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Home My WebLink About203-036Operator Name:2. Development Exploratory Service Permit to Drill Number:203-036 6.50-029-20852-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11263 11263 9008 8982, 9155 11263 None 8622, 8748 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 28 - 108 28 - 108 1490 470 Surface 2547 13-3/8" 27 - 2574 27 - 2574 5380 2670 Intermediate 8590 9-5/8" 25 - 8615 25 - 8307 6870 4760 Liner 884 7" 8460 - 9344 8163 - 8873 8160 7020 Perforation Depth: Measured depth: 9382 - 11095 feet True vertical depth:8897 - 9007 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 23 - 9191 23 - 8772 8982 8622Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 2079 4-1/2" 9184 - 11263 8767 - 9008 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 37314542145111 2605227 1523 168 152 351 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brown, Don L. browd2@BP.com Authorized Name:Brown, Don L. Authorized Title: Authorized Signature with Date:Contact Phone:+1 9075644675 Treatment descriptions including volumes used and final pressure: 13. Petroleum Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9008 Sundry Number or N/A if C.O. Exempt: N/A 4-1/2" Baker S-3 Perm Packer 9155 8748 Junk Packer Printed and Electronic Fracture Stimulation Data Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028315 PBU 13-13A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations SFD 4/23/2020 9018 SFD 4/23/2020 ACTIVITYDATE SUMMARY 3/17/2020 ***WELL FLOWING ON ARRIVAL****(g/l for rate) MIRU SWCP 4518 SLICKLINE ****CONT WSR ON 3-18-20**** 3/18/2020 ****CONT WSR FROM 3-17-20****(perf) DRIFT W/ 32' x 3.16" DUMMY GUN, 1-3/4" S-BAILER TO 9375' SLM/9403' MD. RUN W/ KJT, 4-1/2'' BLB, AND 3.70'' GAUGE RING TO XN NIP @ 9454' SLM. DRIFT W/ 3.0'' CENT, 2'x1-7/8'' ST' STEM, AND 25 'x 3.0'' DD BAILER W/ MSB TO 9472' SLM.. SET 4-1/2" WHIDDON CATCHER @ 8945' SLM. PULL RK-DGLV FROM STA #1(8306' MD). ****CONT WSR ON 3-19-20**** 3/19/2020 ****CONT WSR FROM 3-18-20****(perf) PULL RK-OGLV FROM STA #2 (7295' MD) PULL RK-LGLV FROM STA #3 (5842'MD) & STA #4 (3452' MD) SET RK-LGLV'S IN STA #4 (3452' MD), ST #3 (5,842' MD) & ST #2 (7,295' MD) SET RK-OGLV IN ST #1 (8,306' MD) MULTIPLE ATTEMPTS TO PULL 4 1/2" WHIDDON FROM 8,939' SLM JARRED ON 4 1/2" WHIDDON FOR 1 HOUR & 45 MINUTES ***CONTINUE JOB ON 03/20/2020*** 3/20/2020 ***CONTINUE JOB FROM 03/19/2020*** (perf) SWCP 4517 STANDBY FOR PUMP TRUCK **MOVE TO WEATHER TICKET*** *****NOTE: WHIDDON CATCHER LIH @ 8939' SLM***** 3/21/2020 ***CONTINUE JOB FROM 03/20/2020***(perf) LRS PUMPED 36 BBLS OF CRUDE & TUBING PRESSURED UP RAN 10' x 2.25" PUMP BAILER TO 8,983' SLM (no returns) SHEARED DOGLESS GS ON TOP OF WHIDDON CATCHER @ 8,985' SLM PULLED WHIDDON CATCHER FROM 8,985' SLM (empty) ***CONTINUE JOB ON 03/22/2020*** 3/22/2020 ***JOB CONTINUED FROM 21-MAR-2020***Assist SLB Slickline (PERFORATING) Rigged down, SSL in control of well upon LRS departure. CV's=OTG FWHP's=1700/1700/200. 3/22/2020 ***CONTINUE JOB FROM 03/21/2020*** (perf) DRIFTED W/ 22' x 3" DRIVE DOWN BAILER TO 9,498' SLM (all clear) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 3/22/2020 ***WELLSHUT IN UPON ARRIVAL*** (ELINE AD PERF) PERFORATED 9384'-9415' (REFERENCE DEPTHS: 9382' - 9413') W/31' 2-7/8" POWERJET 6 SPF 60 DEG, CCL TO TOPSHOT=3.46', CCL STOP DEPTH=9380.5' CORRELATED TO SLB PBMS RST LOG DATED 29-AUG-2015 ***JOB COMPLETE, DSO NOTIFIED*** Daily Report of Well Operations PBU 13-13A • I13ck 13- 13/1-- 0 P71\ 3— l3?1- P71\ Z0 3O 36Q Regg, James B (DOA) From: Cook, Guy D (DOA) Sent: Tuesday,August 09, 2016 1:21 PM � 11, To: akopsfs3dsopslead@bp.com 11 Cc: Regg,James B (DOA) l Subject: PBU DS13-13 Deficiency Report Attachments: Deficiency_Report_PBU_DS13-13.xlsx • Justice, Attached is the deficiency report for well PBU DS13-13 with an incorrect permit to drill number on the well sign. This is provided for your records and to ensure the deficiency is corrected. Please provide photo evidence of the well sign after installation when you return the completed deficiency report (date corrected). If you have any questions, please feel free to call or email. Thank you, Guy Cook Nt4E0 JAN 1 12017 Petroleum Inspector AOGCC 907-227-2614 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Cook at 907-659-2714 or guy.cook@alaska.gov. 1 • • State of Alaska " `to ‘ip Oil and Gas Conservation Commission Deficiency Report Location: PBU 13-13A Date: 8/9/2016 PTD: 2030360 Operator: BP Exploration Alaska Type Inspection: SVS Operator Rep: Justice English Inspector: Guy Cook _ Position: Flow Station 3 Drill Site Lead Op. Phone: 907-659-8341 Correct by(date): 9/9/2016 Op. Email: akopsfs3dsopslead@bp.corn Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Wellhouse sign needs to be updated with correct permit to drill number. Operator Rep Signatures: AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention: Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention: Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 12/2015 Ms • • C o 6 o 1- � CU CU � � � _ > Q o - o � a ,A .� C4 v v 0 0 0 a J Z oz '''' H >. .�• Y O L a > fl O O O O C rs 0 ° c @ Q J W.1 a ccin m u7 CO o a) CO r W Wu, " '"' a, O �+ " N �_ C7 O ' d d d d vi L C C - ra coNz NaNycom E } O�W W -O Q a, Z -i„m Q M N M aD N CC 03 Q1 > a, -C _ ....;.. 0 0 Q p 0 0 -, N C L Cr .a J J J J J J } W W W W W W bOp O is O I- LL U. U. LL U. LL 'vi O E -c CO I- Q Q Q Q Q Q O_ _▪ O - ro C = CO Q Z Z Z Z Z Z v ' -0 '" u Q LL LL LL LL LL LL a, C) . u a, y O ▪ Q1 > LI N E C 4- y a; a, O o E U H 0 c o JD a v C tea, r� a, v w G O O 17. d H > >CO o .Q) MI - O C V Q a s u > Yx. 2 O q J ►- J O J I— CO m m 0 O N ci O U J a 0 re m ` • V R. C \ so Le w �n > G4 u \ a, Lu W 0 0 xN Ce CL ft MI ta• 4 >-IJJO CO 5 a O J J O O J Lwgz M . oL, r' te' RW T T T T a E f,3 cO c0 00 00 m _a Z o o o o 0 w E 0 . .0 .0 .0 .0 .0 O w 3 3 3 3 3 3111 u LL LL CL LL LL Li LL .0. O r C ? 