on tubing to 2,750 psi. Pressure falling off to 550 psi. Continue to circulate hole clean with clean diesel at 3 bpm, 550 psi. 19:00 - 21 :30 2.50 PULL P DECOMP Pump 50 bbl soap pill, displace well bore to clean seawater at 5 bpm, 975 psi. Obtained soap and seawater returns after 323 bbls pumped. Clean seawater after 388 bbls pumped. Circulating uphole through GLM or possible hole in tubing near 4,800'. 21 :30 - 22:30 1.00 PULL P DECOMP Screw into tubing hanger with landing joint. Unseat hanger and pull 40 K over. Set in slips. 22:30 - 23:30 1.00 PULL P DECOMP RU eline. 23:30 - 00:00 0.50 PULL P DECOMP RIH wI 2 3/8" chemical cutter. 12/4/2002 00:00 - 02:00 2.00 PULL N DFAL DECOMP RIH to 2,300'. Lost GR signal from eline tool. POH and change tools. 02:00 - 06:00 4.00 PULL P DECOMP RIH with 2 3/8" chemical cutter. Fire chemical cutter at 10,470'. No indication on surface orfrom line tension that cutter fired. POH. Cutter hung up in GLM at 6,586'. Pressure up tubing and work cutter free. POH with 500 psi on tubing. No circulation at 500 psi. 06:00 - 06:30 0.50 PULL P DECOMP Latch onto landing joint and pull hanger to rig floor. Tubing came free at 21 OK. PU=175K. 06:30 - 07:00 0.50 PULL P DECOMP LD tubing hanger and eline. 07:00 - 10:00 3.00 PULL P DECOMP RU and break circulation. Well flowing. 100 psi shut in annulus pressure. Circulate through choke at 3 bpm, 400 psi. 10:00 - 14:00 4.00 PULL P DECOMP Screw top drive to tubing. Reciprocate and circulate at 6 bpm, 850 psi. 14:00 - 14:30 0.50 PULL P DECOMP RU casing equipment and spooling unit. 14:30 - 17:00 2.50 PULL P DECOMP Pull completion equipment. LD 4 1/2" tubing and dual encapsulated control lines. LD SSSV. Recovered 39 of 40 SS control line bands. 17:00 - 17:30 0.50 PULL P DECOMP RD spooling unit. 17:30 - 18:30 1.00 PULL P DECOMP POH and LD 4,000' 41/2" tubing. 18:30 - 19:00 0.50 PULL P DECOMP Circulate to clear tubing of diesel at 8 bpm, 610 psi. Pump dry job. 19:00 - 19:30 0.50 PULL P DECOMP LD 474' of 41/2" tubing. Recovered 140 joints of 4 1/2" tubing. 19:30 - 20:00 0.50 PULL P DECOMP Change out handling equipment to 3 1/2". 20:00 - 00:00 4.00 PULL P DECOMP LD 3 1/2" tubing. 12/5/2002 00:00 - 01 :00 1.00 PULL P DECOMP Continue to LD 3 1/2" tubing. Recovered 140 joints of 4 1/2" tubing, 193 joints of 31/2" tubing, 2 GLMs, 1 SSSV w/39 control line bands, 12.81' cut joint. 01 :00 - 02:00 1.00 PULL P DECOMP Clear floor, LD casing tongs. 02:00 - 03:30 1.50 PULL P DECOMP Pressure test casing to 3,500 psi. Lost 200 psi in 20 minutes. Bleed off pressure and check surface equipment. Pressure test casing to 3,500 psi for 30 minutes. Lost 250 psi in 30 minutes. 03:30 - 04:00 0.50 BOPSURP DECOMP Install wear bushing. 04:00 - 05:00 1.00 FISH P DECOMP MU overshot w/ cut lip guide and mill control packoff, and 3 1/2" grapple, bumper sub, jars, 9 DCs, and accelerator. 05:00 - 10:00 5.00 FISH P DECOMP RIH picking up 4" DP to 7,928'. 10:00 - 11 :30 1.50 FISH P DECOMP Circulate diesel and gas out at 10.5 bpm, 1,750 psi. Printed: 12/26/2002 10:13:47 AM ) ) BPEXPLORATION Op:~fêÌ~i.<>.I')$'~ymr1'lêÌ.rY ...RepQ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-05 18-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/2/2002 Rig Release: 12/16/2002 Rig Number: 2ES Spud Date: 4/21/1986 End: 12/16/2002 Date From('"Tó HOOrs Task .Códe. NPT De$øri ptíón qfOperé1tiOns 12/5/2002 11 :30 - 14:30 3.00 FISH P DECOMP Continue to RIH and PU DP to 10,456'. Break circulation every 1,000'. 14:30 - 16:00 1.50 FISH P DECOMP Circulate at 10 bpm, 2,015 psi. PU=180K, SO=140K, Rot=155K, Tq. =7K 16:00 - 16:30 0.50 FISH P DECOMP Tag top of 3 1/2" tubing stub at 10,464'. Engage fish. Jar on tubing with 325K up. Fish came free. PU weight with fish=200K. 16:30 - 17:30 1.00 FISH P DECOMP Unable to circulate through fish. POH to 10,390'. Circulation obtained. CBU at 10.5 bpm, 2,115 psi. 17:30 - 18:30 1.00 FISH P DECOMP Monitor well. Clean oil based mud / KCI fluid from under shale shakers. 18:30 - 22:30 4.00 FISH P DECOMP Pump dry job. POH from 10,390' to 314'. 22:30 - 23:30 1.00 FISH P DECOMP Stand back BHA. 23:30 - 00:00 0.50 FISH P DECOMP LD overshot with cut joint of 3 1/2" tubing. 12/6/2002 00:00 - 01 :30 1.50 FISH P DECOMP POH and LD 31/2" tubing fish. Top cutjt 16.74'. Recovered 36 joints of tubing and one 12.57' cut joint. 1/4 of the tubing circumference was not cut. Three of the joints that were previously shot with an eline tubing punch, at 11,021', 11,250', and 11,505' had 9 holes each. The holes in the joint at 11,505' were plugged. 01 :30 - 02:00 0.50 FISH P DECOMP LD casing tongs. Clear rig floor. 02:00 - 03:00 1.00 FISH P DECOMP Pressure test casing to 3,500 psi for 30 minutes. Lost 150 psi. 03:00 - 05:30 2.50 FISH P DECOMP Clean drip pan. Remove rotary table and clean out emulsified mud and solids that were circulated out of the hole. 05:30 - 06:30 1.00 FISH P DECOMP Break fish out of overshot and break down overshot assembly 06:30 - 08:00 1.50 CLEAN P DECOMP MU window mills, 1 joint HWDP, float sub, bumper sub, jar, DCs, 15 joints HWDP to 770'. 08:00 - 10:00 2.00 CLEAN P DECOMP RIH picking up 108 joints 4" DP to 4,131'. 10:00 - 14:00 4.00 CLEAN P DECOMP RIH to 11,535'. 14:00 - 15:30 1.50 CLEAN P DECOMP Wash from 11,535' to 11,622'. Tag tubing stump at 11,622'. 15:30 - 16:30 1.00 CLEAN P DECOMP Circulate sweep around at 10.5 bpm, 2,700 psi. 16:30 -17:00 0.50 CLEAN P DECOMP POH from 11,622' to 11,157'. 17:00 - 18:00 1.00 CLEAN P DECOMP Test casing to 3,500 psi for 30 minutes. Lost 100 psi in 30 minutes. 18:00 - 18:30 0.50 CLEAN P DECOMP RIH from 11,157' to 11,622'. 18:30 - 22:00 3.50 CLEAN P DECOMP Circulate sweep sround at 11.7 bpm, 2,770 psi. Still getting some oil based emulsion back. Circulate second sweep. 22:00 - 22:30 0.50 CLEAN P DECOMP Service top drive. 22:30 - 00:00 1.50 CLEAN P DECOMP POH from 11,622' to 8,265'. PU=190K, SO=135K. 12/7/2002 00:00 - 04:30 4.50 CLEAN P DECOMP POH and stand back BHA. 04:30 - 05:30 1.00 STWHIP P WEXIT MU whipstock to window mills. Orient whipstock to MWD. 05:30 - 06:30 1.00 STWHIP P WEXIT RIH with BHA to 830'. Change elevators. Flow test MWD. 06:30 - 11 :00 4.50 STWHIP P WEXIT RIH from 830' to 11,561'. 11 :00 - 11 :30 0.50 STWHIP P WEXIT Install blower hose. Orient whipstock. Tag tubing stump at 11,622'. Set whipstock 82 degress right of high side. Shear whipstock bolt. Top of window will be 11,604'. 11 :30 - 14:00 2.50 STWHIP P WEXIT Displace well bore to 8.6 ppg Flo-pro mud. 14:00 - 00:00 10.00 STWHIP P WEXIT Mill window from 11,604' to 11,621 '. Weight on mill 2K - 10K from 11,604' to 11,613'. Torque 6K - 10K. RPM 95 - 120. Flow rate 300 gpm. Penetration 10 - 25 minutes per foot. From 11,613' to 11,621' penetration rate slowed to 30 - 62 minutes per foot. Increased weight on mill to 1 OK - 35K. 12/8/2002 00:00 - 04:00 4.00 STWHIP P WEXIT Continue to mill to 11,622'. Increased weight on mill to 30K - Printed: 12/26/2002 10:13:47 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-05 18-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES [Date' From - To .' HöÜts Task Code NPT ' Phase 12/8/2002 00:00 - 04:00 4.00 STWHIP P WEXIT 04:00 - 04:30 0.50 STWHIP P 04:30 - 06:00 1.50 STWHIP P 06:00 - 10:00 4.00 STWHIP P 10:00 - 10:30 0.50 STWHIP P 10:30 - 11 :00 0.50 STWHIP P 11 :00 - 12:00 1.00 STWHIP P 12:00 - 15:30 3.50 STWHIP P 15:30 - 17:30 2.00 STWHIP P 17:30 - 18:00 0.50 STWHIP P 18:00 - 19:30 1.50 STWHIP P 19:30 - 20:00 0.50 DRILL P 20:00 - 00:00 4.00 STWHIP P 12/9/2002 00:00 - 01 :00 1.00 STWHIP P 01 :00 - 02:00 1.00 BOPSUR P 02:00 - 02:30 0.50 BOPSUR P 02:30 - 06:00 3.50 BOPSUR P 06:00 - 15:30 9.50 BOPSUR P 15:30 - 19:00 3.50 DRILL P 19:00 - 23:00 4.00 DRILL P 23:00 - 23:30 0.50 DRILL P 23:30 - 00:00 0.50 DRILL P 12/10/2002 00:00 - 00:30 0.50 DRILL P 00:30 - 02:00 1.50 DRILL P 02:00 - 00:00 22.00 DRILL P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 12/2/2002 Rig Release: 12/16/2002 Rig Number: 2ES Spud Date: 4/21/1986 End: 12/16/2002 DescriþtiorlQfQper~tibns 35K. Pump sweep while milling. One foot of progress in the last 140 minutes. Metal cuttings, formation sand, and cement in samples. Mills quit. Monitor well, static. POH to 11,440'. Pump dry job. Blow down surface equipment. Slip and cut drilling line, service top drive. POH from 11,440' to 812'. Stand back BHA. LD MWD and window mills. Starter mill worn flat and upper string mill is 1/16" under gauge. MU new starter mill, bit sub, and new full gauge string mill. RIH to 11,622'. Mill from 11,622' to 11,630'. Weight on mills 6K - 20K. RPM: 100 - 110. Torque: 8K - 1 OK ft*lbs, 400 gpm. Penetration rate: 3 - 17 minutes per foot. Work through window. Circulate sweep around at 11 bpm, 2,350 psi. Perform FIT test to 10.0 ppg EMW. (8.6 ppg mud, 8,630' TVD, 629 psi surface pressure). POH from 11,630' to 785'. LD BHA. String mill in gauge. 10% wear on starter mill. Flush BOP stack of all metal. Flush choke and kill line. Pull wear bushing. Set test plug. Test BOPE to 250 psi / 3,500 psi. Hydril will not test. Change out Hydril element. Witness of test waived by John Crisp of AOGCC. Change out Hydril element and test Hydril to 250 psi / 3,500 psi. RD test equipment. Pull test plug and install wear bushing. MU BHA. Upload MWD. Load RA source. RIH to 11,526'. Service top drive and install blower hose. Orient to 82 degrees right of high side. PU=165K, SO=135K. RIH With 4" Drill Pipe From Mast To 11,580' - Orient Motor And Bit Travel Thru Window To 11,627' Wash Under Gauge Hole From 11,627' To 11,630' Obtain Slow Pump Rates - Directional Drill Ahead From 11,630' To 12,368' - Weight On Bit 7K To 20K - With Pump Rate At 114 Strokes Or 279 GPM - Off Bottom Pump Pressure At 1945 Psi. & On Bottom Pump Pressure At 2300 Psi. - Top Drive RPM At 0 To 50 - Off Bottom Torque At 7K & On Bottom Torque At 1 OK - String Rotating Weight At 155K - Drag Up At 180K And Drag Down At 135K 11,660' To 11,700' - (Zone 4 N) - Very Fine Sand With Common Siltstone - Siltstone Is Light Tan And Hard 11,700' To 11,930' - (Zone 2A) - Medium Grain Sand - ROP Average 50 To 100 FPH - Sand Is Clean 20 To 25 API GR And Well Sorted Probably Gas Swept - High Resisitivity 11,930' To 12,170' - (Zone 1 B) - Predomiately Fine Grain Sand - Clean To Slightly Shaley Increasingly Silty Near Base- Probable Oil With Gas Under Reams - Several Thin Siltstone Interbeds Printed: 12/26/2002 10:13:47 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-05 18-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/2/2002 Rig Release: 12/16/2002 Rig Number: 2ES Spud Date: 4/21/1986 End: 12/16/2002 Dáte From-To HÖüts Task Cöde NPT Phåse 12/10/2002 02:00 - 00:00 22.00 DRILL P PROD1 12,170' To 12,200' - (Zone 1A) -Increasingly Very Fine Sand- Gamma Ray Shift At 12,170' = TDF 12,200' To 12,368' - Interbedded Thin Sands And Shales- Sands Remain Very Fine - Fine Grained To Silty - Shales Are Locally Dark Gray - ROP Averaging 50 To 70 FPH While Rotating And 30 To 50 FPH While Sliding - Hole Appears Sticky In Shale Intervals. 12/11/2002 00:00 - 16:00 16.00 DRILL P PROD1 Directional Drill Ahead From 12,368' To 13,235' - Weight On Bit 7K To 20K - With Pump Rate At 114 Strokes Or 279 GPM- Off Bottom Pump Pressure At 1950 Psi. & On Bottom Pump Pressure At 2400 Psi. - Top Drive RPM At 0 To 70 - Off Bottom Torque At 7K & On Bottom Torque At 10K - String Rotating Weight At 155K - Drag Up At 175K And Drag Down At 135K Actual Slide Time - 3.6 Hours Actual Rotating Time - 6.5 Hours 12,200 - 12,520' - Interval consists of predominantly shale and siltstone with thin (-2' vertical) very fine sands. Inverted the well in this interval in an attempt to cross cut the upper 1A sands. 