04 d cL 0' r r r r O O ca 0 000000 00009 O OM fa L 0 ' v cZc ce cc c0c N H a > > O 0 0 x o �P I< W C) U U U U O C T t� c^ ca liu a O vs p r Co N N O v Or tO N 0 0 0 0 0 0 H N N CO 01N W N M CO vN co O E 0nit CO No� N N 0 N 0 VI 0 N N N N N N N u pNOf 0) 0) 0) 0) 0) O O Q� N0 0 0 0 N (m `" ( 0 0 0 0 0 in in a7 III u7 11) 00 v a=7 ce 'CO p 2- u c g E . �, cu co W J7 a r-1 Q 00 M W CO CO 0 w a, M 130M z N M N N += d H d Q N -ct.JJ a. O .M- r LL raZCIJ (13 tN rl t n .. C 0 COD d co d ?: ►- a a Q Image ~ .'bject Well History File C",Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - 03 b Well History File Identifier Organizing (done) o Two-sided 111111111I111111111 ~scan Needed I RESCAN ~Ior Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Scanning Preparation J x 30 = ~() D Other:: ~ ¡ A A'f} Date:7 is oS /s/ VVf¡--' , . I Date: 7 IS: ~ Isl mfJ + tl..a = TOTAL PAGES 6.q ~(/;ount d~no~' elude cover sheettl}A0 Date: 17 IS: DS /s/ r r .' {I I . BY: Helen (Maria J Project Proofing BY: Helen (Maria;J BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: ~ () (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO Helen( Maria} Date:7 ,sjOS Is! rn0 If NO in stage 1 page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: /s/ 1111111111111111111 1111111111111111111 II Date: /51 Quality Checked III "1111111" 11111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • • ( ol,I3 -i A Pm 2U303(, Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] c7fei itk}31 Sent: Tuesday, October 23, 2012 11:49 AM To: AK, D &C Well Integrity Coordinator; Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Fowler, Craig (CH2M HILL); AK, D &C DHD Well Integrity Engineer Subject: Operable: 13 -13 (PTD #2030360) Tubing Integrity Confirmed All, 1 Producer J.3- 13(PTD #2030360) passed a TIFL on 10/22/2012. The passing test proves the presence of competent tubing in the well. The well is reclassified as Operable. Please call if you have any questions. Thank you, SCANNED APR 0 9 2013 Shane Wills filling in for Gerald Murphy BP Alaska - Well Integrity Coordinator G& e Or lob aniza W tion ill ' WIC Office: 907.659.5102 WIC Email: AKDCWe1IIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Saturday, October 20, 2012 10:09 AM To: AK, D &C Well Integrity Coordinator; 'Schwartz, Guy L (DOA)'; 'Regg, James B (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Fowler, Craig (CH2M HILL); AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: 13 -13 (PTD #2030360) Sustained IA Casing Pressure Above MOASP All, Producer x.343 (PTD #2030360) has confirmed sustained IA casin• •ressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 386/2010/270 on 10/15/2012. The well has been reclassified as Under Evaluation. The well may remain online while work is oc nducted to attempt to restore integrity. Plan Forward: _ 1. DHD: TIFL �- 2. Pending TIFL results, evaluate for gas lift valve change out. C = 2610FS; ,K ' = 6870 A TIO plot and wellbore schematic have been included for reference. 1 • • Please call if you have any questions or concerns. Tha;ik you, Shane Wills filling in for Gerald Murphy BP Alaska - Well Integrity Coordinator Gv v " Glob& Wells Organization WIC Office: 907.659.5102 WIC Email: AKDCWe1IIntegrityCoordinator ABP.com 2 PBU 13 -13A PTD #2030360 10/20/2012 TIO Pressures Plot Well 13 -13 4.004 — -� — • 1 f Tbg 2.000 - OA OOA —0— 000A l — O^ 1.040 - at ;fir i �. i '*a-' • 0 &1011 09 1311111 - 111 ' - 123 01 +12112 02112 +12 03/1 04/1 4112 05114.12 06/1912 07/16/12 06/36/12 09/16!12 10/17172 TREE = CM/ WELLHEAD = FMC SA TES: WELL ANGLE> 70° @ 9568'. ACTUATOR= BAKER C 13 -13A * * *4- 1 /2 " CHROME TBG &NIPPLES* ** KB. ELEV = 77.20' BF. ELEV = 52,46' KOP = 8615' Max Angle = 96° @ 10158' I Datum MD = 9541' 1800' 9 -5/8" HES ES CEMENTER 1 tf Datum TV D= 8915' SS r , '� 1817' 1-19-5/8" ECP PKR, ID = ? ?? 1 LVAIV 9 -5/8" CSG, 47 #. L -80 HYD 563 1770' V V4 XO TO L -80 BTC ' � ' Ni 2017' H4-1/2" HES X NIP, ID = 3.813" 1 9 -5/8" BOWEN CSG PATCH, 47 #, --1 1844' L -80 BTC, ID = 8.681" GAS LIFT MANDRELS 13-3/8" CSG, 72 #, L-80, ID = 12.347" ! 2586' 1 ST � MD TVD 1 DEV TYPE VLV � LATCH PORT DATE 4 3452 3452 0 MMG DOME RK 16 05/23/09 3 5842 5768 If 21 MMG DOME RK 16 05/23/09 2 7295 7107 r 22 MMG DOME RK 16 05/23/09 1 8306 8012 r 24 MMG SO RK 24 05/23/09 Minimum ID = 3.725 @ 9084' 4-1/2" HES XN NIPPLE 8460' H9-5/8" X 7" ZXP LTP w /BKR HMC LNR HGR, ID = 6.290" 1 EA El 8957' 1- 14 -1/2" HES X NIP, ID= 3.813" 1 MILLOUT WINDOW 8615' - 8631' 8988' —17" X 4 -1/2" BKR S -3 PKR, ID = 3.875" 1 9021' 1- 14 -1/2" HES X NIP, ID = 3.813" J 'TOP OF WHIPSTOCK H 8615' '. 9084' J -14 -1/2" HES XN NIP, ID= 3.725" 1 • 9130' 1-17" X 4-1/2" UNIQUE OVERSHOT 1 .0 9134' 1- 14- 112" HES X NIP, ID = 3.813" 1 1 4 -1/2" TBG STUB (05/14/09) 1 9119' i /��' I � D% %ice,. 9155' 1-17" X 4 -1/2" BKR S -3 PKR, ID = 3.875" , 9179' 4 -1/2' HES X NIP, ID = 3.813" lor 9184' 1-17" X 5" BKR HR TIEBACK SLV J � w /EXTENSION, ID = 4.410 "? M tt . 9191' H4 -1/2" WLEG, ID = 3.958" 1 III "i 9193' 1- 7" X 5" BKR HMC LNR •�+ HGR, ID = 4.43" 9200' 1- 5" x 4 -1/2" XO, 19 -5/8" CSG, 47 #, L -80, ID = 8.681" 1 9201' 11� I♦ ID = 3.96" T � 1 � 4 4 t= i �liJ ,si �� o 1 � 1 �� / ‘ . 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" 1 9597' � jjjjQ j 1 TD H 9600' ! .aaaa.aa.ai ' . • 14 -1/2" TBG, 12.6 #, L -80 IBT, .0152 bpf, ID = 3.958" 1 9191' PERFORATION SUMMARY 17" LNR, 29 #, L -80, .0383 bpf, ID = 6.276" H 9344 1 REF LOG: ANGLE AT TOP PERF: 65° @ 9537' 4 -1/2" SLTD LNR, 12,6 #, L -80, .0152 bpf, ID = 3.958" 1 11095' Note: Refer to Production DB for historical perf data 14 -1/2" SOLID LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" 1 11263' SIZE SPF INTERVAL Opn /Sqz DATE SLOTTED LNR FISH: FASDRILL PLUG PUSHED TO BTM (05/13/09) 1 11271' 9537 - 11095 0 05/05/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/28/82 ORIGINAL COMPLETION 02/09/11 MB /JMD REMVD SSSV SAFETY NOTE WELL: 13 -13A 05/07/03 DAV /KK RIG SIDETRACK (13 -13A) PERMIT No: v 2030360 05/15/09 D14 RWO API No: 50- 029 - 20852 -01 05/19/09 TLH CORRECTIONS SEC 14, T1 ON, R14E, 855' FSL & 1076' FEL 07/13/09 MN/JMD DRLG DRAFT CORRECTIONS 12/20/10 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) • • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 10, 2012 a03 -0 u ECEWAVED Mr. Jim Regg 13 1 AUG 1 5 ?Di? Alaska Oil and Gas Conservation Commission 333 West 7 Avenue AOGCC Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -13 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 13 were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659-5102. Sincerely, 9/ Mehreen Vazir BPXA, Well integrity Coordinator III III BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -13 Date: 10131111 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal 13 -02B 1990110 50029203246000 Sealed conductor NA NA NA NA NA 13-03A 2090480 50029203250100 Sealed conductor NA NA NA NA NA 13 -04 1780630 50029203260000 Sealed conductor NA NA NA NA NA 13-05 1811030 50029206260000 Sealed conductor NA NA _ NA NA NA 13 -06A 1972180 50029206420100 Sealed conductor NA NA NA NA NA 13 -07 1811290 50029206500000 Sealed conductor NA NA NA NA NA 13-08A 1982150 50029206670100 Sealed conductor NA NA NA NA NA 13 -09 1811580 50029206710000 Sealed conductor NA NA NA NA NA 13 -10 1811650 50029206780000 Sealed conductor NA NA NA NA NA 13-11 1810760 50029206040000 0.0 NA 0.0 NA 11.1 10/31/2011 13 -12 1801420 50029205380000 Sealed conductor NA NA NA NA NA -----713-13A 2030360 50029208520100 0.4 NA 0.4 NA 11.1 10/31/2011 13-14 1821710 50029208450000 2.0 NA 2.0 NA 13.6 10/6/2009 13 -15 1821570 50029208310000 Sealed conductor NA NA NA NA NA 13 -16 1821480 50029208230000 0.4 NA 0.4 NA 13.6 10/31/2011 13 -17 1820260 50029207180000 Sealed conductor NA NA NA NA NA 13-18 1820350 50029207240000 Sealed conductor NA NA NA NA NA _ 13 -19 1811800 50029206900000 Seal conductor NA NA NA NA NA 13 -20 1820090 50029207050000 Sealed conductor NA NA NA NA NA 13 -21 1820530 50029207890000 Sealed conductor NA NA NA NA NA 13-22 1820770 _ 50029207490000 Sealed conductor NA NA NA NA NA 13 -23A 1820230 50029207150000 Sealed conductor NA NA NA NA NA 13 -24A 2042430 50029207390100 Sealed conductor NA NA NA NA NA 13 -25 1820910 50029207610000 Sealed conductor NA NA NA NA NA 13-26 1820740 50029207460000 Sealed conductor NA NA NA NA NA 13 -27 1961210 50029209490200 17.0 NA 17.0 NA 130.9 11/22/2009 13-28 1830600 50029209420000 5.0 NA 5.0 NA 144.5 11/19/2009 13 -29L1 2020690 50029209286000 Dust Cover NA NA NA NA NA 13-30C 2080870 50029207680300 Sealed conductor NA NA NA NA NA 13-31A 2051600 50029224590100 0.5 NA 0.5 NA 3.4 10/6/2009 13-32A 2012350 50029207980100 0.0 NA 0.0 NA 10.2 10/31/2011 13 -33 1821060 50029207730000 5.2 NA 5.2 NA 27.2 11/17/2009 13 -34 1821360 50029208110000 0.3 NA 0.3 NA 11.1 10/31/2011 13-35 1940410 50029224600000 0.9 NA 0.9 NA 5.1 , 11/17/2009 , 13 -36 1951670 50029226130000 0.0 - NA 0.0 NA 4.3 10/31/2011 13-37 2100820 50029234280000 3.8 NA 3.8 NA 33.2 10/31/2011 13 -98 1822070 50029208780000 1.0 NA 1.0 NA 5.1 10/6/2009 1 06/08/09 -- ~ U ~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-35 AYTO-00018 CROSS FLOW CHECK ~ 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE ~' ~ 05/15/09 1 1 O6-08A AV1H-00012 IBP/FBS/CFS/GRADIO/PRESS/T P 05/11/09 1 1 A-44 AWLS-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECKflBP ~ 05/17/09 1 1 H-29A AYOO-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK 05/06/09 1 1 15-45B ANHY-00010 PRODUCTION PROFILE ~- 05/09/09 1 1 13-13A AYTU-00033 USIT - ~~p ~ 05/08/09 1 1 M-198 AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A B1JJ-00018 MEM CNUSTP ! r 05/18/09 1 1 X-30A 62WY-00005 C MEM PROD PROFILE 05/10/09 1 1 12-23 AYKP-00021 USIT L - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1 Z-14B AZCM-00022 PROD PROFILE/JEWELRY LOG • (o- 05/20/09 1 1 L1-21 62NJ-00006 PRODUCTION PROFILE 05/24/09 1 1 A-31A AZCM-00023 USIT (,~ - Q ip G 05/22/09 1 1 H-196' B2WY-00004 MEM PROD PROFILE t- 05/07/09 1 1 G-16 AYKP-00022 SCMT / / - 05/09/09 1 1 M-19B AY3J-00024 SCMT - 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE yC/ ~ 04/21/09 1 1 11-04A AYOO-00028 USIT f ~ J -- 05/21/09 1 1 18-30 B1JJ-00015 MEM PROD PROFILE JG/ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ - ~ ( 05/11/09 1 1 3-37/L-35 AWL9-00035 PROD/INJECTION PROFILE 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 INJ PROFILE/RST WFL ~} /$/5 04/26/09 1 1 YLtASt AGKIVUWLtUGt titGCIY I CfT SiIa NINCi AIVU Fitl Uti1VIIVl9 VIVt GVYY tAGI't 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ ~~ ~t ~,g~ ~ ~ ~ ~ ~ ~ ~ „ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS l,h aY 2 9 2009 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate rrnm~~l1 E'~1a'S~~'t~rC~dls{e~f WeIItS ® Alter Casing , ®Pull Tubing _ ^ Perforate New Pool ^ Waiver ^ Other Anchorage ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drilf Number: BP Exploration (Alaska) Inc. ,® Development ^ Exploratory 203-036 . 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20852-01-00 7. KB Elevation (ft): 77 2' 9. Well Name and Number: PBU 13-13A- 8. Property Designation: 10. Field /Pool(s): _ ADL 028315 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 11263' - feet true vertical 9018' ' feet Plugs (measured) None Effective depth: measured 11263'' feet Junk (measured) None true vertical 9018' ' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2586' 13-3/8" 25$6' 2586' 4930 2670 Intermediate 8615' 9-5/8" 8615' 8298' 6870 4760 Production Liner 8884' 7" 8460' - 9344' 8154' - 8872' 7240 5410 Liner 2079' 4-1/2" 9184' - 11263' 8765' - 9018' 8430 7500 Perforation Depth MD (ft): Slotted section: 9537' - 11095' Perforation Depth TVD (ft): 8982' - 9017' 4-1/2", 12.6# 13Cr- 80 / L-80 9191' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packers 8988" & 9155' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 9109'. Cut and pull 9-5/8" casing from 1841'. Run 9-5/8" (47#, L-80) tieback to surface. Cement w/ 130 bbls Class 'G' w/Gas-Blok 1.16 730 cu ft / 629 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: 0 0 0 20 0 Subsequent to operation: 465 1557 4018 1650 395 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Explorato ry ®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 Mehrdad Nadem, 564-5941 309-129 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number Sig ture Phone 564-4750 Dat Sondra Stewman, 564-4750 Form 10-404 Revised 0412006 ~ Submit Original Only ~~~ ~ IOR TREE _ WRLHEAD = G ACTUATOR ___ __ ___ AXEL KB. ELEV = - 77.20' BF. ELEV = 52.46' KOP = 8615' Max Angle = 96° @ 10158' Datum MD = 9541' DatumTVD= 8915'SS 9-5/8" TIEBACK CSG, 47#, 1844' 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 25$6' SAFEf ES: ***4-1 /2" CHROME TBG** 2,016' - 4-1/2" HES "X" Nipple 1817' -- 9-5/8", 47#, L-80 Hyd-563 1817 9-5/8" ECP 1844' - 9-5/8" CSG Patch GAS LIFT MANDRELS Minimum ID = 3.725" @ 9084' 4-1 /2" HES XN NIPPLE 9-5/8" x 7" ZXP LTP, ID=6.290" $,460' - TOP OF WHIPSTOCK a-v2 rBG 12.6 ~3c~-3u 10=3.