12,520 - 13,250' - Predominantly sand. Increasingly fine grained with depth. Sands are clean with good oil staining and florescence. Several thin siltstone beds, <1' thick were encountered. Interval drilled well (ROP +/- 1 OO'/hr) while rotating and sliding. Formation Tops: TZ2A - 11 ,695'md 8,608'tvdss TZ1 B - 11 ,915'md 8,661 'tvdss TZ1A - 12, 170'md 8,706'tvdss 16:00 - 16:30 0.50 DRILL P PROD1 While Directional Drilling (Sliding) The Drill String Briefly Became Stuck On Bottom - Jar String Free With Som.e Right Hand Torque - Keep String Moving 16:30 - 18:30 2.00 DRILL P PROD1 Circulate Sweep Around To Clean Hole And Condition Mud 18:30 - 19:30 1.00 DRILL P PROD1 Monitor Well Bore (Static) - Pull 5 Stands Of 4" Drill Pipe (Wet) With No Problems - Blow Down Top Drive - Continue To POH With 4" Drill Pipe Into Window (11,571') With No Problems 19:30 - 20:00 0.50 DRILL P PROD1 Service Can-Rig Top Drive And Traveling Blocks 20:00 - 20:45 0.75 DRILL P PROD1 RIH With 4" Drill Pipe From Mast To 13,210' With No Problems - Connect Top Drive And Break Circulation Slowly 20:45 - 21 :30 0.75 DRILL P PROD1 Circulate LCM Sweep In Open Hole Section And Spot Glass Beads While Rotating And Reciprocating Drill String 21 :30 - 00:00 2.50 DRILL P PROD1 Continue To Directional Drill Ahead From 13,235' To 13,378' Actual Slide Time - .5 Hours Actual Rotating Time - 1.1 Hours 13,250 - 13,500' - Reverted well bore in an attempt to stay within Z1A, and cross cut objective sands again. Encountered exceptionally clean (30 - 50 API GR), fine grained sands with minor thin siltstones. Printed: 12/26/2002 10:13:47 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 18-05 18-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/2/2002 Rig Release: 12/16/2002 Rig Number: 2ES Spud Date: 4/21/1986 End: 12/16/2002 From - To Hours Task Code NPT D~scrip~jQnofoper~tiohS 12/12/2002 00:00 - 03:30 03:30 - 05:30 05:30 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 09:30 09:30 - 12:00 12:00 - 12:30 12:30 - 14:30 14:30 - 16:00 16:00 - 17:00 17:00 - 20:30 20:30 - 00:00 12/13/2002 00:00 - 01:15 01 : 15 - 01 : 30 01 :30 - 05:30 05:30 - 06:00 06:00 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 16:00 16:00 - 17:30 17:30 - 18:00 3.50 DRILL P PROD1 2.00 DRILL P PROD1 1.50 DRILL P 1.00 DRILL P PROD1 PROD1 0.50 DRILL 1.00 DRILL 2.50 DRILL 0.50 DRILL 2.00 DRILL 1.50 DRILL 1.00 DRILL 3.50 DRILL P P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 3.50 DRILL P 1.25 CASE P 0.25 CASE P PROD1 COMP COMP 4.00 CASE P COMP 0.50 CASE P 4.00 CASE P 0.50 CASE P COMP COMP COMP 1.50 CASE P COMP 1.00 CEMT P COMP 3.00 CEMT P COMP 1.50 CASE P COMP 0.50 CASE P COMP Directional Drill Ahead From 13,378' To 13,656' Pump sweep, circulate at 115spm, 280gpm and reciprocate pipe. Monitor well, static. POOH from 13656 to 11526', no problems. Slip and cut drilling line. Service top drive. RIH from 11526' to 13656'. No problems. No fill on bottom. Sweep hole. CBU @ 13656', 280gpm, 2000psi. Continue spotting liner running pill. POOH from 13656' to 11589', LID 68 joints 4" dp. No problems. Drop dart and pump Hi-Vis sweep, 12bpm @ 1790psi. POOH from 11,589' to 10,314', LID 40 joints 4" dp. POOH from 10,314' to 329' SLM. Remove RA sources, download Sperry MWD. LID BHA. Clear rig floor. Conduct PJSM, rig up to run 4 1/2" liner. Conduct safety meeting regarding 4 1/2" liner running operation. M/U shoe equipment, check floats, RIH with 41/2", 12.6#, L-80 liner filling pipe every 5 jts. P/U Baker HMC hanger and ZXP packer assembly. Rig down casing tools and equipment, clear rig floor. *NOTE 4 1/2" liner weight when full of fluid at 62K Circulate one liner volume at 5 BPM with 250 psi. RIH With 41/2" liner on 4" drill pipe from mast to 11,584' Connect top drive and circulate drill pipe and liner volume at 6.4 BPM with 890 psi. Continue to RIH with liner thru open hole section from 11,604' to 13,656' with no problems - Make up cement plug draping head and install circulating lines. Circulate and condition mud - Hold pre-job meeting with all personal involved with cement operation Shut down and turn over to Dowell Schlumberger - Pump 5 bbl. fresh water - Test surface lines at 4,000 psi. - While reciprocating liner pump 15 bbls. CW-100 Pre-flush spacer - 25 bbls. 9.5 ppg. mud push spacer - 54 bbls. (259 sacks) 15.8 ppg. Class "G" Cement - Flush cement lines - Release drill pipe wiper plug - Displace with 71 bbls. perf pill and 83 bbls. 8.6 ppg flo-pro mud to bump plug - Increase pressure to 3700 psi. and set Baker HMC liner hanger - Bleed off pressure and check floats (OK) cement in place at 14:34 hours - Apply 20 turns of right hand rotation to release liner - Pressure up to 1000 psi. and unsting from liner top bring pumps on line and circulate bottoms up at 12 BPM with 2100 psi. - Slow pump rate to 2.6 BPM and set down with 60K having good indication that Baker ZXP Packer set, rotate on packer with 60K Displace flo-pro mud in well to 8.5 ppg. seawater at 9,864' - 10 BPM 2300 psi. Rig down surface circulating lines and rig down Baker plug droping head - Clear rig floor Printed: 12/26/2002 10:13:47 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-05 18-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/2/2002 Rig Release: 12/16/2002 Rig Number: 2ES Spud Date: 4/21/1986 End: 12/16/2002 Date Frori1.-'To Hours Task .Code NPT 12/13/2002 18:00 - 21 :30 3.50 CASE P COMP 21 :30 - 00:00 2.50 BOPSURP COMP 12/14/2002 00:00 - 00:30 0.50 BOPSURP COMP 00:30 - 01 :30 1.00 EVAL P COMP 01 :30 - 03:00 1.50 BOPSURP COMP 03:00 - 03:30 0.50 PERF P COMP 03:30 - 04:45 1.25 PERF P COMP 04:45 - 07:30 2.75 PERF P COMP 07:30 - 08:00 0.50 PERF P COMP 08:00 - 13:00 5.00 PERF P COMP 13:00 - 13:30 0.50 PERF P COMP 13:30 - 14:00 0.50 PERF P COMP 14:00 - 14:30 COMP 0.50 PERF P 14:30 - 16:00 16:00 - 16:30 16:30 - 20:30 20:30 - 21 :00 21 :00 - 22:00 22:00 - 22:30 22:30 - 23:00 1.50 PERF 0.50 PERF 4.00 PERF 0.50 PERF 1.00 PERF 0.50 PERF 0.50 PERF P COMP COMP COMP COMP COMP COMP COMP P P P 23:00 - 00:00 12/15/2002 00:00 - 01 :45 1.00 PERF P 1.75 PERF P COMP COMP 01 :45 - 02:00 0.25 PERF P COMP 02:00 - 04:30 COMP 2.50 PERF P P$sbriptiön ôf ()þèrations POH with Baker liner running tool and lay down same Pull wear ring and install test plug - Change pipe rams in top gate to 2 3/8" - Test rams, floor valve, dart valve at 3500 psi. (Good Test) Rig down testing equipment and install wear ring - Clear rig floor Pressure test casing at 3500 psi. for 30 minutes (Test Good) Remove And Inspect 4 Lock Down Studs On Tubing Spool Only 1 Was Damaged - Test Lock Down Stud Packing At 3500 Psi. (Had 1 Leaking Tighten And Retest Tested Good) Hold pre-job safety meeting regarding Haliburton Perf Guns - Review Drill Pipe Convyed Perforating Recommended Procedures Pick Up And RIH With Haliburton 2 1/2" Perf Guns To 1037' Per Program Rig Up Power Tongs - Make Up Ported Sub And Cross Overs - Pick Up And RIH With 2 3/8" Drill Pipe To 3763' Rig down power tongs and change equipment to accept 4" drill pipe - Clear rig floor RIH with 4" drill pipe from mast tag landing collar at 13570' - Record weights 170K up and 135K down - Position perf gun bottom shot at 13560' (Bottom of assembly at 13,563') Hold pre-job meeting regarding perforation operation - Close rams and pressure up to 3000 psi. to fire guns - Haliburton sound recorder indicated that guns fired - Bleed pressure to 0 psi. and open rams. Perforaton Intervals 4 Shots Per Foot From: 12,530' To 12,670' 12,770' To 13,250' 13,320' To 13,560' POH with 4" drill pipe stand back in mast - Position perf guns above top perforation to 12,441' Monitor well bore (Static) - Pump dry job and blow down top drive POH laying down 4" drill pipe to 10,991' Service top drive and traveling blocks Continue to lay down 4" drill pipe to 3,761' RIH with 14 stands of 4" drill pipe from mast to 5,068' Slip and cut 111' of 1 1/4" drilling line POH laying down 4" drill pipe to 3,761' Rig up power tongs and change equipment to accept 2 3/8" drill pipe Lay down 2 3/8" drill pipe from 3,761' to 2,920' Continue to lay down 2 3/8" drill pipe from 2,920' to 1,036' - Break out and remove cross over subs - Rig down power tongs - Change elevators to accept perf gun lift subs. Hold pre-job meeting regarding traped pressure and perf gun handling safety Lay down Haliburton 2 1/2" perf guns - Wash and clear rig floor of tools and perf gun equipment *NOTE* All shots fired on perf guns Printed: 12/26/2002 10:13:47 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-05 18-05A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Dpte FrOf11-"Fô . Hôurš "Fäsk. Code NP"F Phase 12/15/2002 04:30 - 05:00 0.50 BOPSUR P COMP 05:00 - 05:30 0.50 RUNCOrvP COMP 05:30 - 13:30 8.00 RUNCOrvP COMP 13:30 - 14:30 1.00 RUNCOrvP COMP 14:30 - 17:30 3.00 RUNCOrvP COMP 17:30 - 19:00 1.50 RUNCOrvP COMP 19:00 - 20:30 1.50 RUNCOrvP COMP 20:30 - 00:00 3.50 RUNCOrvP COMP 12/16/2002 00:00 - 01 :00 1.00 RUNCOrvP COMP 01 :00 - 01 :30 0.50 RUNCOrvP COMP 01 :30 - 02:30 1.00 RUNCOrvP COMP 02:30 - 03:30 1.00 BOPSURP COMP 03:30 - 04:00 0.50 BOPSUR P COMP 04:00 - 05:00 1.00 BOPSUR P COMP 05:00 - 07:30 2.50 WHSUR P COMP 07:30 - 08:30 1.00 WHSUR P COMP 08:30 - 10:00 1.50 WHSUR P COMP 10:00 - 10:30 0.50 WHSUR P COMP 10:30 - 11 :30 1.00 WHSUR P COMP 11 :30 - 12:30 1.00 WHSUR P COMP 12:30 - 13:30 1.00 WHSUR P COMP 13:30 - 14:30 1.00 WHSUR P COMP 14:30 - 15:00 0.50 WHSUR P COMP Start: 12/2/2002 Rig Release: 12/16/2002 Rig Number: 2ES Spud Date: 4/21/1986 End: 12/16/2002 R$$çriþ~ibnofOþerations Pull wear ring Hold pre-job meeting - Rig up power tongs and equipment Pick up and RIH with (185 Joints) 41/2" completion assembly per well program to 7704' Rig up Haliburton control line spooling unit and sheave - Install 2 control lines and test to 5000 psi. (Test Good) Continue to RIH with (239 Joints) 4 1/2" completion assembly to 9887' - Bottom of tie back sleeve with tubing measurements Lay down (3) Joints and space out tubing - Make up hanger and cross overs to land with drill pipe - Install control lines and test to 5000 psi. (Test Good) *NOTE* Ran total of 57 bands on control lines Record up weight at 125K and down weight at 107K - Lower FMC hanger to tubing spool and orient control line ports - Energize lock down studs and test control lines thru tubing spool (Test Good) - Wire line entry guide set at 9885' Reverse circulate at 3 BPM 225 Psi. - 291 barrels seawater - 230 barrels sea water and corrosion inhibitor - 227 barrels seawater Continue to reverse circulate seawater and inhibitor at 3 BPM Drop ball and rod and allow time to get on seat RHC-Plug located at 9872' Pressure up down tubing to 3500 psi. to set Baker S-3 Packer - Continue to hold pressure for 30 minutes (Good Test) - Bleed tubing pressure to 1500 psi. - Pressure down annulus to 3500 psi. for 30 minute packer test (Good Test) - Bleed off tubing pressure and shear OCR valve in upper GLM Install BPV and test to 2500 psi. (Good Test) - Blow down all surface lines Change out 23/8" ram blocks in top gate and install 3 1/2" X 6" Variables Nipple down 13 5/8 5M BOP and related equipment Install FMC Adaptor Flange And Test To 5000 Psi. (Test Good) - Nipple Up FMC Tree Rig up DSM lubricator and pull BPV - Install Tree Test Plug Rig Up and test tree to 5000 psi. for 10 minutes several attempts required to obtain good test due to leaks - Change out test hose and tighten top tree flange - (Test Good) Rig up DSM and pull tree test plug Hold pre-job safety meeting - Rig up Little Red Services for freeze protection Reverse circulate 155 barrels diesel at 2.5 BPM with 275 psi. U-tube diesel from annulus to tubing Install BPV and test from below to 2500 psi. (Test Good) - Freeze protect tree cycle all valves and secure tree Remove secondary valve from annulus - Pick up area *NOTE* Nabors Rig 2ES Released From Well OS 18-05A at 15:00 Hours On 12-16-2002 Printed: 12/26/2002 10:13:47 AM ) ') C;;Q;)-d/l 31-Dec-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 18-05A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 11,537.45' MD Window / Kickoff Survey 11,604.00' MD (if applicable) Projected Survey: 13,656.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN 03 2003 A1aIka Oö ¡ Gal Cons. Commi8Iion AnctøIge Sperry-Sun Drilling Services North Slope Alaska BPXA PBU EOA DS 18 18-05A Job No. AKZZ22191, Surveyed: 12 December, 2002 Survey Report 2 January, 2003 Your Ref: 500292158301 Surface Coordinates: 5960911.44 N, 691538.57 E (70017' 51.9618" N, 148026' 55.6004" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 960911.44 N, 191538.57 E (Grid) Surface Coordinates relative to Structure Reference: 1698.79 N, 3.66 W (True) Kelly Bushing: 46.45ft above Mean Sea Level Elevation relative to Project V Reference: 46.45ft Elevation relative to Structure Reference: 46.45ft spe""'''''V-SUI! DRìLLI.NG SEER-VICES A Halliburton Company ):= \ --VE ~. ~ Survey Ref: svy11414 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18 - 18-05A Your Ref: 500292158301 Job No. AKZZ22191, Surveyed: 12 December, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 11537.45 74.800 240.800 8566.92 8613.37 3177.70 S 5920.87 W 5957583.87 N 685700.61 E 6394.00 Tie-on Point AK-6 BP _IFR-AK 11604.00 75.400 240.630 8584.03 8630.48 3209.16 S 5976.96 W 5957550.99 N 685645.34 E 0.935 6454.81 Window Point 11641.20 75.180 244.650 8593.48 8639.93 3225.69 S 6008.91 W 5957533.65 N 685613.82 E 10.469 6489.20 11674.90 74.550 248.290 8602.28 8648.73 3238.68 S 6038.73 W 5957519.90 N 685584.35 E 10.593 6520.87 11705.60 74.560 251.600 8610.46 8656.91 3248.82 S 6066.52 W 5957509.05 N 685556.82 E 10.392 6550.03 ~ 11735.23 75.370 254.790 8618.15 8664.60 3257.10 S 6093.91 W 5957500.09 N 685529.65 E 10.751 6578.45 11767.48 74.940 258.840 8626.42 8672.87 3264.21 S 6124.26 W 5957492.21 N 685499.50 E 12.212 6609.58 11798.70 76.130 260.600 8634.21 8680.66 3269.60 S 6154.00 W 5957486.06 N 685469.90 E 6.658 6639.81 11828.68 76.850 265.230 8641.22 8687.67 3273.19 S 6182.92 W 5957481.73 N 685441.08 E 15.207 6668.90 11862.26 76.460 269.010 8648.97 8695.42 3274.83 S 6215.54 W 5957479.26 N 685408.51 E 11.014 6701.30 11890.11 76.840 271.960 8655.41 8701.86 3274.60 S 6242.64 W 5957478.79 N 685381.42 E 10.396 6727.91 11920.09 77.150 275.520 8662.16 8708.61 3272.70 S 6271.78 W 5957479.96 N 685352.24 E 11.616 6756.24 11954.75 78.290 277.520 8669.53 8715.98 3268.85 S 6305.43 W 5957482.94 N 685318.50 E 6.527 6788.66 11985.76 78.4 70 280.080 8675.77 8722.22 3264.20 S 6335.44 W 5957486.82 N 685288.38 E 8.107 6817.36 12014.21 78.660 279.960 8681.42 8727.87 3259.35 S 6362.90 W 5957490.98 N 685260.81 E 0.785 6843.50 12048.52 78.920 280.400 8688.09 8734.54 3253.40 S 6396.03 W 5957496.08 N 685227.54 E 1.469 6875.03 12079.64 79.920 277.990 8693.80 8740.25 3248.52 S 6426.22 W 5957500.19 N 685197.23 E 8.263 6903.86 12107.31 80.980 276.690 8698.39 8744.84 3245.03 S 6453.28 W 5957502.99 N 685170.09 E 6.012 6929.86 12137.83 83.220 273.490 8702.59 8749.04 3242.35 S 6483.39 W 5957504.90 N 685139.92 E 12.717 6959.00 12168.19 83.710 273.220 8706.04 8752.49 3240.59 S 6513.50 W 5957505.90 N 685109.78 E 1.840 6988.31 12201.17 84.150 273.760 8709.53 8755.98 3238.59 S 6546.23 W 5957507.06 N 685077.00 E 2.105 7020.16 12235.12 86.490 273.050 8712.30 8758.75 3236.58 S 6580.01 W 5957508.20 N 685043.19 E 7.201 7053.03 ~ 12266.38 87.350 272.820 8713.98 8760.43 3234.98 S 6611.18 W 5957509.01 N 685011.99 E 2.848 7083.41 12294.96 88.030 270.650 8715.13 8761.58 3234.12 S 6639.72 W 5957509.14 N 684983.43 E 7.951 7111.34 12328.63 87.720 266.370 8716.38 8762.83 3234.99 S 6673.35 W 5957507.41 N 684949.84 E 12.736 7144.58 12358.95 88.890 261.640 8717.28 8763.73 3238.16 S 6703.48 W 5957503.48 N 684919.79 E 16.064 7174.79 12385.75 90.370 258.050 8717.45 8763.90 3242.88 S 6729.86 W 5957498.09 N 684893.55 E 14.489 7201.59 12422.81 92.650 254.290 8716.47 8762.92 3251.74 S 6765.82 W 5957488.32 N 684857.82 E 11.862 7238.56 12452.94 90.920 252.860 8715.53 8761.98 3260.25 S 6794.71 W 5957479.07 N 684829.16 E 7.448 7268.50 12480.94 91.480 253.060 8714.95 8761.40 3268.45 S 6821.47 W 5957470.19 N 684802.62 E 2.124 7296.30 2 January, 2003 - 11:18 Page 20f4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18 - 18-05A Your Ref: 500292158301 Job No. AKZZ22191, Surveyed: 12 December, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12574.89 90.250 252.810 8713.53 8759.98 3296.02 S 6911.27 W 5957440.34 N 684713.55 E 1.336 7389.58 12669.21 90.490 253.180 8712.92 8759.37 3323.60 S 7001.47 W 5957410.47 N 684624.09 E 0.468 7483.26 12762.86 90.740 253.540 8711.92 8758.37 3350.42 S 7091.19W 5957381.38 N 684535.08 E 0.468 7576.33 12856.62 91.410 253.530 8710.16 8756.61 3376.99 S 7181.09 W 5957352.52 N 684445.88 E 0.715 7669.54 12951.11 92.220 253.700 8707.16 8753.61 3403.63 S 7271.70 W 5957323.58 N 684355.98 E 0.876 7763.45 .~ 13043.41 90.180 255.050 8705.23 8751.68 3428.48 S 7360.56 W 5957296.47 N 684267.78 E 2.650 7855.32 13137.32 90.860 255.370 8704.38 8750.83 3452.46 S 7451.35 W 5957270.19 N 684177.63 E 0.800 7948.94 13230.81 90.250 256.330 8703.47 8749.92 3475.31 S 7542.00 W 5957245.04 N 684087.59 E 1.217 8042.22 13324.47 86.980 258.550 8705.74 8752.19 3495.67 S 7633.37 W 5957222.36 N 683996.77 E 4.219 8135.76 1341 7.90 88.090 258.650 8709.76 8756.21 3514.12 S 7724.87 W 5957201.58 N 683905.77 E 1.193 8229.08 13512.03 87.970 258.150 8712.99 8759.44 3533.03 S 7817.03 W 5957180.32 N 683814.13 E 0.546 8323.13 13584.66 88.030 258.210 8715.53 8761.98 3547.90 S 7888.07 W 5957163.65 N 683743.48 E 0.117 8395.69 13656.00 88.030 258.210 8717.98 8764.43 3562.4 7 S 7957.87 W 5957147.31 N 683674.08 E 0.000 8466.97 Projected Survey 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 259.690° (True). Magnetic Declination at Surface is 26.151°(04-Dec-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 13656.00ft., The Bottom Hole Displacement is 8718.88ft., in the Direction of 245.884° (True). ~ 2 January, 2003 - 11:18 Page 3 0(4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18 -18-05A Your Ref: 500292158301 Job No. AKZZ22191, Surveyed: 12 December, 2002 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ' (ft) (ft) (ft) Comment 11537.45 11604.00 13656.00 8613.37 8630.48 8764.43 3177.70 S 3209.16 S 3562.47 S 5920.87 W 5976.96 W 7957.87 W Tie-on Point Window Point Projected Survey ~ Survey tool program for 18-05A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 11537.45 0.00 11537.45 8613.37 13656.00 8613.37 AK-3 BP _HM - BP High Accuracy Magnetic(18-05) 8764.43 AK-6 BP _IFR-AK(18-05A) ~ 2 Jantlary, 2003 - 11:18 Page 4 of4 DrillQuest 3.03.02.004 ') t ) ¿;( o~- d )1 31-Dec-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 18-05A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 11,537.45' MD Window / Kickoff Survey 11,604.00 I MD (if applicable) Projected Survey: 13,656.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN 03 2003 Alaska on & Gas Cons CommiaIon ~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU EOA DS 18 18-05A MWD '~ Job No. AKMW22191, Survey Report 2 January, 2003 Your Ref: 500292158301 Surface Coordinates: 5960911.44 N, 691538.57 E (70017' 51.9618" N, 148026' 55.6004" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~" Surface Coordinates relative to Project H Reference: 960911.44 N, 191538.57 E (Grid) Surface Coordinates relative to Structure Reference: 1698.79 N, 3.66 W (True) Kelly Bushing: 46.45ft above Mean Sea Level Elevation relative to Project V Reference: 46.45,t Elevation relative to Structure Reference: 46.45ft spe"-,,,-,v-sul! DR-ILLïN_G ~eRVIc:es A Halliburton Company Survey Ref: svy11415 Sperry-Sun Drilling Services Survey Report forPBU_EOA DS 18 -18-05A MWD Your Ref: 500292158301 Job No. AKMW22191, BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11537.45 74.800 240.800 8566.92 8613.37 3177.70 S 5920.87 W 5957583.87 N 685700.61 E 6394.00 Tie-in Point MWD Magnetic --11604.00 75.400 240.630 8584.03 8630.48 - 3209.16 S 5976.96 W 5957550.99 N 685645.34 E 0.935 6454.81 Window Point 11641.20 75.180 244.650 8593.48 8639.93 3225.69 S 6008.91 W 5957533.65 N 685613.82 E 10.469 6489.20 11674.90 74.550 248.290 8602.28 8648.73 3238.68 S 6038.73 W 5957519.90 N 685584.35 E 10.593 6520.87 11705.60 74.560 249.750 8610.46 8656.91 3249.27 S 6066.36 W 5957508.61 N 685557.00 E 4.584 6549.95 '-...-ø' 11735.23 75.370 252.211 8618.15 8664.60 3258.60 S 6093.41 W 5957498.60 N 685530.19 E 8.474 6578.23 11767.48 74.940 258.589 8626.42 8672.87 3266.45 S 6123.56 W 5957489.98 N 685500.25 E 19.162 6609.30 11798.70 76.130 261.612 8634.22 8680.67 3271.65 S 6153.34 W 5957484.03 N 685470.62 E 10.121 6639.52 11828.68 76.850 265.023 8641.22 8687.67 3275.04 S 6182.28 W 5957479.90 N 685441.77 E 11.320 6668.61 11862.26 76.460 268.946 8648.98 8695.43 3276.76 S 6214.90 W 5957477.35 N 685409.20 E 11.426 6701.01 11890.11 76.840 272.178 8655.41 8701.86 3276.49 S 6242.00 W 5957476.93 N 685382.11 E 11.373 6727.62 11920.09 77.1 50 276.975 8662.16 8708.61 3274.16 S 6271.10 W 5957478.51 N 685352.95 E 15.624 6755.84 11954.75 78.290 278.140 8669.53 8715.98 3269.70 S 6304.68 W 5957482.11 N 685319.28 E 4.648 6788.07 11985.76 78.470 281.319 8675.78 8722.23 3264.57 S 6334.61 W 5957486.48 N 685289.22 E 10.058 6816.60 12014.21 78.660 280.447 8681.42 8727.87 3259.31 S 6361.99 W 5957491.04 N 685261.71 E 3.078 6842.60 12048.52 78.920 281.448 8688.09 8734.54 3252.92 S 6395.03 W 5957496.59 N 685228.52 E 2.960 6873.97 12079.64 79.920 279.330 8693.80 8740.25 3247.40 S 6425.12 W 5957501.34 N 685198.30 E 7.422 6902.58 12107.31 80.980 278.957 8698.39 8744.84 3243.06 S 6452.06 W 5957504.99 N 685171.26 E 4.055 6928.31 12137.83 83.220 275.704 8702.59 8749.04 3239.21 S 6482.04 W 5957508.07 N 685141.19 E 12.857 6957.11 12168.19 83.710 274.702 8706.05 8752.50 3236.48 S 6512.08 W 5957510.04 N 685111.10 E 3.655 6986.18 12201.17 84.150 274.829 8709.53 8755.98 3233.75 S 6544.76 W 5957511.93 N 685078.36 E 1.388 7017.84 12235.12 86.490 274.211 8712.30 8758.75 3231.08 S 6578.49 W 5957513.74 N 685044.57 E 7.127 7050.55 ~> 12266.38 87.350 273.652 8713.98 8760.43 3228.94 S 6609.63 W 5957515.09 N 685013.38 E 3.280 7080.81 12294.96 88.030 271.302 8715.13 8761.58 3227.71 S 6638.16 W 5957515.59 N 684984.83 E 8.553 7108.65 12328.63 87.720 266.679 8716.38 8762.83 3228.30 S 6671.79 W 5957514.14 N 684951.23 E 13.752 7141.85 12358.95 88.890 262.473 8717.28 8763.73 3231.17 S 6701.95 W 5957510.51 N 684921.15 E 14.393 7172.04 12385.75 90.370 258.924 8717.45 8763.90 3235.50 S 6728.39 W 5957505.51 N 684894.82 E 14.347 7198.83 12422.81 92.650 254.379 8716.48 8762.93 3244.05 S 6764.43 W 5957496.04 N 684859.02 E 13.716 7235.81 12452.94 90.920 253.078 8715.54 8761.99 3252.49 S 6793.34 W 5957486.87 N 684830.34 E 7.183 7265.76 12480.94 91.480 253.655 8714.95 8761.40 3260.50 S 6820.16 W 5957478.18 N 684803.73 E 2.871 7293.58 2 January, 2003 - 11:19 Page 20f4 DrillQuest 3.03.02_004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18. 18-05A MWD Your Ref: 500292158301 Job No. AKMW22191, BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12574.89 90.250 253.146 8713.53 8759.98 3287.33 S 6910.18 W 5957449.05 N 684714.42 E 1.417 7386.96 12669.21 90.490 253.355 8712.92 8759.37 3314.52 S 7000.50 W 5957419.58 N 684624.82 E 0.337 7480.68 12762.86 90.740 253.810 8711.92 8758.37 3340.98 S 7090.32 W 5957390.83 N 684535.70 E 0.554 7573.79 12856.62 91.410 254.304 8710.16 8756.61 3366.73 S 7180.46 W 5957362.79 N 684446.25 E 0.888 7667.08 12951.11 92.220 254.199 8707.17 8753.62 3392.37 S 7271.36 W 5957334.85 N 684356.04 E 0.864 7761.10 13043.41 90.180 255.180 8705.23 8751.68 3416.73 S 7360.36 W 5957308.23 N 684267.69 E 7853.02 ~ 2.452 13137.32 90.860 255.573 8704.38 8750.83 3440.44 S 7451.22 W 5957282.21 N 684177.46 E 0.836 7946.66 13230.81 90.250 257.139 8703.48 8749.93 3462.49 S 7542.06 W 5957257.85 N 684087.20 E 1.798 8039.98 13324.47 86.980 258.534 8705.74 8752.19 3482.22 S 7633.58 W 5957235.80 N 683996.22 E 3.796 8133.55 13417.90 88.090 259.825 8709.76 8756.21 3499.74 S 7725.26 W 5957215.95 N 683905.02 E 1.821 8226.89 13512.03 87.970 258.568 8712.99 8759.44 3517.37 S 7817.67 W 5957195.96 N 683813.09 E 1.341 8320.96 13584.66 88.030 259.095 8715.53 8761.98 3531.43 S 7888.88 W 5957180.09 N 683742.26 E 0.730 8393.54 13656.00 88.030 258.210 8717.98 8764.43 3545.46 S 7958.78 W 5957164.29 N 683672.74 E 1.240 8464.82 Projected Survey 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 259.690° (True). Magnetic Declination at Surface is 26.151 0(04-Dec-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 13656.00ft., The Bottom Hole Displacement is 8712.78ft., in the Direction of 245.988° (True). ~' 2 January, 2003 - 11:19 Page 3 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 18 - 18-05A MWD Your Ref: 500292158301 Job No. AKMW22191, BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11537.45 11604.00 13656.00 8613.37 8630.48 8764.43 3177.70 S 3209.16 S 3545.46 S 5920.87 W 5976.96 W 7958.78 W Tie-in Point Window Point Projected Survey "-'" Survey tool program for 18-05A MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 11537.45 0.00 11537.45 8613.37 13656.00 8613.37 AK-3 BP _HM - BP High Accuracy Magnetic(18-05) 8764.43 MWD Magnetic(18-05A MWD) .~ 2 January, 2003 - 11:19 Page 4 of4 DrillQuest 3.03.02.004 ') ~u~iŒ illJ~ ~i%~æ / I / TONY KNOWLES, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Sr. Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 18-05A BP Exploration (Alaska), Inc. Permit No: 202-219 Surface Location: 951' SNL, 221' WEL, Sec. 24, TIIN, RI4E, UM Bottomhole Location: 4522' SNL, 2894' WEL, Sec. 23, TIIN, RI4E, UM Dear Mr. Isaacson, Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative. Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~t/"~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 4¿.~day of November, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 6" -, STATE OF ALASKA ," ALASKA t. )AND GAS CONSERVATION COMMI-- ,,)ON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 49.30' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028307 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number . 18-05A / 9. Approximate spud date 12/01/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13656' MD / 8779' TVD 0 17. Anticipated pressure {s~O MC 25.035 (e) (2)} 90 Maximum surface 2420 psig, At total depth (TVD) 8800' / 3300 psig Setting Depth T OD Bottom Quantity of Cement Lenath MD TVD MD TVD (include staae data) 3756' 9900' 80851 136561 8779' 244 sx Class 'G' /' yJcA- iI/I'8!O'L /Yll4$ I'/If~ 10 L 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 951' SNL, 221' WEL, SEC. 24, T11N, R14E, UM At top of productive interval 4200' SNL, 1684' WEL, SEC. 23, T11 N, R14E, UM At total depth 4522' SNL, 2894' WEL, SEC. 23, T11 N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028306, 2386' MD 02-17A is 41S' away at 11735' 16. To be completed for deviated wells Kick Off Depth 11600' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade CouDlina 4-1/2" 12.6# L-80 IBT-M 11. Type Bond (See 20 AAC 25.025) Nùmber 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Su rface Intermediate Production Liner Slotted Liner 13444 feet 8849 feet 12965 feet 8802 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 110' 20" 2974' 13-3/8" 10232' 9-5/8" 4581' 7" 556' 4-1/2" 2156# Poleset 3000 sx CS III, 400 sx Class 'GI 110' 30081 110' 2837' 500 sx Class 'G' 10264' 8264' 970 sx Class 'G' (Liner Tieback) 79191 - 125001 6570' - 8774' Uncemented SlotTt F( E 1 V E D24091 - 12965' 8770' - 8799' Perforation depth: measured Slotted Section: 12501' - 12953' Open Hole Section: 12965' - 13444' true vertical Slotted Section: 8774' - 8798' AI ska Oil & Gas Cons. Gommissior Open Hole Section: 8799' - 8849' a Anchoraae II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements NOV 1 2 2002 20. Attachments Contact Engineer Name/Number: Dave Wesley, 564-5773 21. I hereby certify that tü foregoi~g is true, and correct to the best of my ~nowl~~ge . Signed Bill Isaacson 1 L ~ ~ - - Title Semor Dnlhng Engineer . '. . ~, - ,w"" Prepared By Name/Number: Terrie Hubble, 564-4628 Date \\/1/07. Permit Number 202.