~5a~~ 9,119' MILLOUT WINDOW (13-13A) 8615' - 8631' 9-5/8" CSG, 47#, L-80, ID = 8.681" I-1 9201' 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I TD I-i 9600' 1191' J~ 4-1 /2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 9193' 7" X 5" BKR HMC LNR HGR, ID = ? '. `, ., .~ 4-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9190' ~ ~ ~ . PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: 65 @ 9537' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SLOTTED LNR 9537 - 11095 O 05/05/03 7" LNR, 29#, L-80, .0383 bpf, ID = 6.276" 9344' ` ~ . `, 4-1/2" SOLID LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 953T 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11095' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/28182 ORIGINAL COMPLETION 05/07/03 DAV/KK RIG SIDETRACK (13-13A) 08/28/03 TLH/TLH CORRECTIONS 05/15/09 D14 RWO 05/19/09 TLH CORRECTIONS FMC • RAY 50N ~..~ 1'C L. ~ U € 13-13A ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3452 3451 0 N1MG DCR RKP G 05 15/09 3 5342 5768 22 MMG DMY RK 0 05;15/09 2 7295 7107 22 MMG DMY RK 0 OSi15/09 1 8306 8012 24 MMG DMY RK 0 05/15/09 ' 8,957` HES 4-1i2" "X" Nipple, ID=3.813 8988` BKR 7" x 4-1 /2" S-3 . 9CR PKR 9,021 , X84 HES 4 1/2 XN Nip.3.725 9,29` 9-5/8" x 4-112" 13CR Unique Overshot 9155' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 9179' 4-1/2" HES X NIP, ID = 3.813" PRUDHOE BAY UNIT WELL; 13-13A PERMff No: 2030360 API No: 50-029-20852-01 SEC 14, T10N, R14E, 396.1' FNL & 2443.36' FEL BP Exploration (Alaska) 13-13A, Well History (Pre Rig Workover) Date Summary 4/11/2009 T/i/O = 180/0+/0+. Temp = SI. TBG, iA, & OA FLs (pre-rig). AL connected, SI C~3 casing valve. ALP = 1900 psi. T FL C«3 60' (1 bbl), IA FL near surface, OA FL C~ 160' (10 bbl). SV, WV =Shut. SSV, MV = Open. IA & OA = OTG. NOVP. 4/11/2009 T/IA/OA= SI/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP BT onto THA test void 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 and torqued "ET style" all were in good working condition PPPOT-IC RU 2 HP BT onto IC test void 0 psi. flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycle and torqued LDS "ET style" all were in good working condition "*" All LDS cycled out 1.5" ran in and torqued "~* 4/12/2009 T/I/O = 160/20/0. Temp= SI. IA FL (FB). ALP= 1800 psi, SI Q casing valve. IA FL @ 2730' (147 bbls). LRS on location pumping fluid down IA. SI LRS for 30 mins to let fluid settle. FL shot could be inconclusive due to suspended fluid in IA, shot was not "well pronounced". LRS has control of well head. 4/12/2009 T/I/0=180Nac/0 Temp = S/I. Attemt CMIT-TxIA to 3000 psi. MIT-OA (RWO Prep). Pumped 3 bbls of neat meth followed by 225 bbls of 120° crude to load and test IA. Never caught pressure (Out of fluid). DHD shot fluid level. Rig off IA and Rig up to OA. Pressured up OA with 8 bbls of 120° crude to reach 2000 psi. MIT-OA 2nd test lost 100 psi in 1st 15 minutes and 70 psi in 2nd 15 minutes for a total of 170 psi in a 30 minute test. Job postponed due to truck would be over hours. Bled down OA psi. FW HP's = 420Nac/5. SV, WV, SSV =Closed. MV, IAV, OAV =Open. 4/12/2009 T/I/0=160/0/0 CMIT Tx iA tested inconclusive to 3000 psi (Pre RWO). Loaded IA w/ 91 bbls crude and 5 bbls DSL for upcoming CMIT Tx IA. Tags hung and wellhead valves left in following positions, SV, SSV & WV = C. MV, IA & OA left open. FWP's = 16050/0. 4/12/2009 T/I/0=500Nac/0. Temp=Sl. TBG, IA, OA FL (for FB). AL SI C~3 casing valve. ALP=2000 psi. TBG FL C«3 24" (.36 bbl). IA FL C«2 1254' (67 BBL). OA FL C«3 126' (7.3 bbl). FB on location upon departure. 4/13/2009 T/1/0=220Nac/5, Temp= S/I, CMIT-TxIA PASSED to 3000 psi. MIT-OA PASSED to 2000 qsi (RWO Prep). Pressured up IA and Tbg with 51 bbls of 120° crude to 3000 psi. CMIT-TxIA lost 120/120 psi in 1st 15 minutes and 20/40 psi in 2nd 15 minutes for a total of 140/160 in a 30 minute test. Bled down pressure, rig off IA and rig up to OA. Pressured up OA with 2 bbls of 120° crude to reach 2000 psi. MIT- OA lost 100 psi in 1st 15 minutes and 40 psi in 2nd 15 minutes for a total of 120 psi in a 30 minute test. Bled down OA psi. FWHP's = 500/460/20. SV, WV, SSV =Closed. MV, IAV, OAV =Open. 4/16/2009 T/I/0=220/220/0 CMIT-TxIA PASSED to 3500 psi. (RWO Prep) Pumped 10.4 bbls crude down IA to reach test pressure for CMIT TxIA. T/IA lost 40/40 psi in the 1st 15 mins and 20/20 psi in the 2nd 15 mins for a total pressure loss of 60/60 psi in 30 min test. Bled T/IA. FWHP's = 0/0/0. Tags hung, SV, WV, SSV shut. MV, IA, OA open. 4/20/2009 WELL S/I ON ARRIVAL. IN THE PROCESS OF RIGGING UP TO PULL 4.5" TT PLUG. 4/21/2009 PULLED P-PRONG FROM 9 165' GI AA R a ~" ax _ai i it tznnv FRnnn a i_, _ s_ G_i~ (LOST ONE NUBBIN AND A FEW CHUNCKS OF PACKING OFF PLUG BODY) DRIFTED W/ 3.80" CENT. TO 9,250' SLM. (ALL CLEAR) WELL LEFT S/I AND NORMALED ON DEPARTURE. DSO NOTIFIED OF STATUS. 4/30/2009 T/I/O = 110/75/1. Temp = SI. T & IA FL (pre-EL FasDrill). Drilling scaffold on well. TBG FL C~ 120'. IA FL C~3 surface. SV, WV, MV = C. SSV = O. IA, OA = OTG. NOVP. Page 1 of 2 • 13-i 3A, Well History (Pre Rig Workover) Date Summary 4/30/2009 WELL SI ON ARRIVAL. T/I/O = 50/0/0, SWAB CLOSED, SSV OPEN, WING CLOSED. FLOW LINE AND WELLHOUSE REMOVED. RIH W/ HES FASDRILL 3.66 PLUG. SET HALIBURTON FASDRILL IN 4.5" TUBING, MID ELEMENT AT 9164' IN THE MIDDLE OF THE FIRST 10' PUP JOINT BELOW THE BAKER S-3 PACKER. POOH. 5/1/2009 MIT-T FASDRILL TO 3500 PSI, 80 PSI LOSS IN FIRST 15MIN, 40 PSI IN SECOND 15 MIN. PT GOOD. CUT TUBING AT 9104' WITH 3.65" POWERCUTTER. FINAL T/I/O = 80/0/0. VALVE POSIT DEPARTURE -SWAB CLOSED, MASTER OPEN, SSV OPEN. JOB COMPLETE. 5/1/2009 T/I/O = 0/0/0 Temp = SI Assist E-line pump as directed. MIT T to 3500 psi PASSED 1st attempt (RWO Prep) Pumped 3.7 bbls 40° diesel down TBG to reach test pressure, TBG lost 80 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 120 psi in 30 min test. Bleed TBG pressure, Bled back -3 bbls. Final WHP's 200/0/0 SLB on well C~ departure. Valve position C~ departure Swab, Wing = SI /SSV, Master, IA & OA =Open. 5/2/2009 T/I/O=0/0/0 Circ out TBG & IA. CMIT-TxIA to 1000 (INCONCLUSIVE) psi (pre RWO). Pumped 5 bbls neat meth, 997 bbls SW and 137 bbls DSL down TBG, up IA, throught jumper ine tot a flowline on well #14. U-Tubed DSL into IA for a freeze protect. CMIT-TxIA. Pumped 3.8 bbls diesel down IA to reach test pressure. TBG/IA lost 120/130 psi in the 1st 15 min, OA gained 300 psi in the 1st 15 min. TBG/IA lost 120/110 psi in the 2nd 15 min, OA gained 150 psi in the 2nd 15 min. 5/3/2009 T/I/O = 0/0/0, temp = S/I. CMIT TxIA "**PASS""" to 1000 psi. Rigged up to IA. Pressured up IA and TBG to 1000 psi with 3.5 bbls of 20° diesel. CMIT TxIA lost 20 20 psi in 1st 15 minutes and 0/0 psi in 2nd 15 minutes for a total 20/20 psi in 30 minute test. While performing CMIT left an open bleed on the OA. OA remained C~ 0 psi through out job. Bled T/IA down to 0 psi. FWHP = 0/0/0 Swab, Wing =Closed. SSV, Master, IA, OA =Open. 5/3/2009 CMIT-TxIAxOA to 1000 psi (Inconclusive). CMIT-TxIAxOA to 500 psi (Inconclusive). Attempted two CMIT-TxIAxOA at 1000 psi both with similar results. Pumped 0.6 bbls of diesel to reach test pressure. T/IA lost 20/20 psi and OA gained 20 psi in the 1st 15 min. T/I/O lost 20/20/10 psi in the 2nd 15 mins. Test carried out an additional 15 min. T/I/O lost 20/40/20 psi in the 3rd 15 mins for a total loss of 60/80/10 psi during a 45 min test. CMIT-TxIAxOA to 500 psi. Pumped 0.4 bbls diesel to reach test pressure. T/I/O lost 0/0/0 psi in the 1st 15 mins and T/I/O lost 0/20/20 psi in the 2nd 15 mins. Test carried out an additional 15 mins with T/I/O losing 0/20/20 psi for a total loss of 20/40/40 during a 45 min test. W HPs bled to 0 psi. Freeze protected hard line jumper with 5 bbls meth. FW HPs = 0/0/0 Valve positions at time of departure; SV shut, WV shut, SSV open, MV open, IA open, OA open. Page 2 of 2 BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: WORKOVER Start: 5/1/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: NABORS 2ES Rig Number: 2 ' Date , From - To Hours Task Code NPT Phase Description of Operations 5/4/2009 18:00 - 18:30 0.50 RIGD P PRE RD Rig floor. -Remove all service lines: hydraulic, water, air and steam. 18:30 - 19:30 1.00 RIGD P PRE Skid rig floor to moving position. 19:30 - 21:30 2.00 MOB P PRE Install Rear Boosters. Position to move off well. 21:30 - 23:00 1.50 MOB P PRE Wait on Security to finish moving Rig 2 ES. - Service Rig. 23:00 - 00:00 1.00 MOB P PRE Move from DS-12 to Mukluk Pad. 5/5/2009 00:00 - 03:00 3.00 MOB P PRE Continue to move from Mukluk Pad to DS # 13. 03:00 - 03:30 0.50 MOB P PRE Move rig to back side of DS 13 and position near well 13-13A. 03:30 - 05:00 1.50 RIGU P PRE -Remove rear boosters. -Install cellar heaters. -Install cellar doors. 05:00 - 06:00 1.00 CONS P PRE -Wait for ramp to be built to double stack rig mats. -Lay rig mats (double stack) to position rig over well. 06:00 - 08:00 2.00 RIGU P PRE -Position rig over well 13-13A. Shim rig. -Spot and berm rock washer. 08:00 - 09:00 1.00 RIGU P PRE Skid rig floor to drilling position. 09:00 - 10:00 1.00 RIGU P PRE RU service lines to rig floor (water, air and steam). SIMOPS: Hardline crew RU hard line, choke and tiger tank. -Acce t ri Q 10:00 10:00 - 13:00 3.00 RIGU P DECOMP -Install secondary valve in IA. -Remove blanking flanges and install pump in flanges. -RU lines to tubing and IA to displace out freeze protect. 13:00 - 14:00 1.00 WHSUR P DECOMP -Mobilize lubricator and RU same on tree. -Test lubricator to 500 psi x 5 min. -Pull BPV. -RD lubricator. 14:00 - 16:30 2.50 WHSUR P DECOMP Displace out freeze protect: -Check hard line w/ air. Test hard line w/ water to 3500 psi. Good test. -Pump 40 bbls seawater down IA, taking returns out tubing to tiger tank. 3 BPM C~ 240 psi. -Blow down lines and swap them. -Pump 200 bbls seawater down tubing, taking returns out IA to tiger tank. -Blow down lines. RU lines to take returns to pits. -Pump 40 bbls seawater down tubing, taking returns out IA to pits. Overboard 25 bbls to rockwasher, and take rest back to pits. 16:30 - 20:00 3.50 WHSUR P DECOMP -Verif well static. -FMC Re . d rod TWC in tubin hanger. -RU testin a ui ment. Test TWC f/ below to 1000 psi x 10 min on chart. -Test TWC f/ above to 3500 six 10 min one hart. -RD testing equipment and vac out tree. 20:00 - 21:30 1.50 WHSUR P DECOMP ND tree and adapter flange. Remove from cellar. -Barriers in place to ND tree: Fasdrill plug C~2 9164', TWC in tubing hanger. 21:30 - 00:00 2.50 BOPSU P DECOMP NU spacer spool, BOP stack and choke line. Printed: 5/18/2009 9:57:41 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To Hours Task Code NPT 5/5/2009 5/6/2009 21:30 - 00:00 00:00 - 01:00 2.50 1.00 BOPSU BOPSU P P Start: 5/1 /2009 Rig Release: 5/5/2003 Rig Number: 2 Phase. DECOMP Page 2 of 12 ~ Spud Date: 11/11/1982 End: Description of Operations 13-5/8" 5M BOP stack configuration: - Annular preventer - 3-1/2" x 6" VBR (top rams) - Blind Rams - Mud cross - 2-7/8" x 5" VBR (bottom rams) DECOMP Continue NU BOP's.- Install riser, flowline, bleed off line, hole fill line and covers. 01:00 - 02:30 1.50 BOPSU P DECOMP Install mouse hole. Remove long bales, 4-1/2" elevators and compensator. 02:30 - 04:00 1.50 BOPSU P DECOMP Rig up to test BOP's - MU floor valves, MU TCII XO to 4" test jt, fill stack and lines. 04:00 - 11:00 7.00 BOPSU P DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test components to 250 psi low - 3500 psi high x 5 min each on chart w/ 4" test jt. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 4" test jt. Test upper & lower rams w/ 4" & 4-1/2" test jts. Test witnessed by WSL and Toolpusher. John Crisp, AOGCC Rep, waived witness of test. -Perform accumulator test: 1. System pressure: 3000 psi. 2. Pressure after close: 1620 psi 3. 200 psi attained Q 37 sec. 4. Full pressure attained C~3 3 min 1 sec. 5. Nitrogen: 4 bottles 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. 4" Inside BOP, 4" FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP). 11:00 - 11:30 0.50 BOPSU P DECOMP -RD testing equipment. -Blow down choke manifold, choke line and kill line. -Install bales and elevators. -Suck out stack. 11:30 - 12:00 0.50 WHSUR P DECOMP Break down and readjust dutch system. 