- 2- ì 9 Conditions of Approval: API Number 50- 029-21583-01 Samples Required 0 Yes .81 No Hydrogen Sulfide Measures iii Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: Tec.;t 'toPE 10 ~S-OO r~e' . ORIGINAl SIGNEDB~Qmmis~iQner ML.t8 ""; "',.; . App.roval f3.ate See cover letter , i I~lo ¡o;;. for other reauirements Mud Log Required 0 Yes 18 No Directional Survey Required BI Yes 0 No D4K D5K D10K D15K 0 3.5K psi for CTU Approved By Form 10-401 Rev. 12-01-85 by order of the commission " ,. Date II ::it (P O-;). Sl bmit I Triplicate ) ) Mud Program Production Mud Properties: Flo-Pro Density (ppg)/ LSRV PV 8.5 - 8.6 -35,000 7 - 11 YP 20 - 27 1 6" hole section LSYP 4-8 I MBT <6 pH 9.0 - 9.5 API FI 4-6 Logging Program Open Hole: Cased Hole: Sample Catchers - Two, at Company man call out MWD Dir/GRlRes- Real time GRlRes throughout entire interval; Recorded Den/Neu through entire interval. None None 6" Production: Drilling: Cement Program CasinA Size 141/2", 12.6#, L-80 Production Liner Basis: Lead: None Tail: Based on -82' of 4-1/2" shoe track, 2,056' of 6" open hole, with 30% excess, and 500' of 4 %" x 7" liner lap. / Tail TOC: -11,100' MD (-8,500'TVD) - 500' liner lap. Fluid Sequence & Volumes: Pre 10bbls CW1 00 Flush Spacer Lead Tail 25bbls MudPUSH at 9.5ppg None ~ 51 bbl/286 fe I ~ks of Dowell 'G' at 15.8 ppg and 1.17 cf/sk, BHST -1 WF 18-05A Sidetrack Page 2 ) ) Well Control / Well control equipment consisting of 5000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: 'GK' Hydril 3 %" X 6" (variable pipe upper) Blind Shear ram 2 7/8" X 5" (variable pipe lower) + DRIP PAN RIG FLOOR I A A A A A A A y -.- y -.- r ~ HYDRIL SIN H67879 ~ -¡;- '-- .) , r ~ I I A DBL GATE 3112"X 6"VARIABLEI TOP FLANGED PIPE RAM: 13" BORE yy SIN R4683 ~ SHEAR BLIND RAM: 135/8" BORE --L: y ROTTOM !=>TI InnFn -.- ~ MUD ~ CROSS y I I / ~ DBL STUD 2 7/8" X 5" VARIABLE SINGLE PIPE RAM y y SIN 2714 A y -.- [ MUD CROSS ~ l y y ~ ~ TBGSPOOL ~ ~ I \ BASE FLANGE I ( y y -.- GROUND LEVEL 18-05A Sidetrack Page 3 ) ") Based upon calculations below, BOP equipment will be tested to 3500 psi. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- . Maximum anticipated BHP: -3300 psi @ 8800' TVDss - Z1 . Maximum surface pressure: -2420 psi @ surface ~ (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: . Planned completion fluid: /' 3500 psi 8.6 ppg seawater /7.2 ppg Diesel . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Formation Markers Formation Tops (W p#7) MD TVDss Comments CM1 THRZ BHRZ T JA I TOP KINGAK A SAG RIVER 10020 8097 TSHU I TOP SHUBLIK TSAD I TZ4B UPPER 10255 8211 TCGL 10717 8356 BCGL I TZ2 11070 8443 TZ2A 11705 8608 Est. Pore Pressure 3300psi (-7 .2ppg EMW) ~.~ TZ18 11887 8650 TZ1A 12214 8705 BSAD 13656 8730 TD Criteria: TD will be as planned, at the end of the target polygon. 18-05A Sidetrack Page 4 ) ') Sidetrack and Complete Procedure Summary Ria Oøerations: 1. MI/RU Nabors Rig 2ES. 2. Circulate out freeze protection and displace well to seaw~er. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. /' 4. Pull 5 Y2" X 4Y2" X 3 Y2" tubing from the pre-rig tubing cut at -11,625' MD. POOH LID completion. 5. M/U 6" milling BHA and P/U 4" drill pipe. RIH and drift down to the remaining tubing stump. Displace the well to milling fluid. POOH. ,r 6. P/U and RIH with 7" Baker bottom-trip anchor whip stock assembly. Orien~hip stock, as desired, and set on tubing stump. Mill window in 7", 29.0# casing at :!: 11,600' MD, plus an additional -20' formation. Pull up into 7" casing and conduct an FIT to 10.0ppg EMW. POOH. /" 7. RIH with 6" Dir/GR/Res/Den/Neu assembly. Kick off and drill the 6" section to planned TO of 13,656' -' MD. POOH. r 8. Run and cement a 4 Y2", 12.6#, L-80 pr9duction liner. POOH. 9. R/U and RIH with Halliburton 2 Y2" dpc perforating guns. Perforate per Halliburton recommendation. POOH. /' 10. Run a 4 Y2", 12.6#, L-80 completion, stinging into the 4 Y2" liner tie back sleeve. 11. Set packer and test the tubing and annulus to 3,500psi for 30 minutes. ,- 12. Nipple down the BOPE. Nipple up and test the tree to 5,000psi. 13. Freeze protect the well to -2,200' and secure the well. 14. Rig down and move off. Post-Ria Work: 1. MIRU slick line. Pull the ball and rod 1 RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Estimated Pre-rig Start Date: 11/15/02 Estimated Spud Date: 12101/02 18-05A Sidetrack Page 5 ') ) > Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whip stock Sidetracks" RP 1Jrw\ ~...,..,'lrr\_;1. .;~~I,lI:Th-W-"'iA.. ~-.~';;;I,~'~""'lIm'II\''''I', "i,.~,....~«(I~-:.,~ Job 7: Drill 6" Production Hole Hazards and Contingencies > There are several anticipated fault crossings while drilling 18-05A. These are all of relatively small throw, -15 feet. Historically, these have not been sources of significant lost circulation. They are deemed a low risk. > During the drilling of the original well, 18-05, there was a lost circulation event at (-11,425' MD, -8,587' TVD). This area is above the proposed kickoff point for the planned sidetrack. ~ Some surrounding area wells have experienced lost circulation, so due awareness and preparation will be prudent. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" ""';II,-,~..'I.,..r'¡;J"¡rn""O:I¡,,~,,,',:t Job 9: Install 4Y2" Production Liner Hazards and Contingencies > The completion design is to run a 4 ~" L-80 liner throughout the production interval. > Differential sticking is a concern. The 8.6ppg Flo-Pro will be -600psi over balanced to the /' Ivishak formation. Minimize the time the pipe is left stationary while running the liner. > Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. > Sufficient 4 ~" liner will be run to extend -1,700' back up into the 7" liner. This will place the tubing tail, with 'X' and 'XN' profiles, above the high inclination section of the original well bore. Reference RP .:. "Modified Conventional Liner Cementing" RP 18-05A Sidetrack Page 7 Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move onto 18-05. However, 18-04 is 120' to the South and 18-27 is 60' to the North. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters will be used at all times. ~ DS-18 is not designated as an H2S site. Standard Operating Procedures for H2S precautions should, however, be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: 18-27B 0 ppm 15-11 4 ppm 18-04B 8 ppm 02-30A 0 ppm The maximum level recorded of H2S on the pad was 50 ppm,. in 02/2001. ~. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies ~ The slotted liner interval and open hole section of this well should be isolated by 2 barriers (the cement plug and the seawater). Prior to pulling the tree, verify a static column of seawater to surface and that no pressure exists. If necessary, shoot a fluid level prior to rig MIRU. ~ Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. ~ The existing wellhead is an FMC Generation III and has a tubing hanger with 5 3/4" RH ACME landing thread. Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP '.r--, -.-. ,,'-.w,- .1<". -.<.- '"- Job 3: Run Whipstock Hazards and Contingencies ~ A 7" whip stock will be run and set in the existing 7" drilling liner. 18-05A Sidetrack Page 6 } ) Job 12: Run ComDletion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP +:+ "Completion Design and Running" RP +:+ "Tubing connections" RP .~~ " ,~,,¥'\""-,,\, . ,fl., ~<q"--\~Æ"~~"'''?II: Job 13: ND/NU/Release Ria Hazards and Contingencies ~ There are no close proximity surface issues. However, identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig away from the well and about the pad. Reference RP +:+ "Freeze Protecting an Inner Annulus" RP 18-05A Sidetrack Page 8 ò COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Depth Fm Depth To SurveylPlan Plan: 18-05A WflJ7 (18-05/P1an 18-05A) BP Amoco Co-ordinate (NÆ) Referenoc: Wen Ceme: 1~5, True North Vertìcal(lVD) Refermce: 4930' 49.30 Section (VS) Reference: Slot - 05 (O.OON,O.OOE) Measured Depth Reference: 4930' 49.30 Cakolation Method: MiniJmm CurvaIore Tool OeatedBy: Ken Allen Glecked: Date: 912412002 Calculation Method: Minimun CurvaIun> ~ ~.J:,~ ~';'W~~North Enor Surf"",,: Elliptical + Casing WarnÎtJ.( MðIhod: Rules Buod 11600.00 13656.14 Planned: 18-05A wp07 V5 MWD Date: Reviewed: Date: WELL DETAILS Name +NI-S +EI-W Northing Eæting Latitude Longitude Slol 18-05 1698.98 -1.57 5960911.44 691538.57 7001T51.962N 148"26'55.6OOW 05 TARGET DETAILS lVD +N/-S +EI-W NŒIbing Eæting Shape 684881.00 Polygou 684367.00 Point 685150.00 Polygon 683680.00 Point 684125.00 Polygon 683872.00 Polygon 685192.00 Polygon Name 18-D5A T1 1~5A 12 18-05A Poly 1~5A 1'3 1~5A Fau1t2 1~5A FaulI3 1~5A Faultl 876430 -3245.84 -6742.87 5957495.00 876430 -3416.69 -7261.43 5957310.99 876430 -3039.75 -646852 5957708.00 877930 -3566.14 -7952.50 5957143.99 877930 -339753 -7503.03 5957323.99 878030 -3402.07 -7756.24 5957312.99 884530 -2905.86 -6423.09 5957843.00 SECTION DETAILS See MD Inc Azi TVD +N/-S +Fl-W DLeg TFace VSec Target 1 11600.00 75.34 240.65 8631.60 -3205.91 -5971.19 0.00 0.00 6760.22 2 11620.00 75.56 243.12 8636.62 -3215.03 -5988.26 12.00 85.00 6779.53 3 12015.94 79.89 283.45 8724.23 -3258.11 -6363.89 10.00 88.46 7139.90 4 12078.91 79.89 283.45 8735.29 -3243.70 -6424.18 0.00 0.00 7189.02 5 12402.40 90.00 256.00 8764.30 -3245.84 -6742.87 9.00 -71.33 7480.69 18-05A Tl 6 12510.19 90.33 249.54 8763.99 -3277.75 -6845.78 6.00 -87.06 7587.64 ~ 7 12738.85 90.33 249.54 8762.67 -3357.68 -7060.01 0.00 0.00 7815.82 8 12948.93 88.78 257.80 8764.30 -3416.69 -7261.43 4.00 100.65 8023.75 18-05A T2 9 13656.14 88.78 257.80 8779.30 -3566.14 -7952.50 0.00 0.00 8715.48 18-05A T3 FORMATION TOP DETAILS All TVD depths are ssTVD plus 49.3'for RKBE. No. TVDPath MDPath Fonnation 1 2 3 8492.30 11068.88 TZ2 8699.30 11887.43 TZlB 8754.30 12213.83 TZIA CASING DETAILS No. TVD MD Name Size 8779.36 13656.13 41/2" 4_500 .."" ..~ , + ,~ ~ 'J"~ /' " 8400- J .--", . . 11600' MD, 8"L<ITVD , SOrt Do< 12/100 . , 8'" 62'TVD 'TVD . 13656-I< MD, 87193 TVD - ~ ''''00 IMOO , 11620 MD, . &d Do< oI20IS.94' MD07s~~~, "'''''TVD 37VD &dIM ,1_93' MD, "64.3' TVD ~ T~. I ~ Start Dir 9/100' : 12. Dir 6/100' : 12402.4' MD, 8764 , TVD 18-OSA T3 ~ J Start 0 19' MD 876~'99 0 ~ - (. . EndDir: 1- 25. 1 . , _. - . ~ 18-05Awp07 Ë ---;;~. , . þ - ../ - -- . .' I--'.¡ . """A_a.,/ 4112. .. 8700 . -_..' -- ,------, "",\, if-T' 8-<l5A 12 18",^."" --, 18-<15 (18-<15) /' ~ ------- n -- mA 18-<I5A TI I : :--~=: _~-~8~~-'~?.-=-::===-~ OM 1M 4/1" , 12738.",' MD. "".6TIVD 9000 6600 6900 7200 7500 7800 8100 Vertical Section at 245.85° [300ft/in] 8400 8700 I 9000 I 9300 bp 0 COMPANY DETAILS REFERENCE INFORMATION Co-ordinato (NÆ) Refercnoe: Wen Como: 18-05, True North VorIica1(1VD) Reforc:nco: 4930' 49.30 Sodion (VS) Refercnoe: Slot - 05 (O.OON,O.OOE) Measured Depth Reference: 4930' 4930 Calculation Method: Mmñmm Curw1uro SURVEY PROGRAM Depth Fm Depth To SurvoylPJan 11600.00 13656.14 PJamod: 18-05A wp07 V5 BP Amoco CeJallation Method: Minimum CtuvaIuro = ~= ~;~¿~indorNorth Enor Surf..,.: ElIiptica1 + Caaíng Waminp: MðIhod: Rul.. Bued CASING DETAILS MD Name Size No. TVD 8779.36 13656.13 41/2" 4.500 See MD 1 2 3 4 5 6 7 8 9 11600.00 75.34 11620.00 75.56 12015.94 79.89 12078.91 79.89 12402.40 90.00 12510.19 90.33 12738.85 90.33 12948.93 88.78 13656.14 88.78 'Y4b " Ñ ,~ ~ -........¿ " ., " All TVD depths are ssTVD plus 49.3'for RKBE. Plan: 18'()5A wp01 (18'()51P1an 18'()5A) Tool Date: 9/24/2002 CreatedBy: Ken Allen Oleeked: Date: MWD Reviewed: Date: WEIL DETA1I.S Name +NI-S 18-05 1698.98 Nonhing Latìtudo Longitude Slot +EI-W Easting -1.57 5960911.44 691538.57 7001T51.962N 148"26'55.600W 05 Ine TARGET DETAILS Name 1VD +W-S +EI.W Northing Eastiug Shape 18-05A T1 8764.30 -3245.84 -674287 5957495.00 684881.00 Polygon 18-05A 1'2 8764.30 -3416.69 -7261.43 5957310.99 684367.00 Point :~1!;31y 8764.30 -3039.75 -6468.52 5957708.00 685150.00 Polygon 8779.30 -3566.14 -795250 5957143.99 683680.00 Point 18-05A Fault2 8779.30 -3397.53 -7503.03 5957323.99 684125.00 Polygon 18-05A Fault3 878030 -3402.07 -7756.24 5957312.99 683872.00 Polygon 18-05A Fault! 8845.30 -2905.86 -6423.09 5957843-00 685192.00 Polygon SECTION DETAILS Azi TVD +N/-S +E/- W DLeg TFace vSec Target 240.65 8631.60 -3205.91 -5971.19 0.00 0.00 6760.22 243.12 8636.62 -3215.03 -5988.26 ,.-1'1.00 85.00 6779.53 283.45 8724.23 -3258.11 -6363.89 10.00 88.46 7139.90 283.45 8735.29 -3243.70 -6424.18 0.00 0.00 7189.02 256.00 8764.30 -3245.84 -6742.87 9.00 -71.33 7480.69 18-05A Tl 249.54 8763.99 -3277.75 -6845.78 6.00 -87.06 7587.64 .~ 249.54 8762.67 -3357.68 -7060.01 0.00 0.00 7815.82 257.80 8764.30 -3416.69 -7261.43 4.00 100.65 8023.75 18-05A T2 257.80 8779.30 -3566.14 -7952.50 0.00 0.00 8715.48 18-05A T3 FORMATION TOP DETAILS No. TVDPath MDPath Formation t- 18-05A Fault! '1I-05A ""y -1 \ s_'"'~.~ =- End D'. )10.~9' WD, &763.99' -:'VD \ ~ 3300 Start Dn 4/1 '.. 38.85 MD 87.2 6~'TV' "'-.." 875J . j I ð761' 0 - ' ., J ~ 1;J-05<\ r - ~ 18-05AF<I\dt3. .--J:..J~.129o'8.9~M D,87~.3'TV]) . \ ~ - ~ \./" 'g ----~------------- ~ 18-05AFaulQ J- ~ ~ / ~ :"-:=:~. ----------- -- )\ 1t:-05A T2 ~ .. / ~ ----t_A~~=:~AT~____- - - // \ -3600 Is.-O 'A wp07 "rr- ~ :-:::~_TO~WD"~~- \ . / 18,05(111-0')/ \ -3000- -3900 -8100 -7800 -7500 -7200 -6900 -6600 W est( - )/East( + ) [300ft/in] 1 2 3 8492.30 11068.88 TZ2 8699.30 11887.43 TZlB 8754.30 12213.83 TZIA ShIrt )irQ/IOC': 1201R91'MD,~7J".29'\l1) / EruI D' , '2015.~' M', ~ 24.23' TVD -,."..."l -6300 -6000 I -5700 I -5400 ) BP KW A Planning Report MAP ) Company: BP Amoco Field: Prudhoe Bay Site: PB OS 18 Well: 18-05 Wellpath: Pla1118-05A Date: 9/24/2002 Time: 10:11:03 Co-ordinate(NE) Reference: Well: 18-05. True North Vertical (fVD) Reference: 49.30' 49.3 Section (VS) Reference: Well (O.00N,O.00E,245.85Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Page: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 PB OS 18 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5959213.15 ft 691583.44 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 35.252 N 148 26 55.555 W True 1.46 deg 18-05 18-05 Well Position: Slot Name: 05 70 17 51.962 N 148 26 55.600 W Well: +N/-S 1698.98 ft Northing: 5960911.44 ft +EI-W -1.57 ft Easting: 691538.57 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan 18-05A Plan: 18-05A wp07 Date Composed: Version: Tied-to: 18-05 11600.00 ft Mean Sea Level 26.24 deg 80.84 deg Direction deg 245.85 9/23/2002 5 From: Definitive Path Current Datum: Magnetic Data: Field Strength: Vertical Section: 49.30' 9/3/2002 57545 nT Depth From (TVD) ft 0.00 Height 49.30 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Principal: Yes Casing Points MD TVD Diameter Hole Size Name ft ft in in 13656.13 8779.36 4.500 6.000 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft de~ deg 11068.88 8492.30 TZ2 0.00 0.00 11887.43 8699.30 TZ1B 0.00 0.00 12213.83 8754.30 TZ1A 0.00 0.00 0.00 BSAD 0.00 0.00 Targets Map Map <- Latitude --> <- Longitude --> Name Description TVD +N/-S +EI-W Northing Easting Deg Min Sec Deg.Min See Dip. Dir. ft ft ft ft ft 18-05A T1 8764.30 -3245.84 -6742.87 5957495.00 684881.00 70 17 20.009 N 148 30 12.069 W 18-05A T2 8764.30 -3416.69 -7261.43 5957310.99 684367.00 70 17 18.324 N 148 30 27.174 W 18-05A Poly 8764.30 -3039.75 -6468.52 5957708.00 685150.00 70 17 22.038 N 148 30 4.080 W -Polygon 1 8764.30 -3039.75 -6468.52 5957708.00 685150.00 70 17 22.038 N 148 30 4.080 W -Polygon 2 8764.30 -3069.06 -6731.37 5957672.00 684888.00 70 17 21.748 N 148 30 11.739 W -Polygon 3 8764.30 -3287.80 -7451.22 5957435.00 684174.00 70 17 19.590 N 148 30 32.707 W -Polygon 4 8764.30 -3446.89 -8038.50 5957261.00 683591.00 70 17 18.019 N 148 30 49.814 W -Polygon 5 8764.30 -3726.49 -8097.65 5956980.00 683539.00 70 17 15.269 N 148 30 51.529 W -Polygon 6 8764.30 -3596.29 -7319.03 5957129.99 684314.00 70 17 16.557 N 148 30 28.847 W -Polygon 7 8764.30 -3530.17 -6930.20 5957206.00 684701.00 70 17 17.211 N 148 30 17.520 W -Polygon 8 8764.30 -3402.26 -6610.81 5957342.00 685017.01 70 17 18.472 N 148 30 8.217 W ) BP KW A Planning Report MAP ') Company: BP Amoco Field: Prudhoe Bay Site: PB OS 18 Well: 18-05 Well path: Plan 18-05A Date: 9/24/2002 Time: 10:11:03 Co-ordinate(NE} Reference: Well: 18-05, True North Vertical (TVD) Reference: 49.30' 49.3 Section (VS) Reference: Well (0.00N,O.00E,245.85Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Page: 2 Targets Map Map <-- Latitude ---> <-- LongitQde -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec DegMin See Dip. Dir. ft ft ft ft ft -Polygon 9 8764.30 -3331.51 -6403.93 5957417.99 685222.00 70 17 19.170 N 148 30 2.191 W 18-05A T3 8779.30 -3566.14 -7952.50 5957143.99 683680.00 70 17 16.848 N 148 30 47.305 W 18-05A Fault2 8779.30 -3397.53 -7503.03 5957323.99 684125.00 70 17 18.510 N 148 30 34.214 W -Polygon 1 8779.30 -3397.53 -7503.03 5957323.99 684125.00 70 17 18.510 N 148 30 34.214 W -Polygon 2 8779.30 -3703.43 -7354.77 5957021.99 684281.00 70 17 15.503 N 148 30 29.8B5 W 18-05A Fault3 8780.30 -3402.07 -7756.24 5957312.99 683872.00 70 17 18.463 N 148 30 41.591 W -Polygon 1 8780.30 -3402.07 -7756.24 5957312.99 683872.00 70 17 18.463 N 148 30 41.591 W -Polygon 2 8780.30 -3910.50 -7747.19 5956804.99 683894.01 70 17 13.463 N 148 30 41.312 W 18-05A F ault1 8845.30 -2905.86 -6423.09 5957843.00 685192.00 70 17 23.356 N 148 30 2.760 W -Polygon 1 8845.30 -2905.86 -6423.09 5957843.00 685192.00 70 17 23.356 N 148 30 2.760 W -Polygon 2 8845.30 -3721.79 -6241.82 5957032.00 685394.00 70 17 15.333 N 148 29 57.458 W Plan Section Information MD Incl Azim TVD +N/-S +EI-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10OO deg/100ft deg/1 DOft deg 11600.00 75.34 240.65 8631.60 -3205.91 -5971.19 0.00 0.00 0.00 0.00 11620.00 75.56 243.12 8636.62 -3215.03 -5988.26 12.00 1.11 12.34 85.00 12015.94 79.89 283.45 8724.23 -3258.11 -6363.89 10.00 1.09 10.19 88.46 12078.91 79.89 283.45 8735.29 -3243.70 -6424.18 0.00 0.00 0.00 0.00 12402.40 90.00 256.00 8764.30 -3245.84 -6742.87 9.00 3.12 -8.49 -71.33 18-05A T1 12510.19 90.33 249.54 8763.99 -3277.75 -6845.78 6.00 0.31 -5.99 -87.06 12738.85 90.33 249.54 8762.67 -3357.68 -7060.01 0.00 0.00 0.00 0.00 12948.93 88.78 257.80 8764.30 -3416.69 -7261.43 4.00 -0.74 3.93 100.65 18-05A T2 13656.14 88.78 257.80 8779.30 -3566.14 -7952.50 0.00 0.00 0.00 0.00 18-05A T3 Survey MD loci ADm TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 OOft . 11068.88 75.91 238.90 8492.30 8443.00 5957826.78 686085.47 6251.09 0.00 TZ2 11600.00 75.34 240.65 8631.60 8582.30 5957554.58 685651.38 6760.22 0.34 Start Dir 12/100': 11600' MD, 11620.00 75.56 243.12 8636.62 8587.32 5957545.02 685634.54 6779.53 12.00 Start Dir 10/100': 11620' MD, 11650.00 75.67 246.22 8644.08 8594.78 5957531.93 685608.61 6808.58 10.00 MWD 11700.00 75.92 251.37 8656.36 8607.06 5957513.26 685563.90 6856.97 10.00 MWD 11750.00 76.29 256.50 8668.37 8619.07 5957498.65 685517 .64 6905.00 10.00 MWD 11800.00 76.76 261.62 8680.03 8630.73 5957488.22 685470.17 6952.32 10.00 MWD 11850.00 77.33 266.72 8691.25 8641.95 5957482.04 685421.85 6998.56 10.00 MWD 11887.43 77.82 270.52 8699.30 8650.00 5957480.23 685385.35 7032.26 10.00 TZ1B 11900.00 78.00 271.79 8701.93 8652.63 5957480.16 685373.06 7043.37 10.00 MWD 11950.00 78.76 276.84 8712.01 8662.71 5957482.60 685324.17 7086.41 10.00 MWD 12000.00 79.61 281.85 8721.40 8672.10 5957489.34 685275.54 7127.35 10.00 MWD 12015.94 79.89 283.45 8724.23 8674.93 5957492.39 685260.16 7139.90 10.00 End Dir : 12015.94' MD, 8724. 12078.91 79.89 283.45 8735.29 8685.99 5957505.26 685199.52 7189.02 0.00 Start Dir 9/100' : 12078.91' M 12100.00 80.50 281.62 8738.88 8689.58 5957509.25 685179.13 7205.68 9.00 MWD 12150.00 81.99 277 .33 8746.49 8697.19 5957516.14 685130.21 7246.82 9.00 MWD 12200.00 83.53 273.06 8752.79 8703.49 5957519.36 685080.73 7290.05 9.00 MWD 12213.83 83.96 271.89 8754.30 8705.00 5957519.61 685066.98 7302.34 9.00 TZ1A 12250.00 85.09 268.82 8757.75 8708.45 5957518.91 685030.99 7335.09 9.00 MWD 12300.00 86.69 264.60 8761.34 8712.04 5957514.79 684981.31 7381.68 9.00 MWD 12350.00 88.30 260.40 8763.52 8714.22 5957507.01 684931.98 7429.53 9.00 MWD 12402.40 90.00 256.00 8764.30 8715.00 5957495.00 684881.00 7480.69 9.00 18-05A T1 12450.00 90.15 253.15 8764.24 8714.94 5957481.17 684835.46 7527.74 6.00 MWD 12500.00 90.30 250.15 8764.04 8714.74 5957464.23 684788.43 7577.48 6.00 MWD ) BP ') KW A Planning Report MAP Company: BP Amoco Date: 9/24/2002 Time: 10:11:03 Page: 3 Field: Prudhoe Bay Co~ordinate(NE) Reference: Well: 18~05. True North Site: PB OS 18 Vertical (fVD) Reference: 49.30' 49.3 Well: 18-05 Section (VS) Reference: Well (0.00N,O.00E,245.85Azi) Wellpath: Plan 18-05.A Suney Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS 'r ool/Comment ft deg deg ft ft ft ft ft deg/1 OOft 12510.19 90.33 249.54 8763.99 8714.69 5957460.47 684778.95 7587.64 6.00 End Dir : 12510.19' MD, 8763. 12600.00 90.33 249.54 8763.47 8714.17 5957426.95 684695.64 7677.26 0.00 MWD 12700.00 90.33 249.54 8762.89 8713.59 5957389.62 684602.88 7777.05 0.00 MWD 12738.85 90.33 249.54 8762.67 8713.37 5957375.12 684566.84 7815.82 0.00 Start Dir 4/100' : 12738.85' M 12800.00 89.88 251.94 8762.56 8713.26 5957353.49 684509.65 7876.74 4.00 MWD 12900.00 89.14 255.88 8763.41 8714.11 5957323.34 684414.34 7975.73 4.00 MWD 12948.93 88.78 257.80 8764.30 8715.00 5957310.99 684367.00 8023.75 4.00 18~05A T2 13000.00 88.78 257.80 8765.39 8716.09 5957298.94 684317.39 8073.71 0.00 MWD 13100.00 88.78 257.80 8767.52 8718.22 5957275.33 684220.25 8171.52 0.00 MWD 13200.00 88.78 257.80 8769.65 8720.35 5957251.72 684123.11 8269.33 0.00 MWD 13300.00 88.78 257.80 8771.77 8722.47 5957228.11 684025.96 8367.13 0.00 MWD 13400.00 88.78 257.80 8773.90 8724.60 5957204.50 683928.82 8464.94 0.00 MWD 13500.00 88.78 257.80 8776.03 8726.73 5957180.89 683831.67 8562.75 0.00 MWD 13600.00 88.78 257.80 8778.16 8728.86 5957157.28 683734.53 8660.56 0.00 MWD 13656.13 88.78 257.80 8779.36 8730.06 5957144.02 683680.00 8715.46 0.00 18~05A T3 13656.12 88.78 257.80 8779.36 8730.06 5957144.03 683680.01 8715.45 0.00 Total Depth: 13656.14' MD, 87 13656.14 88.78 257.80 8779.30 8730.00 5957143.99 683680.00 8715.48 0.00 MWD WELL DETAILS ANTI-COLLISION SETIINGS Interpolation Method:MD Interval: 25.00 Depth Range From: 11600.00 To: 13656.14 Maximum Range: 1562.28 Reference: Plan: 18-05A wp07 COMPANY DETAILS Name +N/.S +EI-W Nolthing 18-05 1698.98 -1.57 5960911.44 -128 -120 -100 -80 -60 -40 -20 -0 270 -20 -40 --60 -80 -100 -120 -128 Easting Latitude Longitude Slot BP Amoco Calculation Method: Mminmn Curvature Error System: ISCWSA Scan MedJod: Tmv Cylinder North mor Surlàce: EIIiptic;al + Casing Waming Method: Rules Based 691538.57 70"17'51.962N 148"26'55.6OOW 05 18-05 (plan#105 18-05A) ì.. I - From 0 300 600 900 1200 1500 2000 2500 3000 - 3500 4000 4500 5000 0 6000 8000 II 000 12000 See "'Win] 1 11600.00 75.34 240.65 2 11620.00 75.56 243.12 3 12015.94 7\ 89 283.45 4 1207891 79.89 283.45 5 12402.40 90.00 256.00 6 12510.19 90.33 249.54 7 12738.85 90.33 249.54 8 1294893 88.78 257.80 9 13656.14 88.78 257.80 Colour To MD 300 600 900 1200 1500 2000 2500 3000 - 3500 4000 4500 5000 6000 8000 II 000 12000 15000 90 MD Inc A2i SURVEY PROGRAM DepthFm Depth To SurveylPlan 11600.00 13656.14 PIamed: 1~5A wp07 V5 Parent Wellpatb: Tie onMD: Rig: Re£ Damm: V.Seetion ADgle 245.85" - ,," '".'1.". 11'1, 1VI.!l'lrRisk _1'-~1111I-...."'1.!....1'.isk ~ u .".11" I...t. A.L... Risk - 1,.11,-\.,1' <11\, M..!,.orRÏsk - II: '":\ ''': I"il! ""-..II'-rRisk - 1'-.. 11.- Ir-I I\L". ¡risk - 1'11,1 Ihl\.1....,...lcÌ8k - I 11'111 11.", 1'YI..!...rRisk - 1.-1",1,-1 !I\.,....lcisk - 1.-.1"'1 ..:J;~. Mil"' Risk ''''-t''''II-II-, P',/"ll£!',ORS - 1~"I"'IIL.u.UI". 1"-11 o\.),NOERRORS -!"L.ù..!II'o..."\ -1"11"°""""1,..1 SECIlON DETAILS 'IVD +W-S +EI.W DLeg TFaco 8631.60 -3205.91 -5971.19 8636.62 -3215.03 -5988.26 8124.23 -3258.11 -6363.89 8135.29 -3243.70 -6424.18 8764.30 -3245.84 -6742.81 8163.99 -3277.75 -6845.78 8162.67 -3357.68 .7060.01 8764.30 -3416.69 -7261.43 8779.30 -3566.14 -7952.50 0.00 0.00 12.00 85.00 10.00 88.46 0.00 0.00 9.00 .71.33 6.00 -87.06 0.00 0.00 4.00 100.65 0.00 0.00 Tool MWD WELLPA 1H DETAILS Plan 1~5A 18-05 11600.00 49.30' 49.300 Origin Origin +N/-S +FJ-W Starting From TVD 0.00 0.00 0.00 LEGEND ......., .~ VSee Target 6760.22 6779.53 7139.90 7189.02 7480-69 18-05A TI 7581.64 7815.82 8023.75 18-05A 1'2 8115.48 I8-0SA 1"3 Nome +NI-S 1 W5 1698.98 250 200 ~ ¡:: ~ 0 lr) \-....I ¡:: 0 .~ ~ [f r/J Q) ~ U 0 - Q) ~ U 150 100 50 0:/ WELL DETAILS +fY-W Northing Eastiq¡ Latitude Longitude Slot 691538.57 70"1T51.962N 148"26'55.600W 05 -157 5960911.44 ~'" 1 3-05 -- Lqiva~t MagrJCic JS-.anCC KOP 11600' MD from 18-05. 12000 12500 \ \ \ ANTI-COlLISION SETIINGS Interpolation Method:MD InIerval: 100.00 Depth Range From: 33.30 To: 13656.14 Maximum Range: 1562.28 Reference: Plan: 18-05A wp07 r'\ l \ I '\ 13000 cor wet platt :.8-05A .i~ \. ,> '\ Measured Depth [500ft/in] 13500 14000 COMPANY DETAILS BP Amxo Calculation Melhod: Minìmun Curvature Error System: ISCWSA Scan Method: Trav eylinda North Error Surface: Elliptical + Casing Warning MeJhod: Rules Based 14500 SURVEY PROGRAM Depth Fro Depth To SurveylPlan 11600.00 13656.14 PIamed: IW5A wp07 V5 Tool MWD WELLPATII DETAILS - WeIIpath: Tie on MD: Plan I8-05A 1W5 11600.00 Rig: Ref. Dotum: 49.30' 49.3011 V.Section Angle 245.85° Origin Origin +W-S +FJ-W Starting From 1VD 0.00 0.00 0.00 LEGEND I; '\ "'-" I:\.' 1'-.1.£1' . Itisk -- II~' ~"''': !II. ""'11.. i..JoJ.. - 1'_' 01'11': 11''\, 11.411." irs.:k - ": "'A.": il''\. 1W....ltÎsk - ": '''A I'L- '''LI' "'t..! I' Ir.isk ~"."," h'''''..II...lr...J,. - 111'1 II''''''..LI--''u - I 11.'\11'-11"-1 M,¡..I(jsk - 1.....1"'1.....:1 .M~I'."'''''' - 1'-..I'II-I_.\..1\.1..11";u~ - 1""-11 11Io...-,N,.i_trICI'ltS -- I.'",i-~II'" 1"_11-'\, NOERRORS - "Lù,II'II.'\ - I,..I'-,,-pl': ........" ...."..,' 15000 1550 SECTION DETAILS So<: MD Jnç Azi 1VD +W-S +FJ-W DLeg 1Face VSec Target 11600.00 75.34 240.65 8631.60 -3205.91 -5971.19 0.00 0-00 676022 11620.00 75.56 243.U 8636.62 -3215.03 -5988.26 12.00 85.00 6179.53 12015.94 79.89 283.45 8724.23 -3258.11 -6363.89 10.00 88.46 7139.90 12078.91 79.89 283.45 8735.29 -3243.70 -6424.18 0.00 0.00 7189.02 12402AO 90_00 256.00 876430 -3245.84 -6742.87 9.00 -71.33 7480.69 18'()5A T1 USIO.19 9(;,33 249.54 8763.99 -3277.75 -6845.78 6.00 -87.06 7587.64 12738.85 9033 249.54 8762.67 -3357.68 -7060.01 0.00 0.00 7815.82 12948.93 88.78 257.9:1 876430 -3416.69 -7261.43 4.00 100.65 9:123.75 18-05A 1'2 13656.14 88.78 257.9:1 877930 -3566.14 -7952.50 0.00 0.00 8715.48 IW5A 1'3 ') BP Anticollision Report '} Company: BP.Amoco Field: Prudhoe Bay Reference Site: PB OS 18 Referençe Well: 18-05 Reference Wellpath: Plan 18-05A Date: 9/24/2002 Time: 09:32:39 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 18-05, True North 49.30' 49.3 Db: Oracle GLOBAL SCAN APPLIED: All weUpaths within 200t+ 100/1000 of reference - There ar~8feUs in thii~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 11600.00 to 13656.14 ft Sean Method: Trav Cylinder North Maximum Radius: 1562.28 ft Error Surface: Ellipse + Casing Survey Program for Definitive W eUpath Date: 9/19/2002 Validated: No Version: 4 Planned From To Survey T oolcode Tool Name ft ft 450.30 11600.00 1 : MWD - Standard (0) MWD MWD - Standard 11600.00 13656.14 Planned: 18-05A wp07 V5 MWD MWD - Standard Casing Points MD TVD Diameter Bole Siz~ Name ft ft in in 13656.13 8779.36 4.500 6.000 41/2" Summary <--------- Offset WeUpath --------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Well path MD MD Distance Area Deviation Warning ft ft ft ft ft PB OS 02 02-17A V2 11735.55 12719.00 417.89 441.35 48.87 Pass: Major Risk PB OS 02 02-30 V1 13109.76 11040.00 1296.60 469.68 830.68 Pass: Major Risk PB OS 02 02-30A V1 Out of range PB OS 02 02-30A V2 Out of range PB OS 02 02-30B VO Plan: 02-30B Out of range PB OS 02 02-36 V2 Out of range PB OS 15 15-11 V2 Out of range PB OS 15 15-11AV3 Out of range PB OS 15 15-42 V4 Out of range PB OS 15 15-42A V1 Out Wgngê'-""") PB OS 18 18-05 V3 11625.28 11625.00 0.68 590.52 -589.85 ¿: Mapr;v PB OS 18 Plan#105 18-05A V1 Pia 13599.49 13700.00 27.43 718.94 -687.86 AIL: Major Ri Site: PB OS 02 _......