12:00 - 12:30 0.50 WHSUR P DECOMP Inspect and service top drive, blocks and drawworks. 12:30 - 13:30 1.00 WHSUR N WAIT DECOMP Wait on DSM to pull TWC. -Service skate, iron roughneck and air slips. 13:30 - 15:00 1.50 WHSUR P DECOMP -Mobilize lubricator to rig floor. -MU extension rods. MU lubricator to dutch system. -Test lubricator to 500 psi x 5 min on chart. -Pull TWC. -RD lubricator and dutch system. 15:00 - 16:00 1.00 PULL P DECOMP -MU XOs to 4" DP jt. Printed: 5/18/2009 9:57:41 AM • BP EXPLORATION Operations Summary Report Page 3 of 12 Legal Well Name: 1 3-13 Common W ell Name: 13-13A Spud Date: 11/11/1982 Event Nam e: WORKO VER Start : 5/1/2009 End: Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 5/5/2003 Rig Name: NABOB S 2ES Rig Number: 2 ' Date From - To Hours Task Code NPT Phase ~ Description of Operations 5/6/2009 15:00 - 16:00 1.00 PULL P DECOMP -RIH and screw into tubing hanger. BOLDS. -Pull tubing hanger to rig floor. Tubing hanger pull free w/ 150k pull. PUW 150k after tubing hanger pulled free (blocks weight 50k). 16:00 - 17:30 1.50 PULL P DECOMP Circulate S/S w/ 120 F seawater. 10 BPM C~ 60 psi. -Mobilze and RU tubing handling equipment. 17:30 - 00:00 6.50 PULL P DECOMP -LD 4" DP jt, XOs and tubing hanger. -Pull and LD 4-1/2" 12.6# L-80 IBT tubin and com letion equipment f/cut C~ 9104' to 2700'. 5/7/2009 00:00 - 03:00 3.00 PULL P DECOMP Cont. pulling and LD 4-1/2" 12.6# L-80 IBT tubing and completion equipment f/ 2700' to surface. -Total LD: 216 jts + 20.90' cutoff jt (flare in cut 4-3/4" OD) / 1 X-nipple assy / 6 GLM assys. 03:00 - 04:00 1.00 PULL P DECOMP -RD and clean tubing handling equipment. -Clear rig floor of tools not needed for upcoming operations. 04:00 - 05:00 1.00 CLEAN P DECOMP -Mobilize wear bushing to rig floor. -Mobilize BHA tools to rig floor. 05:00 - 05:30 0.50 WHSUR P DECOMP Install wear bushing. 05:30 - 07:30 2.00 CLEAN P DECOMP MU dressoff BHA w/ Shoe + Washpipe extensions + top dress mill (inside washover boot basket) + 7" casing scraper + Bumper Sub + Jars + 6 jts 4-3/4" DCs + 18 jts 4" DP (to space out 9-5/8" casing scraper) + 9-5/8" casing scraper. 07:30 - 08:30 1.00 CLEAN P DECOMP RIH on 4" DP 1x1 f/ 816 to 1350'. 08:30 - 10:30 2.00 CLEAN P DECOMP -Cut and slip drilling line (59.5') -Service top drive and blocks. 10:30 - 12:00 1.50 CLEAN P DECOMP Cont. RIH on 4" DP 1x1 f/ 1350' to 3472' 12:00 - 12:30 0.50 CLEAN P DECOMP Inspect and service top drive, blocks and drawworks. 12:30 - 14:00 1.50 CLEAN P DECOMP Cont. RIH on 4" DP f/ 3472' to 5700' 14:00 - 14:30 0.50 CLEAN P DECOMP Hold meeting in dog house w/ Steve Robinson and Paul Forman (BP). Discussed safety expectations. 14:30 - 17:30 3.00 CLEAN P DECOMP Cont. RIH on 4" DP 1x1 f/ 5700' to 9095'. Scrape int. 8950' - 9050' several times w/ 7" casing scraper. -MU top drive and obtain parameters: PUW 180k /SOW 148k / ROTW 175k. 1 k torque C~ 40 RPM 17:30 - 20:30 3.00 CLEAN P DECOMP -Break circulation w/ 126 gpm Q 240 psi. -Wash down and tag top of tubing stub ~ 9108'. Work over tubing stub and swallow 17'. Dressoff 1' top of tubing stub w/ top dress mill (leave top of tubing stub_@_9.109'). Max. WOB: 10k /Max. RPM: 80 /Max. torque: 5k. -Reciprocate over stub and swallow several times without rotation. 20:30 - 22:00 1.50 CLEAN P DECOMP Pump hi-vis sweep and circulate S/S. 462 gpm C~ 2320 psi. -Rack back 1 stand 4" DP. Blow down top drive. 22:00 - 00:00 2.00 CLEAN P DECOMP POOH f/ 9066' to 4420' 5/8/2009 00:00 - 01:30 1.50 CLEAN P DECOMP Cont. POOH f/ 4420' to 816' (BHA). 01:30 - 02:30 1.00 CLEAN P DECOMP -LD 9-5/8" casing scraper. -Rack back 6 stands 4" DP used to space out 9-5/8" casing scraper. Rack back 2 stands 4-3/4" DCs. -LD rest of BHA. 02:30 - 03:30 1.00 CLEAN P DECOMP Clear rig floor of BHA tools. 03:30 - 12:30 9.00 EVAL P DECOMP -Spot Schlumberger unit in place. -RU Schlumberger a-line equipment. -RIH w/ USIT log on a-line and take USIT log in cement / Printed: 5/18/2009 9:57:41 AM • BP EXPLORATION Page 4 of 12' Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: WORKOVER Start: 5/1/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: NABOBS 2ES Rig Number: 2 Date From - To Hours I~ Task I Code ~ NPT Phase ~ Description of Operations 5/8/2009 03:30 - 12:30 9.00 EVAL P DECOMP corrosion mode f/ 8400' to surface. 12:30 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 18:30 18:30 - 20:00 0.50 1.00 0.50 4.00 1.50 EVAL DHB CLEAN CLEAN DHB P P P N P REP DECOMP DECOMP DECOMP DECOMP DECOMP -Identif to of cement @ 1900'. RD Schlumberger a-line equipment. Mobilize 9-5/8" RBP and running tool to rig floor. MU same. Inspect and service top drive Troubleshoot and repair iron roughneck. -RIH w/ 9-5/8" RBP to 1988'. Obtain parameters: PUW 80k / SOW 80k. -Set RBP per HES Rep. Top RBP C~ 1987' / C.O.E ~ 1990'. 20:00 - 20:30 0.50 DHB P DECOMP -RU testing equipment. -Test RBP to 3500 psi x 10 min on chart. 26 stks to pressure up, -RD testing equipment. 20:30 - 21:30 1.00 CLEAN P DECOMP Displace well above RBP w/ 9.7 ppg brine. 10 BPM C~3 550 psi. Blow down top drive. 21:30 - 23:00 1.50 DHB P DECOMP Dum 2200# 20-40 mesh sand on top of RBP. -Rack back 1 stand 4" DP and pump 10 bbls brine down drill pipe (1/2 string volume). 1.5 BPM ~ 50 psi. 23:00 - 00:00 1.00 DHB P DECOMP Wait for sand to settle. 5/9/2009 00:00 - 01:00 1.00 DHB P DECOMP -RIH and tag top of sand ~ 1929'. -POOH to DCs. 01:00 - 02:00 1.00 FISH P DECOMP -Rack back 2 stands 4-3/4" DCs. -LD RBP running tool. -MU multistring cutter BHA. 02:00 - 04:30 2.50 FISH P DECOMP -RIH w/multistring cutter. -Locate collars C~3 1821' & 1863' (drill pipe measure). -Position cutter ~ 1841'. -Cut casing C~ 1841'. Observe 200 psi pressure in OA after cut. -Close ba and establish circulation out OA to ti er tank. 5 BPM ~ 580 psi. Open bag. 04:30 - 08:30 4.00 FISH P DECOMP -Pull and LD 2 jts 4" DP. -RU to pump heated diesel down drill pipe into OA. Close bag -Little Red tested lines w/ 3500 psi. -Little Red pump 60 bbls heated diesel down drill pipe and into OA, taking returns out OA to tiger tank. 1.75 BPM C 650 psi. -Displace diesel out of drill pipe and spot in OA w/ 20 bbls Safe Surf O pill. -Shut down pumps and let diesel soak in OA f/ 1 hr. -Pump 20 bbls Safe Surf O pill and follow w/ 250 bbls 9.7 ppg brine, taking returns out OA to tiger tank. -Open bag and circulate out brine to rock washer until clean up. 08:30 - 10:30 2.00 FISH P DECOMP POOH and LD multistring cutter. Clear rig floor. 