~_J""''''''''' Well: 02-17A Rule Assigned: Major Risk Wellpath: 02-17A V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TV]) Ref Offset TFO+AZI TFO-BS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11750.00 8668.37 11450.00 8854.99 92.13 58.35 160.21 263.70 7.000 1546.99 466.01 1104.82 Pass 11750.00 8668.37 11475.00 8855.90 92.13 58.36 159.96 263.45 7.000 1527.28 466.08 1085.56 Pass 11750.00 8668.37 11500.00 8856.74 92.13 58.36 159.71 263.20 7.000 1507.60 466.15 1066.35 Pass 11750.00 8668.37 11525.00 8857.47 92.13 58.36 159.45 262.95 7.000 1488.08 466.22 1047.29 Pass 11750.00 8668.37 11550.00 8858.11 92.13 58.37 159.19 262.69 7.000 1468.85 466.09 1028.76 Pass 11750.00 8668.37 11575.00 8858.61 92.13 58.37 158.93 262.43 7.000 1449.85 466.17 1010.23 Pass 11750.00 8668.37 11600.00 8859.16 92.13 58.38 158.66 262.16 7.000 1431.51 466.25 992.41 Pass 11750.00 8668.37 11625.00 8859.75 92.13 58.38 158.38 261.88 7.000 1413.89 466.33 975.33 Pass 11729.72 8663.53 11650.00 8860.33 92.52 55.12 156.51 262.08 7.000 1396.29 450.05 972.50 Pass 11724.80 8662.35 11675.00 8860.92 92.61 54.44 155.82 261.91 7.000 1379.24 446.19 959.01 Pass 11719.76 8661.14 11700.00 8861.34 92.71 53.80 155.13 261.73 7.000 1362.42 442.26 945.60 Pass 11700.00 8656.36 11725.00 8861.41 93.09 51.78 153.30 261.94 7.000 1345.50 426.65 938.62 Pass 11700.00 8656.36 11750.00 8861.28 93.09 51.79 153.02 261.65 7.000 1327.25 426.78 920.52 Pass 11700.00 8656.36 11775.00 8861.20 93.09 51.80 152.74 261.37 7.000 1308.00 426.90 901.45 Pass 11700.00 8656.36 11800.00 8860.93 93.09 51.81 152.46 261.09 7.000 1287.92 427.03 881.53 Pass 11700.00 8656.36 11825.00 8860.29 93.09 51.81 152.20 260.83 7.000 1266.91 426.96 860.86 Pass 11700.00 8656.36 11850.00 8859.31 93.09 51.82 151.96 260.59 7.000 1244.99 427.08 839.06 Pass 11700.00 8656.36 11875.00 8858.21 93.09 51.83 151.73 260.37 7.000 1222.30 427.17 816.52 Pass 11700.00 8656.36 11900.00 8857.13 93.09 51.84 151.51 260.14 7.000 1199.02 427.25 793.38 Pass 11700.00 8656.36 11925.00 8856.24 93.09 51.85 151.28 259.92 7.000 1175.25 427.32 769.78 Pass ') BP Anticollision Report Company: BP Amoco Date: 9/24/2002 Time: 09:32:39 Page: 2 Field: Prudhoe Bay Reference Site: PB OS 18 Co.-ordinate(NE) Reference: Well: 18-05, True North Referençe Well: 18-05 Vertical (TV») Reference: 49.30' 49.3 Reference Wellpath: Plan 18-05A Db: Oracle Site: PB OS 02 Well: 02-17A Rule Assigned: Major Risk Wellpath: 02-17A V2 Inter-Site Error: 0.00 ft Reference Offset SeòÚ-Major Axis Ctr-Ctr No-Go AUowable MD TV» MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance. Area Deviation Warning ft ft ft ft ft ft deg deg In ft ft ft 11700.00 8656.36 11950.00 8855.82 93.09 51.86 151.05 259.68 7.000 1151.12 427.37 745.86 Pass 11700.00 8656.36 11975.00 8856.04 93.09 51.87 150.79 259.42 7.000 1126.80 427.39 721.81 Pass 11700.00 8656.36 12000.00 8856.84 93.09 51.89 150.51 259.14 7.000 1102.42 427.40 697.75 Pass 11700.00 8656.36 12025.00 8857.88 93.09 51.90 150.21 258.84 7.000 1078.06 427.40 673.73 Pass 11700.00 8656.36 12050.00 8858.86 93.09 51.91 149.91 258.54 7.000 1053.71 427.40 649.75 Pass 11700.00 8656.36 12075.00 8859.91 93.09 51.92 149.58 258.21 7.000 1029.42 427.40 625.84 Pass 11700.00 8656.36 12100.00 8861.00 93.09 51.94 149.24 257.88 7.000 1005.15 427.39 601.98 Pass 11700.00 8656.36 12125.00 8861.98 93.09 51.95 148.90 257.53 7.000 980.87 427.38 578.12 Pass 11700.00 8656.36 12150.00 8862.63 93.09 51.96 148.56 257.19 7.000 956.56 427.37 554.23 Pass 11700.00 8656.36 12175.00 8862.88 93.09 51.98 148.22 256.85 7.000 932.18 427.36 530.27 Pass 11700.00 8656.36 12200.00 8862.75 93.09 51.99 147.90 256.53 7.000 907.73 427.33 506.22 Pass 11700.00 8656.36 12225.00 8862.15 93.09 52.01 147.60 256.23 7.000 883.22 427.30 482.09 Pass 11700.00 8656.36 12250.00 8860.98 93.09 52.02 147.32 255.95 7.000 858.62 427.27 457.85 Pass 11700.00 8656.36 12275.00 8859.58 93.09 52.04 147.04 255.67 7.000 834.00 427.24 433.60 Pass 11700.00 8656.36 12300.00 8858.10 93.09 52.06 146.75 255.39 7.000 809.40 427.20 409.37 Pass 11700.00 8656.36 12325.00 8856.87 93.09 52.07 146.44 255.07 7.000 784.88 427.17 385.27 Pass 11700.00 8656.36 12350.00 8855.99 93.09 52.09 146.08 254.71 7.000 760.47 427.13 361.32 Pass 11700.00 8656.36 12375.00 8855.17 93.09 52.11 145.70 254.33 7.000 736.12 427.09 337.48 Pass 11700.00 8656.36 12400.00 8854.16 93.09 52.13 145.31 253.95 7.000 711.80 427.05 313.68 Pass 11700.00 8656.36 12425.00 8853.18 93.09 52.15 144.91 253.55 7.000 687.59 427.00 290.00 Pass 11700.00 8656.36 12450.00 8852.62 93.09 52.16 144.46 253.10 7.000 663.60 426.94 266.63 Pass 11700.00 8656.36 12475.00 8852.78 93.09 52.18 143.93 252.57 7.000 639.96 427.07 243.52 Pass 11700.00 8656.36 12500.00 8853.65 93.09 52.20 143.31 251.95 7.000 616.71 427.01 221.12 Pass 11700.00 8656.36 12525.00 8854.67 93.09 52.22 142.63 251.27 7.000 593.68 426.95 199.01 Pass 11700.00 8656.36 12550.00 8855.77 93.09 52.25 141.89 250.52 7.000 570.82 426.88 177.14 Pass 11713.37 8659.60 12575.00 8856.58 92.83 53.46 142.15 249.41 7.000 547.71 437.30 155.31 Pass 11716.84 8660.44 12600.00 8856.88 92.76 53.85 141.63 248.54 7.000 524.75 439.99 133.59 Pass 11720.39 8661.29 12625.00 8857.05 92.70 54.28 141.06 247.59 7.000 501.88 442.76 112.11 Pass 11724.17 8662.20 12650.00 8857.28 92.63 54.77 140.42 246.57 7.000 479.20 445.72 91.04 Pass 11728.13 8663.15 12675.00 8857.67 92.55 55.30 139.68 245.42 7.000 456.77 448.84 70.53 Pass 11732.27 8664.15 12700.00 8858.17 92.47 55.86 138.84 244.16 7.000 434.59 444.62 57.93 Pass 11735.55 8664.93 12719.00 8858.54 92.41 56.32 138.13 243.11 417.89 441.35 48.87 Pass Site: PB OS 02 Well: 02-30 Rule Assigned: Major Risk Wellpath: 02-30 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13014.96 8765.71 10625.00 8848.53 109.21 27.90 165.42 267.62 1545.59 460.41 1085.64 Pass 13020.60 8765.83 10650.00 8865.56 109.29 28.00 164.76 266.96 1528.88 460.92 1068.11 Pass 13026.28 8765.95 10675.00 8882.51 109.38 28.10 164.09 266.29 1512.31 461.44 1050.76 Pass 13032.00 8766.07 10700.00 8899.39 109.46 28.19 163.40 265.60 1495.90 461.95 1033.63 Pass 13037.71 8766.19 10725.00 8916.21 109.55 28.30 162.71 264.91 1479.64 462.48 1016.68 Pass 13043.43 8766.31 10750.00 8933.03 109.63 28.40 161.99 264.19 1463.60 463.01 1000.00 Pass 13049.15 8766.43 10775.00 8949.85 109.72 28.51 161.27 263.47 1447.80 463.55 983.62 Pass 13054.87 8766.56 10800.00 8966.67 109.80 28.61 160.52 262.72 1432.23 464.08 967.53 Pass 13060.59 8766.68 10825.00 8983.49 109.89 28.72 159.76 261.96 1416.91 464.61 951.76 Pass 13066.30 8766.80 10850.00 9000.31 109.98 28.83 158.98 261.18 1401.85 465.15 936.32 Pass 13072.02 8766.92 10875.00 9017.13 110.06 28.93 158.19 260.39 1387.05 465.68 921 .22 Pass 13077.74 8767.04 10900.00 9033.95 110.15 29.04 157.38 259.58 1372.52 466.22 906.47 Pass 13083.46 8767.16 10925.00 9050.76 110.23 29.15 156.55 258.75 1358.27 466.76 892.09 Pass ., BP Anticollision Report Company: BP Amoco Date: 9/24/2002 Time: 09:32:39 Page: 3 Field: Prudhoe Bay Reference Site: PB OS 18 Co-ordinate(NE) Reference: Well: 18-05, True North Referençe Well: 18-05 Vertical (fVD) Reference: 49.30' 49.3 Reference Wellpath: Plan 18-05A Db: Oracle Site: PB OS 02 Well: 02-30 Rule Assigned: Major Risk Wellpath: 02-30 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Cn- No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg In ft ft ft 13089.17 8767.29 10950.00 9067.58 110.32 29.25 155.71 257.91 1344.31 467.29 878.10 Pass 13094.89 8767.41 10975.00 9084.40 110.40 29.36 154.84 257.04 1330.65 467.83 864.50 Pass 13100.61 8767.53 11000.00 9101.22 110.49 29.47 153.96 256.16 1317.30 468.82 850.88 Pass 13106.33 8767.65 11025.00 9118.04 110.58 29.58 153.06 255.26 1304.27 469.36 838.12 Pass 13109.76 8767.72 11040.00 9128.13 110.63 29.64 152.52 254.72 1296.60 469.68 830.68 Pass Site: ~B'DS) 8 Rule Assigned: Major Risk Well: ,18-0,5.'" / Wellpath:{ 18:::~5)\13 Inter-Site Error: 0.00 ft RèrèreíÍée Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TV]) MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11600.30 8631.68 11600.00 8631.38 92.94 92.05 240.69 0.00 7.000 0.00 588.77 -156.35 FAIL ~~Y" \~\. 11625.28 8637.94 11625.00 8637.65 93.22 92.36 152.45 268.78 7.000 0.68 590.52 -589.85 FAIL 11650.14 8644.11 11650.00 8643.83 93.36 92.48 155.75 269.54 7.000 2.53 591.33 -588.87 FAIL ,) yl(/' 11674.79 8650.19 11675.00 8649.91 93.22 92.42 158.57 269.80 7.000 5.50 590.53 -585.08 FAIL \L-- 11699.13 8656.14 11700.00 8655.86 93.09 92.18 161.16 269.89 7.000 9.65 589.17 -579.56 FAIL .~~ 11723.05 8661.93 11725.00 8661.68 92.65 91.79 163.55 269.81 7.000 14.96 586.58 -571.70 FAIL 11746.46 8667.53 11750.00 8667.37 92.20 91.25 165.77 269.63 7.000 21.40 583.32 -562.10 FAIL 11769.30 8672.92 11775.00 8672.92 91.50 90.59 167.87 269.39 7.000 28.93 579.12 -550.52 FAIL 11791.51 8678.08 11800.00 8678.34 90.78 89.81 169.87 269.11 7.000 37.48 574.28 -537.31 FAIL 11813.08 8683.01 11825.00 8683.66 89.90 88.93 171.76 268.81 7.000 46.93 568.90 -522.70 FAIL 11833.97 8687.70 11850.00 8688.87 88.94 87.96 173.58 268.49 7.000 57.24 562.79 -506.52 FAIL 11854.16 8692.16 11875.00 8693.98 87.96 86.92 175.32 268.18 7.000 68.36 557.05 -489.48 FAIL 11873.63 8696.37 11900.00 8698.97 86.82 85.81 177.00 267.88 7.000 80.25 550.44 -470.76 FAIL 7/00 11892.33 8700.33 11925.00 8703.86 85.72 84.64 178.60 267.59 7.000 92.99 543.76 -451.15 FAIL ~"'fí 1.('1 ,). 11910.17 8704.03 11950.00 8708.63 84.54 83.45 180.13 267.31 7.000 ~536.99 -430.58 FAIL ~ 00 11927.16 8707.49 11975.00 8713.29 83.33 82.24 181.59 267.05 7.000 121.18 529.79 -408.76 FAIL @ 11943.29 8710.69 12000.00 8717.84 82.19 81.02 182.97 266.81 7.000 136.52 522.75 -386.29 FAIL 11958.58 8713.67 12025.00 8722.28 80.99 79.82 184.29 266.59 7.000 152.62 515.85 -363.24 FAIL 11973.05 8716.43 12050.00 8726.60 79.79 78.63 185.55 266.39 7.000 169.42 508.69 -339.24 FAIL 11986.72 8718.97 12075.00 8730.80 78.66 77.47 186.74 266.21 7.000 186.88 501.79 -314.86 FAIL 12000.00 8721.40 12100.00 8734.89 77.55 76.30 187.90 266.05 7.000 204.95 494.94 -289.92 FAIL 12011.76 8723.50 12125.00 8738.86 76.49 75.25 188.95 265.92 7.000 223.58 488.64 -264.98 FAIL 12026.29 8726.05 12150.00 8742.70 76.27 75.00 189.38 265.93 7.000 242.64 487.51 -244.78 FAIL 12042.43 8728.88 12175.00 8746.33 76.51 75.21 189.50 266.05 7.000 261.73 488.81 -226.95 FAIL 12058.59 8731.72 12200.00 8749.75 76.76 75.41 189.65 266.20 7.000 280.79 490.10 -209.12 FAIL 12074.75 8734.56 12225.00 8752.95 77.01 75.62 189.82 266.37 7.000 299.85 491.40 -191.29 FAIL 12101.31 8739.09 12250.00 8755.94 79.32 77.85 188.39 266.87 7.000 318.69 504.89 -186.57 FAIL 12134.30 8744.24 12275.00 8758.71 82.47 80.93 186.13 267.46 7.000 336.77 522.80 -187.31 FAIL 12170.89 8749.28 12300.00 8761.26 85.80 84.16 183.54 268.00 7.000 353.94 543.33 -190.17 FAIL 12211.40 8754.04 12325.00 8763.60 89.25 87.50 180.56 268.47 7.000 370.04 564.31 -194.68 FAIL 12256.16 8758.27 12350.00 8765.72 92.72 90.85 177.15 268.84 7.000 384.89 585.22 -200.49 FAIL 12305.36 8761.64 12375.00 8767.62 96.07 94.13 173.25 269.09 7.000 398.31 605.35 -207.07 FAIL 12359.05 8763.77 12400.00 8769.31 99.16 97.18 168.82 269.18 4.500 410.09 623.77 -213.63 FAIL 12412.47 8764.30 12425.00 8770.87 101.58 99.58 164.46 269.06 4.500 420.11 638.24 -218.01 FAIL 12454.44 8764.23 12450.00 8772.30 102.89 100.88 161.76 268.88 4.500 428.92 646.16 -217.09 FAIL 12497.72 8764.06 12475.00 8773.60 104.03 102.03 159.00 268.71 4.500 436.75 652.88 -215.95 FAIL 12527.37 8763.89 12500.00 8774.79 104.56 102.55 158.09 268.55 4.500 443.84 656.34 -212.29 FAIL 12551.32 8763.75 12525.00 8775.85 104.89 102.88 157.97 268.42 4.500 450.94 658.22 -207.03 FAIL 12575.25 8763.61 12550.00 8776.79 105.22 103.20 157.85 268.31 4.500 458.11 660.10 -201.70 FAIL 12599.17 8763.47 12575.00 8777.61 105.55 103.52 157.76 268.22 4.500 465.33 661.98 -196.32 FAIL ) BP ) Anticollision Report Company: BP Amoco Date: 9/24/2002 Time: 09:32:39 Page: 4 Field: Prudhoe Bay RefereDc~ Site: PB OS 18 Co-ordinate(NE) Reference: Well: 18-05, True North Reference Well: 18-05 Vertical (IVD) Reference: 49.30' 49.3 Reference Wellpatb: Plan 18-05A Db: Oracle Site: PB OS 18 Well: 18-05 Rule Assigned: Major Risk W ellpath: 18-05 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go AUowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area De\'iation Warning ft ft ft ft ft ft deg deg in ft ft ft 12623.08 8763.34 12600.00 8778.38 105.89 103.81 157.68 268.14 4.500 472.60 664.23 -191.27 FAIL 12646.99 8763.20 12625.00 8779.22 106.24 104.11 157.59 268.05 4.500 479.90 666.08 -185.80 FAIL 12670.88 8763.06 12650.00 8780.13 106.58 104.40 157.50 267.96 4.500 487.21 667.93 -180.30 FAIL 12694.77 8762.92 12675.00 8781.11 106.93 104.69 157.40 267.86 4.500 494.54 669.78 -174.77 FAIL 12718.64 8762.78 12700.00 8782.17 107.27 104.99 157.29 267.75 4.500 501.89 671.78 -169.38 FAIL 12738.85 8762.67 12725.00 8783.29 107.56 105.28 157.18 267.64 4.500 509.27 673.72 -163.89 FAIL 12759.22 8762.58 12750.00 8784.49 107.70 105.34 157.88 267.54 4.500 516.84 674.27 -156.81 FAIL 12776.72 8762.54 12775.00 8785.76 107.82 1 05.41 158.46 267.43 4.500 524.73 674.79 -149.39 FAIL 12800.00 8762.56 12800.00 8787.12 107.98 105.38 159.27 267.32 4.500 532.97 675.14 -141.41 FAIL 12800.00 8762.56 12825.00 8788.57 107.98 105.66 159.16 267.22 4.500 541.58 676.33 -134.02 FAIL 12828.36 8762.67 12850.00 8790.11 108.06 105.52 160.17 267.11 4.500 550.21 676.12 -125.06 FAIL 12845.26 8762.78 12875.00 8791.73 108.11 105.53 160.73 267.00 4.500 559.30 676.24 -116.04 FAIL 12862.01 8762.93 12900.00 8793.45 108.15 105.53 161.28 266.89 4.500 568.68 676.32 -106.68 FAIL 12878.59 8763.12 12925.00 8795.25 108.20 105.51 161.82 266.79 4.500 578.35 676.36 -96.99 FAIL 12900.00 8763.41 12950.00 8797.14 108.26 105.38 162.55 266.67 588.33 676.12 -86.68 FAIL 12911.27 8763.59 12975.00 8799.10 108.25 105.44 162.89 266.57 598.53 676.42 -76.75 FAIL 12927.36 8763.87 13000.00 8801.11 108.24 105.38 163.42 266.47 609.02 676.18 -65.97 FAIL 12948.93 8764.30 13025.00 8803.17 108.23 105.19 164.16 266.36 619.82 675.53 -54.45 FAIL 12963.35 8764.61 13050.00 8805.29 108.44 105.47 164.07 266.27 630.75 677.15 -45.09 FAIL 12985.78 8765.08 13075.00 8807.46 108.77 105.74 163.99 266.19 641.75 678.89 -35.77 FAIL 13008.19 8765.56 13100.00 8809.69 109.11 106.01 163.90 266.10 652.78 681.09 -26.87 FAIL 13030.60 8766.04 13125.00 8811.97 109.44 106.28 163.81 266.01 663.82 682.85 -17 .52 FAIL / 13052.99 8766.52 13150.00 8814.34 109.78 106.55 163.71 265.91 674.89 684.60 -8.12 FAIL 13075.35 8766.99 13175.00 8816.87 110.11 106.83 163.60 265.80 686.00 686.36 1.31 Pass 13097.68 8767.47 13200.00 8819.54 110.45 107.10 163.49 265.69 697.14 688.11 10.80 Pass 13119.99 8767.94 13225.00 8822.36 110.78 107.37 163.37 265.57 708.32 690.32 19.88 Pass 13142.28 8768.42 13250.00 8825.33 111.12 107.65 163.24 265.44 719.54 692.08 29.47 Pass 13164.54 8768.89 13275.00 8828.37 111.45 107.93 163.11 265.31 730.79 693.87 39.04 Pass 13186.81 8769.36 13300.00 8831.42 111.78 108.22 162.98 265.18 742.03 695.67 48.61 Pass 13206.40 8769.78 13322.00 8834.10 112.08 108.47 162.87 265.07 751.93 697.70 56.59 Pass Site: (fi18 Well: 18-0' Rule Assigned: Major Risk Wellpath: #105 18-05A V1 Plan: Plan #105 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go AUowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11600.30 8631.68 11600.00 8631.38 92.94 92.81 240.69 0.00 7.000 0.00 590.64 -155.65 FAIL 11625.28 8637.94 11625.00 8637.65 93.22 93.07 152.45 268.78 7.000 0.68 592.25 -591 .58 FAIL 11650.14 8644.11 11650.00 8643.83 93.36 93.14 155.75 269.54 7.000 2.53 592.91 -590.45 FAIL 11674.79 8650.19 11675.00 8649.91 93.22 93.01 158.57 269.80 7.000 5.50 591.91 -586.46 FAIL 11699.13 8656.14 11700.00 8655.86 93.09 92.69 161.16 269.89 7.000 9.65 590.29 -580.68 FAIL 11723.05 8661.93 11725.00 8661.68 92.65 92.21 163.54 269.81 7.000 14.96 587.45 -572.57 FAIL 11746.46 8667.53 11750.00 8667.37 92.20 91.60 165.77 269.63 7.000 21.40 583.95 -562.73 FAIL 11769.31 8672.92 11775.00 8673.01 91.50 90.85 167.70 269.21 2.875 28.90 579.33 -550.85 FAIL 11791.66 8678.11 11800.00 8680.79 90.77 89.98 166.01 265.24 2.875 36.81 574.19 -538.71 FAIL 11813.72 8683.16 11825.00 8689.92 89.87 88.98 163.63 260.60 2.875 44.42 568.38 -523.78 FAIL 11835.92 8688.14 11850.00 8699.53 88.86 87.85 161.55 256.27 2.875 50.51 561.58 -507.10 FAIL 11858.21 8693.04 11875.00 8709.36 87.73 86.58 159.55 251.99 2.875 55.08 554.79 -489.32 FAIL 11880.67 8697.87 11900.00 8718.44 86.41 85.18 158.24 248.40 2.875 58.04 546.78 -471.55 FAIL 11903.25 8702.61 11925.00 8726.51 85.04 83.65 157.46 245.33 2.875 59.29 538.44 -455.34 FAIL 11925.89 8707.23 11950.00 8733.46 83.42 81.99 156.96 242.55 2.875 58.76 528.68 -439.61 FAIL ) BP ') Anticollision Report Company: BP Amoco Date: 9/24/2002 Time: 09:32:39 Page: 5 Field: Prudhoe Bay Reference Site: PB OS 18 Co-ordinate(NE) Reference: Well: 18-05. True Nörth Reference Well; 18-05 Vertical (IVD) Reference: 49.30' 49.3 Reference Wellpatb: Plan 18-05A Db: Oracle Site: PB OS 18 Well: 18-05 Rule Assigned: Major Risk Wellpatb: Plan#105 18-05A V1 Plan: Plan #105 V1 Inter-Site Error: 0.00 ft I Reference Offset Sel'iÚ-Major A'tis Ct....Ctr No-Go AUowablt i MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distanct Area Deviation Warning ft ft ft ft ft ft deg deg In ft ft ft 11950.00 8712.01 11975.00 8739.21 81.71 80.07 156.69 239.85 2.875 56.47 517.83 -424.44 FAIL 11971.10 8716.06 12000.00 8743.67 79.95 78.32 156.08 237.12 2.875 52.36 507.55 -410.91 FAIL 11993.52 8720.22 12025.00 8746.80 78.09 76.33 155.20 233.99 2.875 46.50 495.97 -396.26 FAIL 12015.98 8724.24 12050.00 8748.85 76.11 74.24 153.91 230.47 2.875 39.75 484.12 -380.24 FAIL 12040.30 8728.51 12075.00 8750.73 76.48 74.49 151.47 228.02 2.875 34.20 485.83 -377.38 FAIL 12064.85 8732.82 12100.00 8752.50 76.86 74.74 150.04 226.60 2.875 29.54 487.55 -377.38 FAIL 12089.76 8737.16 12125.00 8754.16 78.17 75.92 149.39 226.88 2.875 25.68 494.80 -386.18 FAIL 12114.98 8741.29 12150.00 8755.70 80.63 78.28 148.40 228.07 2.875 22.28 508.81 -401.67 FAIL 12140.19 8745.10 12175.00 8757.11 83.04 80.54 147.98 229.81 2.875 19.28 522.61 -419.29 FAIL 12165.42 8748.57 12200.00 8758.39 85.32 82.72 148.32 232.31 2.875 16.70 536.59 -440.37 FAIL 12190.66 8751.71 12225.00 8759.55 87.53 84.80 149.63 235.77 2.875 14.56 549.67 -465.17 FAIL 12215.91 8754.52 12250.00 8760.57 89.60 86.78 152.03 240.32 2.875 12.89 562.20 -493.74 FAIL 12241.19 8756.98 12275.00 8761.45 91.60 88.65 155.47 245.90 2.875 11.73 573.83 -523.72 FAIL 12266.49 8759.09 12300.00 8762.19 93.43 90.41 159.53 252.10 2.875 11.11 584.87 -551.83 FAIL 12291.82 8760.84 12325.00 8762.80 95.19 92.06 163.49 258.20 2.875 11.02 595.03 -574.22 FAIL 12317.18 8762.25 12350.00 8763.25 96.77 93.59 166.58 263.42 2.875 11.44 604.53 -590.00 FAIL 12342.58 8763.29 12375.00 8763.57 98.28 94.99 168.31 267.29 2.875 12.31 613.17 -600.32 FAIL 12368.02 8763.97 12400.00 8763.74 99.59 96.28 168.57 269.69 2.875 13.58 621.09 -607.49 FAIL 12393.50 8764.28 12425.00 8763.78 100.83 97.43 167.49 270.74 2.875 15.23 628.15 -612.90 FAIL 12418.90 8764.29 12450.00 8763.80 101.79 98.32 165.64 270.63 2.875 17.31 633.79 -616.47 FAIL 12444.25 8764.25 12475.00 8763.82 102.59 99.06 163.86 270.37 2.875 20.02 638.33 -618.31 FAIL 12469.60 8764.18 12500.00 8763.84 103.29 99.73 162.06 270.09 2.875 23.36 642.55 -619.19 FAIL 12494.95 8764.07 12525.00 8763.86 103.96 100.33 160.26 269.80 2.875 27.35 646.27 -618.91 FAIL 12519.96 8763.93 12550.00 8763.88 104.46 100.76 159.09 269.55 2.875 32.02 649.38 -617.33 FAIL 12544.27 8763.79 12575.00 8763.90 104.79 101.02 158.92 269.38 2.875 37.86 651.07 -613.17 FAIL 12568.32 8763.65 12600.00 8763.92 105.12 101.27 158.82 269.27 2.875 44.67 652.75 -608.02 FAIL 12592.61 8763.51 12625.00 8763.94 105.46 101.52 158.72 269.18 2.875 50.56 654.43 -603.79 FAIL 12617.18 8763.37 12650.00 8763.95 105.81 101.78 158.62 269.08 2.875 55.17 656.55 -601.29 FAIL 12641.96 8763.23 12675.00 8763.97 106.16 102.04 158.52 268.98 2.875 58.49 658.32 -599.72 FAIL 12666.87 8763.08 12700.00 8763.99 106.52 102.30 158.40 268.86 2.875 60.50 660.09 -599.45 FAIL 12691.86 8762.94 12725.00 8764.00 106.88 102.56 158.26 268.72 2.875 61.21 661.87 -600.49 FAIL 12716.85 8762.79 12750.00 8764.02 107.25 102.83 158.10 268.56 2.875 60.62 663.81 -602.98 FAIL 12741.66 8762.65 12775.00 8764.04 107.58 103.08 158.01 268.36 2.875 58.71 665.71 -606.72 FAIL 12765.55 8762.56 12800.00 8764.05 107.75 103.16 158.75 268.16 2.875 55.76 666.35 -610.24 FAIL 12789.37 8762.54 12825.00 8764.07 107.91 103.22 159.51 267.98 2.875 51.91 666.90 -614.57 FAIL 12813.12 8762.59 12850.00 8764.08 108.02 103.26 160.29 267.83 2.875 47.18 667.64 -619.98 FAIL 12836.76 8762.72 12875.00 8764.10 108.08 103.27 161.08 267.69 2.875 41.55 667.76 -625.66 FAIL 12860.29 8762.92 12900.00 8764.11 108.15 103.25 161.87 267.56 2.875 35.05 667.79 -632.15 FAIL 12883.67 8763.18 12925.00 8764.13 108.21 103.21 162.66 267.43 2.875 27.68 667.76 -639.43 FAIL 12906.90 8763.52 12950.00 8764.14 108.26 103.15 163.43 267.29 2.875 19.44 667.79 -647.64 FAIL 12929.95 8763.92 12975.00 8764.15 108.24 103.07 164.10 267.05 2.875 10.34 667.37 -656.21 FAIL 12952.80 8764.38 13000.00 8764.16 108.28 103.02 156.11 258.31 2.875 0.40 667.49 -654.42 FAIL 12975.24 8764.86 13025.00 8764.17 108.62 103.28 345.72 87.92 2.875 10.62 669.14 -657.83 FAIL 12997.07 8765.33 13050.00 8764.18 108.94 103.53 345.69 87.89 2.875 22.80 670.76 -647.37 FAIL 13018.24 8765.78 13075.00 8764.19 109.26 103.78 345.76 87.96 2.875 36.09 672.79 -635.79 FAIL 13038.86 8766.21 13100.00 8764.21 109.56 104.02 345.85 88.05 2.875 50.23 674.33 -623.32 FAIL 13060.00 8766.66 13125.00 8764.26 109.88 104.26 345.90 88.10 2.875 63.57 675.91 -611.69 FAIL 13081.81 8767.13 13150.00 8764.35 110.21 104.52 345.92 88.12 2.875 75.78 677.54 -601.22 FAIL 13104.23 8767.61 13175.00 8764.48 110.54 104.78 345.93 88.13 2.875 86.83 679.67 -591.97 FAIL 13127.20 8768.10 13200.00 8764.65 110.89 105.04 345.93 88.13 2.875 96.69 681.40 -583.95 FAIL ) BP ~) Anticollision Report Compan~': BP Amoco Date: 9/24/2002 Time: 09:32:39 Page: 6 Field: Prudhoe Bay Reference Site: PB OS 18 Co-ordinate(NE) Reference: Well: 18-05, True North Reference Well: 18-05 Vertical ([VD) Reference: 49.30' 49.3 Reference Wellpath: Plan 18~05A Db: Oracle Site: PB OS 18 Well: 18-05 Rule Assigned: Major Risk W ellpath: Plan#105 18-05A V1 Plan: Plan #105 V1 Inter-Site Error: 0.00 ft R.eference Offset Senll-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13150.66 8768.60 13225.00 8764.86 111.24 105.32 345.93 88.13 2.875 105.33 683.16 -577.18 FAIL 13174.54 8769.10 13250.00 8765.11 111.60 105.60 345.92 88.12 2.875 112.73 684.95 -571.69 FAIL 13198.77 8769.62 13275.00 8765.40 111.96 105.88 345.91 88.11 2.875 118.86 686.77 -567.50 FAIL 13223.29 8770.14 13300.00 8765.73 112.33 106.17 345.89 88.09 2.875 123.72 689.07 -564.60 FAIL 13248.03 8770.67 13325.00 8766.09 112.71 '106.46 345.87 88.07 2.875 127.28 690.93 -563.02 FAIL 13272.93 8771.20 13350.00 8766.49 113.08 106.75 345.85 88.05 2.875 129.54 692.81 -562.74 FAIL 13297.91 8771.73 13375.00 8766.93 113.46 107.04 345.82 88.02 2.875 130.49 694.70 -563.78 FAIL 13322.90 8772.26 13400.00 8767.40 113.83 107.33 345.79 87.99 2.875 130.12 697.04 -566.13 FAIL 13347.84 8772.79 13425.00 8767.90 114.21 107.62 345.75 87.95 2.875 128.45 698.93 -569.78 FAIL 13372.66 8773.32 13450.00 8768.43 114.58 107.90 345.70 87.90 2.875 125.47 700.81 -574.73 FAIL 13397.29 8773.85 13475.00 8768.99 114.96 108.19 345.65 87.85 2.875 121.19 702.67 -580.95 FAIL 13421.66 8774.37 13500.00 8769.58 115.32 1 08.47 345.58 87.78 2.875 115.63 704.97 -588.42 FAIL 13445.70 8774.88 13525.00 8770.20 115.69 108.74 345.49 87.69 2.875 108.80 706.80 -597.13 FAIL 13469.35 8775.38 13550.00 8770.84 116.04 109.01 345.39 87.59 2.875 100.71 708.59 -607.05 FAIL 13492.55 8775.87 13575.00 8771.51 116.40 109.27 345.25 87.45 2.875 91.39 710.36 -618.13 FAIL 13515.22 8776.36 13600.00 8772.19 116.74 109.53 345.06 87.26 2.875 80.88 712.53 -630.35 FAIL 13537.32 8776.83 13625.00 8772.89 117.07 109.77 344.79 86.99 2.875 69.18 714.21 -643.63 FAIL 13558.76 8777.28 13650.00 8773.62 117.40 110.01 344.37 86.57 2.875 56.35 715.84 -657.88 FAIL 13579.51 8777.73 13675.00 8774.35 117.71 110.24 343.65 85.85 2.875 42.42 717.42 -672.89 FAIL 13599.49 8778.15 13700.00 8775.10 118.01 110.46 342.05 84.25 2.875 27.43 718.94 -687.86 FAIL TREE = FMC WELLHEAD = FMC 'ÄcruÄ'fO'R:';"""'" '''''''Ãx'êison' 'KS':"'Ei:E\l";';;;"""""'''''' '''''-''''';''''''''''''''''''''49' 'Î3F:"B:E\J";;;;""',',,',,w''''''''''''''''''2Õ:ä'í' "¡(OP';;;""'-"-" '" '-"""''''''{¡'õõ' ,§~"',~:~Q~~',~~':::,:~~':~:"~:~~f~" Datum I\ID = '5âtlim'íVÔ';;'-' "w' '''äãõõì''ss'' Mnimum 1.0. = 2.813" @ 9815'. 3 1/2" OTIS 'X' Nipple 95/8",47#, L-80 casing, ID= 8.681" 3 1/2",9.2#, N-80 tubing I.D.= 2.992" 7", 29#, L-80 Liner, ID = 6.184" 18-0~-Pre Rig Condition ~ .. 10,264' 12,393' ~ 12,500' ') SA FEIY NOTES: Fis h left @12967' , during well completion on 07/05/86 ' . 25' 1--1 51/2" X 41/2" Tbg XO; ID = 3.958" 2236' 1--1 4-1/2" CAMCO BAL-O SSSV, ID = 3.813" 1 ~ 1 3,008' 1--1 133/8",72#, L-80, Casing; I.D. = 12.347" 1 l GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATCH PORT DA TE 1 3891 3501 43° MMG DV RK 0 7/9/1986 2 6586 5500 37° MMIG-2 RKID RKP 0 7/24/1986 -I 4,474' 1--1 41/2" X 31/2" Tbg XO; ID = 2.992" -I 7,919' 1--1 95/8" X 7" Baker A Lnr Hngr -I 7,932' 1--1 Bottom of Baker Tieback extension 1 9,815' 1--1 3 1/2" OTIS 'X' Ldg Nip. ID = 2.813" 9,926' 1--1 9 5/8" X 7" Baker A Lnr Hngr 9,935' 1--1 7" Baker Tieback Seal assembly .. ~ ~ Pre rig tubing cut at -11,625' MD I ~ - -I 12,394' 1--1 3 1/2" TIW Overshot Seal Assembly ~, I 12,39T l-i TIWPolishedRiserw/2.813"I.D.'X'Profile g- -112,409' 1--1 7"X4-1/2"TIWSSPkrID=2.813" 1 ~ Top of P&A Cement plug at - 12,425' MD "-....1 12483' 1--17" Baker Ext Csg Pkr; I.D. = 6.200" 1 ~ /1 12,502' 1--1 Top of 41/2" Slt'd liner; I.D. = 3.958" 1 /' 1 13,444' 1--18 1/2"Open hole TD 1 .~ .