10:30 - 11:30 1.00 WHSUR P DECOMP -Pull wear bushing. -Pull 9-5/8" packoff throw h BOP stack er FMC Re Packoff s lit while ullin it. 11:30 - 13:30 2.00 BOPSU P DECOMP -ND BOP, flow line and choke line -Remove 18" spacer spool and install stack back on tubing -Barriers in place: Fasdrill plug ~ 9164', 9-5/8" RBP C~ 1990' (COE). 13:30 - 14:00 0.50 FISH P DECOMP -MU spear assy. and RIH. Printed: 5/18/2009 9:57:41 AM • BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: WORKOVER Start: 5/1/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: NABOBS 2ES Rig Number: 2 Date From - To Hours - ~ Task Code NPT Phase 5/9/2009 13:30 - 14:00 0.501 FISH P ( DECOMP 14:00 - 16:00 I 2.001 WHSUR I P I I DECOMP Description of Operations -Engage spear in 9-5/8" casing. PU 2' and casing came free w/ 130k PUW (blocks weight 50k). -PU stack w/ tubing hanger (f/ brake C~ casing soooll. -Work packoff packing above bowl. -Set down casing and release spear. POOH spear assy -Remove packing f/ stump. -Set stack back. Install riser. -RIH w/spear, engage casing and PU 3'. -PU stack and remove emeraencv slips. 16:00 - 17:00 1.00 BOPSU P DECOMP -Set stack back and NU to casing spool. -Install choke line and flow line. -Verify no leaks at breaks. 17:00 - 17:30 0.50 FISH P DECOMP Pull 9-5/8" to rig floor. 17:30 - 18:30 1.00 FISH P DECOMP Pump Safe Surf O pill and circulate S/S. 8 BPM C~3 55 psi. 18:30 - 19:00 0.50 FISH P DECOMP Mobilize casing equipment to rig floor and RU same. 19:00 - 21:00 2.00 FISH P DECOMP -Disengage spear and LD same. LD top cut jt (7.85'). -LD 3 jts 9-5/8" 47# L-80 BTC casing. Pull triple bushing connection w/ 3rd joint pulled. -Resulted in pin up on 4th casing jt. after breaking out 3rd jt w/ triple bushing connection f/ string. 21:00 - 22:00 1.00 FISH N WAIT DECOMP -Requested a 9-5/8" BTC collar f/ CSP to MU on pin on top of 4th casing jt. to latch elevator and cont. LD casing. -Wait on delivery of collar. 22:00 - 00:00 2.00 FISH P DECOMP Cont. LD 9-5/8" 47# L-80 BTC casing. 5/10/2009 00:00 - 03:00 3.00 FISH P DECOMP Cont. LD 9-5/8" 47# L-80 BTC casin . -Total recovered: 44 jts + 20.08' cutoff jt (bottom) + 7.85' top cut jt. -Also recover triple bushing connection w/ jt #3 and 10 bow spring centralizers. 03:00 - 04:00 1.00 FISH P DECOMP RD casing equipment. Clear and clean rig floor. 04:00 - 06:00 2.00 BOPSU P DECOMP -Install test plug and 4" test jt. RU testing equipment. -Test breaks in BOP stack, tubing spool and choke line to 250 psi low - 3500 psi high x 5 min each on chart. -RD testing equipment. 06:00 - 06:30 0.50 WHSUR P DECOMP -Pull test plug. -Install wear bushing. -Blow down choke line. 06:30 - 09:30 3.00 CLEAN P DECOMP -Mobilize BHA tools to rig floor. -MU casin dressoff BHA w/ 13-3/8" casing scraper + 12 jts 6-1/4" DCs. 09:30 - 10:00 0.50 CLEAN P DECOMP RIH f/ 398' to top of casing stump C~3 1841'. 10:00 - 11:00 1.00 CLEAN P DECOMP -Dressoff casing stump w/dressoff shoe and swallow 7' in washpipe extension. Condition top of stump w/dressoff mill. -Work over stump several times without rotation. -PUW 95k /SOW 98k / ROTW 98k. -60 RPM Q 2-5k torque. 3k WOB. 186 gpm ~ 100 psi. 11:00 - 11:30 0.50 CLEAN P DECOMP -PU 5' above stump and pump 40 bbls Safe Surf O pill. Circulate pill S/S. -420 gpm C~3 510 psi. 11:30 - 12:00 0.50 CLEAN P DECOMP POOH to BHA. 12:00 - 12:30 0.50 CLEAN P DECOMP Inspect and service top drive, blocks and drawworks. 12:30 - 13:30 1.00 CLEAN P DECOMP -Rack back 4 stands 6-1/4" DCs. -LD rest of casing dressoff BHA. Printed: 5/18/2009 9:57:41 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To Hours Task. !Code, NPT ', 5/10/2009 13:30 - 14:30 1.50 CASE R P 14:30 - 16:00 16:00 - 19:00 3.00 CASE P DECOMP 19:00 - 19:30 0.50 CASE P DECOMP 19:30 - 20:00 0.50 CASE P DECOMP 20:00 - 21:00 1.00 CASE P DECOMP Start: 5/1 /2009 Rig Release: 5/5/2003 Rig Number: 2 Page 6 of 12 Spud Date: 11 /11 /1982 End: Phase Description of Operations DECOMP Pull wear ring. DECOMP -Mobilize casing equipment, centralizers, ES Cementer, pup jt and XOs to rig floor. -RU to run 9-5/8" HYD 563 casino w/ casino oatch. Install torque turn equipment. -PU casing patch /ECP assy. MU ES Cementer and BTC pin x HYD 563 XO. -Run 9-5/8" 47# L-80 HYD 563 casing. Total jts run: 47. -Bakerlok connections below ES Cementer. Torque turn HYD 563 connections to 15,800 ft-Ibs. -Install 1 floating centralizer in XO above ES Cementer. Install 1 floating centralizer per jt on jts 1-46. Total centralizers used: 47. -PUW 125k /SOW 125k (blocks weight 50k). -MU 9-5/8" HYD 563 pin x 3-1/2 IF box and 3-1/2 IF pin x 4 HT 38 box XOs to 4.84' pup jt. -MU assy to casing string. Screw in top drive. -Run down and tag top of casing stump C~ 1841'. Swallow 3' in casing patch and engage same. Set down 25k. Pull 30k over PUW. -Pull test casing patch to 250k. Slack off to 225k (100k over PUW /blocks weight 50k). Inflate ECP per Baker Rep: -Pressure up to 1000 psi and hold x 10 min. -Increase pressure to 1600 psi in 200 psi increments. -Increase pressure to 1700 psi and open ECP. Observe pressure drop to 1350 psi and stabilize as ECP inflates. -Pressure up back to 1700 psi and hold x 4 min. -Pressure to 2000 psi and hold f/ 10 min to pressure test v en t5 cementer per rtt5 tiep: -Bleed pressure off to 0. -Pressure up to 2800 psi and open ES Cementer. 21:00 - 21:30 0.50 CASE P DECOMP Circulate w/ warm 9.7 brine until returns @ 80 F. 21:30 - 22:30 1.00 CASE P DECOMP -RD XOs on pup jt. Remove short bales. -Install long bales. Blow down top drive. -Install HYD 563 pin x BTC box and BTC pin x ACME XOs. -RU cement head and cement hose. -PU casing back to 225k. 22:30 - 00:00 1.50 CASE P DECOMP -Circulate warm 9.7 ppg brine. 8 BPM @ 230 psi. -Hold PJSM on cementing while circulating. -Schlumberger prime pumps. -Schlumberger pump 5 bbls water. Pressure test lines to 4000 psi. -Schlumberger batch up to start cement job. 5/11/2009 00:00 - 00:30 0.50 CASE P DECOMP -Schlumberger pumps 130 bbls 15.8 ppq class G cement w/ GASBLOK. Yield: 1.16 ft3/sk -Drop closing plug. -Kick plug w/ 5 bbls water. -Switch to rig pumps to displace cement. 