~ ~ 1 12,965' 1--141/2",12.6#, L-80 Liner; I.D. = 3.958" 1 ~ .,-~, 1 12,951' I-iBottom of 41/2'" SIt'd liner; I.D. = 3.958" 1 \ ~~ \ I ~.~.~-,~ .~ .~. ~a'"~$~'~ .'14 & " . 0; c:::J" t:::::;I c:::J c:::a _.c::::::t' c:::a c:::;:I c::::I'" c:::::I.- ~ ~ 12,967' - Fish - Bit, bit sub, 12jts 4 3/4" drill pipe, and burrper jars. PERFORATION SUMv1ARY REF LOG: Array Sonic on 5/22/86 ANGLE AT TOP PERF: 88° @ 12500' Note: Refer to Production DB for historical perf data I SIZE I SPF I INTERVAL 10PnlSqZ DATE I 4-1/2" SLID 12502-12951 0 07/10/86 DATE 07/09/86 01/02/01 02/01/01 10/12/01 09/20/02 COM'v1B'-JTS ORIGINAL COIVPLETION SIS-QAA CONVERTED TO CANVAS SIS-LG REVISION CHltlh CORRECTIONS DeN ReCreated in C7 REV BY DA TE REV BY COMVIENTS 09/20/02 D8N Proposed Pre rig work PRUDHOE BAY UNIT WB..L: 18-05 ÆRMIT No: 186-0800 API No: 50-029-21583-00 SEC 24. T11 N, R14E, 952' FNL, 221' FB.. BP Exploration (Alaska) 18-0~'¡ Proposed Complt,)on TREE = FMC WELLHEAD = FMC 'Ä'êruÄ'foR ';"'" ",- 'Ax'èìson kî3:"E[ë/";;; ',." """"'''''49:30'' - s'F:'B:êJ";'" ""'''''''''''''20.'80'" 'KÖP';""'''''''-' """""1":40Õí fV1ã)('Ängiè'''; "-"'g'(jô@f1'24'14t '6ãtum"rv15';'~'" '-'''-- ""'''''''1'24''14;' 'Baìum-'îV5';'" """"""'ã-;HsÎ'''ss' ~ .t 95/8",47#, L-80 casing, ID=8.681" 10,264' 7" Whip Stock set on tubing - 11,625' stump. 3 1/2",9.2#, N-80 tubing I.D.= 2.992" 12,393' fZ 1 2,200' 1-1 4-1/2" 'X' Landing Nipple, ID = 3.813" ~ 1 3,008' 1-1 133/8",72#, L-80, Casing; I.D. = 12.347" 1 GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATCH PORT DATE 1 3891 3500 43° RP 2 6586 5500 37° DV l -I 7,919' -I 7,932' 1 9,858' 1 9,860' 1 9,876' -I 9,888' 9,900' 9,926' 9,935' g 1-1 9 5/8" X 7" Baker A Lnr Hngr 1-1 Bottom of Baker Tieback extension 1-1 41/2" 'X' landing nipple, I.D. = 3.813" l-i 7" X 4 1/2" Baker 8-3 Production Pkr 1-1 41/2" 'X' landing nipple, I.D. = 3.813" 1-1 4 1/2" 'XN' landing nipple, I.D. = 3.725" - 7" X 5" Baker 'ZXP Liner top packer wI 18S and 'HMC' Liner Hanger 1-1 9 5/8" X 7" Baker A Lnr Hngr 1-1 7" Baker Tieback seal assembly 1 13,656' 1-141/2",12.6#, L-80 Liner, IBT-M 1 \ .4 8 ~ ~ ~ 7",29#, L-80 Liner, 10 = 6.184" 12,500' PffiFORA TION SUM\1ARY REF LOG: Array Sonic on 5/22/86 ANGLE AT TOP PERF: 88° @ 12500' Note: Refer to Production DB for historical perf data I SIZE I SPF INTERVAL lopn/sqz DATE I 4-112" SLTD 12502-12951 0 07/10/86 DATE 07/09/86 01/02/01 02/01/01 10/12/01 09/20/02 COMlVENTS ORIGINAL COMA..ETION SIS-QAA CONVERTED TO CANV AS SIS-LG REVISION a-vtlh CORRECTIONS DEW ReCreated in C7 REV BY ~ 1 13,444' 1-18 1/2"Open hole TD 1 - FISh - B~, b~ sub, 12 jts 4 314' dril \ pipe, and bU"l'er jars. ~ '.~' ~""~ ~.~ "E5 I ~& l ,c:=J c::::::::I c::::;::J c=:r c::::::::J -, ~ 12,96T PRUDHOE BAY UNIT WELL: 18-05A PERMIT No: AA No: 50-029-21583-01 SEC 24, T11 N, R14E, 952' FNL, 221' Fe.. BP Exploration (Alaska) DA TE REV BY COMfvENTS 11/06/02 DEW Proposed Completion Wp07 .t)ST THIS NOTICE IN THE DOGHOUSE) 18-05A Rig site Summary of Drilling Hazards ./ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 50 ppm, February 2001. ./ NORM test all retrieved well head and completion equipment. ./ All wells pass major risk criteria. The closest neighboring wells, at surface, are 18-04 and 18-27. Well 04 is approximately 120' to the south, and well 27 is approximately 60' to the north. No shut-ins will be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ./ There are several fault crossings expected, during the drilling of the 6" production interval. The anticipated throw of each is -15'. No significant losses are expected, but due attention should be paid to the possibility. ./ Lost circulation may also be experienced while drilling. Though not expected to be a problem, potential lost circulation demands awareness. The SSD lost circulation tree should be followed if lost fluid returns are encountered. ./ Differential sticking may be encountered in this depleted reservoir. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. CONSULT THE DS 18 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 18-05A H 207128 DATE INVOICE I CREDIT MEMO 9/20/02 INV# CK091602F I ß-'OC) A- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY " DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ B. TO THE ALASKA OIL & GAS CONSERVATION ORDER - '333 W. 7th AVE,$TE 100 OF ANCHO~AGE, AK99501 ,'''.1 , I. tn,,, ' '. .' tU'Il' tU,rt DATE 9/20/02 CHECK NO. :-1207128 GROSS VENDOR DISCOUNT NET H RE€EIVED NOV 1 2 2002 -- Alaska Oil & G&S Gons. CommissIon Ar chorage FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 207128 CONSOLIDATED COMMERCIAL ACCOUNT 56.389 4i2 ',~ DATE, SEPT~ 20,. 2002 AMOUNT ****$100.00**** ~~~0~:~:~:~~:~~~~:j:~f{:~'~2:~~\~:~~~~~.:~.:~i:\,: ~\ ,.":.':..¡.:M.:."~""'" , ,".",',',' '," ""',',',' ",',,',,",-,.,,',',,',',-,,','"'",'".""','"',,,',,,",',.,',.,.,'M,'.:,:"","::""" ..\....:~-::< - ....:\--.-,-::., '-' :.-.,--_..::t¡\//~~\..--:..'.... ..";.\~. - r~~féMP:'~:,,~i€~~~~~¡~:;~{:;~&7t: "I 20 ? . 2 B "I I: 0 t. . 2 0 ~ B q 51: 00 B t. t. . q III ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /'6'L4 / (j -0 ~ ~ PTD# .20/--' z.)" CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) paOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number, stated above. In accordance with 20 AAC 25.005(f), 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). . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing . exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. (Service Well Only) GEOLOGY APPR DATE ~. ~¿-¿ (Exploratory Only) WELL PERMIT CHECKLIST COMPANY g¡J jI WELL NAME/.J4 /tl-ð _t;';lfPROGRAM: Exp - Dev)L. Redrll..2L Re-Enter - Serv - Wellbore seg- FIELD & POOL G¿¡ðl-<"c;> INITCLASS .o¡t)4/' 1-r1,ï GEOLAREA ?7~ UNIT#, //&.Çr1 ON/OFFSHORE..s:t....N ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . .f- N ' 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N h ~ - }'~2. .., L"? 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ 3:LB!:-/b<- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . V N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #- Y þ( N. r9 . (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. VN ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ro NN 16. Surface casing protects all known USDWs. . . . . . . . . . . (ÿ) 17. CMT vol adequate to circulate on conductor & surf csg. . . . . .y N - ,iflA- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . '~, " N 19. CMT will cover all known productive horizons. . . . . . . . . . œ N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . ~ NN IJ'~ j 'y c 2 J: <- ;p rk Q ~, (;.'"'' 21. Adequate tankage or reserve pit.. . . . . . . " . . . . . . . . ,"",()Q ~ C J -.. { 22 If a re dr II h 1 0-403 ç b d t b d N i .PI;; 'I o-L ;, J,,;;I J - ,- ð , r:;. . ',ø-" c.'>..J ,J' ~ ~ 1~ 'dt-'I . - i', as a lor a an onmen een approve. . . " N '7. '~,l i' , '1:.... u-.r t: ¿. Î. J'7f ~:~ ~ ~ J. - ; ''',~'' (;~- I",)" e>: 71' 1A'I,¿. "'" J. 23. Adequate wellbore separation proposed.. . . . . . . . .,' . . Y1 .- r I ;;> IL. ;, -~,.~ 1---- " K,::' J-,-, y I~I T"V'f:-, '- . 24. If diverter required, does it meet regulations. . . . . . . . . . -4-N /\l/A 25, Drilling fluid program schematic & equip list adequate. . . . . ~ N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . "',' NN ,IIA, J'j ./' ,AA I. I.Þ I 1'- J.¡7"J '. ¡/J,,¡ (.¡') ., ,.; 'D f APPR DATE 27. BOPE press rating appropriate; testto šC;c..?O psig. I'YI."'-'J{ ''''I''-S -, ~ r-r -- {vr.-;;;r vf.(C- jP>l. 1"'.,1 J I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N yJ'"'7/T ìl I ~ '02- 29. Work will occur without operation shutdown. . . . . . . . . . . ',' NN 50 fP"'" 0(.,/''-'' , ' 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . v 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N Ii/A- 32. Permit can be issued wlo hydrogen sulfide measures. . . . . Y @ 33. Data presented on potential overpressure zones. . . . . . . . }1~~ 11) , /J, 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . ,\ Ií 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER RP~/ TEM JDH JBR Rev: 10/15/02 SFD- WGA ../' MJW COMMISSIONER: COT ({xtv DTS /i 11")/4,,")) I \ MLB 11/1,/(1 z.. '- Comments/lnstructions: G:\geology\perm its\checklist.doc ) ) Well H ¡story 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 simplrty finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. " ) ) q;09-a /9 / 110 gJCJ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 09 15:30:44 2003 Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/04/09 Origin........... ........STS Reel Name.. ..............UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/04 /0 9 Origin. . . . . . . . . . . . . . . f . . . STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU/WOA MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 18-05A 500292158301 BP EXPLORATION Sperry Sun 09-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22191 J. BOBBITT J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 24 11N 14E 951 221 .00 46.45 20.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING ') 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY, NO DATA IS PRESENTED. 4. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); COMPENSATED NEUTRON POROSITY (CNP); AND STABILIZED LITHO-DENSITY (SLD). 5. DEPTH SHIFTING WAS WAIVED, PER THE 09-APRIL-2003 E-MAIL FROM D. SCHNORR (BP EXPLORATION) . 7. MWD RUNS 1 - 2 REPRESENT WELL 18-05A WITH API#: 50-029-21583-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13656'MD I 8764'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). (EXTRA SHALLOW SPACING) . (SHALLOW SPACING) . (MEDIUM SPACING) . (DEEP SPACING). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.0" MUD WEIGHT: 8.5 PPG - 8.6 PPG MUD SALINITY: 13000 - 14000 PPM FORMATION WATER SALINITY: 10994 FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ CHLORIDES PPM CHLORIDES File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/04/09 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and 1 clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FCNT NCNT PEF NPHI RPD RPM RPS RPX GR FET DRHO RHOB ROP $ ') .5000 START DEPTH 11537.0 11538.0 11551.5 11600.5 11600.5 11600.5 11600.5 11600.5 11600.5 11604.5 11607.5 11607.5 11630.5 ') STOP DEPTH 13562.5 13562.5 13577.5 13562.5 13605.5 13605.5 13605.5 13605.5 13598.5 13605.5 13577.5 13577.5 13656.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO MERGE TOP 2 11537.0 MERGED MAIN PASS. $ MERGE BASE 13656.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last ) ) Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11537 13656 12596.5 4239 11537 13656 ROP MWD FT/H 0.22 230.6 94.9579 4052 11630.5 13656 GR MWD API 12.88 148.66 56.081 3997 11600.5 13598.5 RPX MWD OHMM 0.28 2000 323.056 4011 11600.5 13605.5 RPS MWD OHMM 0.43 2000 290.203 4011 11600.5 13605.5 RPM MWD OHMM 6.9 2000 162.262 4011 11600.5 13605.5 RPD MWD OHMM 8.87 2000 239.709 4011 11600.5 13605.5 FET MWD HOUR 0.32 64.17 1.92124 4003 11604.5 13605.5 NPHI MWD PU-S 11.16 33.97 22.4288 3925 11600.5 13562.5 FCNT MWD CNTS 318 1392 679.632 4052 11537 13562.5 NCNT MWD CNTS 20816 35013 28750.4 4050 11538 13562.5 RHOB MWD G/CM 1.734 2.907 2.33349 3941 11607.5 13577.5 DRHO MWD G/CM -0.532 0.36 0.0376623 3941 11607.5 13577.5 PEF MWD BARN 0.99 11.83 2.23103 4053 11551.5 13577.5 First Reading For Entire File..........11537 Last Reading For Entire File...........13656 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/04/09 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/04/09 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT PEF NPHI RPD RPM RPS RPX GR FET DRHO 2 header data for each bit run in separate files. 2 .5000 START DEPTH 11537.0 11538.0 11551.5 11600.5 11600.5 11600.5 11600.5 11600.5 11600.5 11604.5 11607.5 STOP DEPTH 13562.5 13562.5 13577.5 13562.5 13605.5 13605.5 13605.5 13605.5 13598.5 13605.5 13577.5 -) RHOB ROP $ 11607.5 11630.5 13577.5 13656.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . ) 12-DEC-02 Insite 66.37 Memory 13656.0 11520.0 13656.0 75.2 92.7 TOOL NUMBER 184054 154268 110041 159436 6.000 .0 Flo-Pro 8.60 57.0 9.0 14000 6.5 .500 .210 .450 .600 70.0 173.5 70.0 70.0 ) ) Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11537 13656 12596.5 4239 11537 13656 ROP MWD020 FT/H 0.22 230.6 94.9579 4052 11630.5 13656 GR MWD020 API 12.88 148.66 56.081 3997 11600.5 13598.5 RPX MWD020 OHMM 0.28 2000 323.056 4011 11600.5 13605.5 RPS MWD020 OHMM 0.43 2000 290.203 4011 11600.5 13605.5 RPM MWD020 OHMM 6.9 2000 162.262 4011 11600.5 13605.5 RPD MWD020 OHMM 8.87 2000 239.709 4011 11600.5 13605.5 FET MWD020 HOUR 0.32 64.17 1.92124 4003 11604.5 13605.5 NPHI MWD020 PU-S 11.16 33.97 22.4288 3925 11600.5 13562.5 FCNT MWD020 CNTS 318 1392 679.632 4052 11537 13562.5 NCNT MWD020 CNTS 20816 35013 28750.4 4050 11538 13562.5 RHOB MWD020 G/CM 1.734 2.907 2.33349 3941 11607.5 13577.5 DRHO MWD020 G/CM -0.532 0.36 0.0376623 3941 11607.5 13577.5 PEF MWD020 BARN 0.99 11.83 2.23103 4053 11551.5 13577.5 First Reading For Entire File..........11537 Last Reading For Entire Fi1e...........13656 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/04/09 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/04/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services ') Reel Trailer Service name.............LISTPE Date.................... .03/04/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS File ) Writing Library. Scientific Technical Services