00:30 - 01:00 0.50 CASE P DECOMP -Displace cement w/ 9.7 ppg brine C~ 6 BPM. -Catch cement C~ 530 stks pumped away. Printetl: 5/18/2009 9:57:41 AM • BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: i3-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: WORKOVER Start: 5/1/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: NABOBS 2ES Rig Number: 2 Date From - To Hours Task 'Code NPT __ 5/11/2009 00:30 - 01:00 ~ 0.50 CASE P 01:00 - 02:30 I 1.501 CASE I P 02:30 - 03:30 1.00 BOPSUF~P 03:30 - 06:30 3.00 WHSUR P 06:30 - 08:30 I 2.001 WHSUR I P 09:30 - 00:30 1.00 BOPSU~P 10:30 - 11:00 0.50 WHSUR P 11:00 - 12:00 1.00 CLEAN P 12:00 - 12:30 0.50 CLEAN P 12:30 - 13:00 0.50 CLEAN P 13:00 - 13:30 0.50 CLEAN P 13:30 - 14;30 I 1.001 CLEAN I P 14:30 - 16:00 I 1.501 CLEAN I P 16:00 - 17:30 I 1.501 CLEAN I P 17:30 - 18:00 0.50 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 19:30 ~ 1.00 CLEAN ~ P 19:30 - 20:00 0.501 CLEAN P Phase Description of Operations DECOMP -Circulating pressure 700 psi C~3 1100 stks away. Observe cement returns to surface C~ 1100 stks away. -Slow pump rate to 2 BPM Q 115 st s away. Circulating pressure 600 psi after slowing pump rate. -Bump plug w/ 1264 stks and 620 psi FCP. -Cont. pressure up to 1700 psi and close ES Cementer. -Cont pressure up to 2000 psi and hold x 5 min. -Bleed off pressure and check floats. OK. -Total cement returns to surface: 17 bbls. -CIP C~3 01:00 -Keep 225k pull (100k over PUW, blocks weight 50k) in casing during all cement job. DECOMP -Flush stack w/ treated water. -RD cement head and cement hose. -Blow down lines to stack. DECOMP ND BOP w/ tubing spool and lift. DECOMP -Install emergency slips. -Set casing on emergency slips w/ 100k over PUW. -Cut casing w/ Wachs cutter. -LD cut jt (29.31') w/ pup jt and XO. DECOMP Install 9-5/8" packoff. Test same to 3800 psi x 30 min per FMC Rep. DECOMP NU BOP. DECOMP -Set test plug and 4" test jt. RU to test breaks in BOP. -Test breaks in BOP to 250 psi low - 3500 psi high x 5 min -RD testing equipment. Pull test plug. DECOMP Install wear bushing. DECOMP -Break down spear assy. -Start mobilizing tools for next BHA to rig floor. DECOMP Inspect and service top drive, blocks and drawworks. DECOMP Cont. mobilizing tools for next BHA to rig floor. DECOMP MU BHA w/ 8-1/2" bit + 2 boot baskets + bumper sub + jars + pump out sub + 4 std 6-1/4" DCs. DECOMP -RIH f/ 398' to 1720'. -MU top drive. Break circulation w/ 5 BPM @ 180 psi. -Obtain parameters: PUW 93k /SOW 95k / ROTW 92k. 0 k torque @ 60 RPM. DECOMP -Run down and to closin lu C~ 1799'. -Drill out closing plug and ES Cementer. Work through 5x. Check without rotation. OK. -2-7k WOB. Max torque: 2k. DECOMP -RU testing equipment. -Test casing to 3500 psi x 30 min on chart. -RD testing equipment. DECOMP Cont. RIH to 1907'. MU top drive and break circulation w/ 5 BPM ~ 150 psi. DECOMP -Run down and tag sand /junk C~ 1927'. -Dry drill to 1932'. PU to 1907' DECOMP -Pump hi-vis sweep. -Displace well w/ seawater. 8.5 BPM ~ 400 psi. -Blow down top drive. DECOMP POOH f/ 1907' to 398' (BHA). Printed: 5/18/2009 9:57:41 AM BP EXPLORATION Page 8 of 12 ~ Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: WORKOVER Start: 5/1/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: NABOBS 2ES Rig Number: 2 Date I From - To I '~, Hours ' Task ,Code NPT Phase. Description of Operations 5/11/2009 20:00 - 21:00 1.00 CLEAN P DECOMP -Rack back 4 std 6-1/4" DCs. -LD bit and boot baskets. -Clean boot baskets: recover small aluminum and brass fragments f/ ES Cementer, and small steel fragments f/ centralizer slabs. -Mobilize RCJB to rig floor. 21:00 - 22:00 1.00 CLEAN P DECOMP MU BHA w/ RCJB + 2 boot baskets + 9-5/8" casing scraper + bumper sub +jars + pump out sub + 4 std 6-1/4" DCs. 22:00 - 22:30 0.50 CLEAN P DECOMP -RIH f/ 408' to 1924'. -MU top drive and break circulation w/ 6 BPM @ 640 psi. 22:30 - 23:00 0.50 CLEAN P DECOMP -Drop ball. Establish circulation w/ 6 BPM @ 2500 psi. -Wash down and taq funk @ 1930'. 23:00 - 23:30 0.50 CLEAN P 23:30 - 00:00 0.50 CLEAN P 5/12/2009 00:00 - 00:30 0.50 CLEAN P 00:30 - 02:30 2.00 CLEAN P 02:30 - 03:00 0.50 CLEAN P 03:00 - 04:00 1.00 CLEAN P 04:00 - 04:30 0.50 CLEAN P 04:30 - 06:00 1.50 CLEAN P 06:00 - 06:30 I 0.501 CLEAN I P 06:30 - 07:30 ( 1.00 I CLEAN I P 07:30 - 08:00 0.50 CLEAN P 08:00 - 11:00 3.00 CLEAN P 11:00 - 12:00 1.00 CLEAN P 12:00 - 12:30 0.50 CLEAN P 12:30 - 13:00 0.50 CLEAN P -Attem t to work RCJB over'unk without success. DECOMP CBU w/ 7.5 BPM @ 3100 psi. Blow down top drive. DECOMP POOH f/ 1924' to 408' (BHA) DECOMP Lubricate rig. Inspect top drive. DECOMP -Stand back BHA. -Clean RCJB. Recover large aluminum and brass fragments f/, ES Cementer and feces of closing plug. -No junk in boot baskets. -LD RCJB and 9-5/8" casing scraper. -PU and MU 8-1/2"junk mill. -Run BHA in hole. DECOMP RIH f/ 400' to 1920'. DECOMP -MU top drive. Run down and tag junk on top of sand @ 1930'. -Dry mill to 1934' and break junk on top of sand. 50 RPM @ 1-4k torque. 6k WOB. -Pump hi-vis sweep and circulate S/S. 6 BPM @ 270 psi. DECOMP POH f/ 1934' to 400' (BHA) DECOMP -Stand back BHA. Junk mill with good marks of having worked on junk. -Clean out boot baskets: some small aluminum pieces, one small steel piece from stabilizer. -PU RCJB. RIH rest of BHA. DECOMP -RIH f/ 404' to 1920'. -Drop ball. DECOMP -Run down and tag sand/debris @ 1936'. -PU 10' and start pumps. 6 BPM @ 2300 psi. -Rotate down and wash sand to 1962'. 20 RPM @ 1 k torque. -CBU. DECOMP POOH f/ 1962' to 404' (BHA). DECOMP -Rack back 6-1/4" DCs. -LD tools. several steel pieces f/ bow spring stabilizers. -Clean out boot baskets. Recover several metal pieces and shavings. -Clear rig floor of tools. -Mobilize RBP retrieving tool to rig floor. DECOMP RIH 4 std 6-1/4" DCs, then LD same. DECOMP Inspect and service top drive, blocks and drawworks. DECOMP -Finish LD 6-1/4" DCs. -MU RBP retrieving tool and RIH on 2 std 4-3/4" DCs. Printed: 5/18/2009 9:57:41 AM • BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: WORKOVER Start: 5/1/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: NABOBS 2ES Rig Number: 2 Date i From - To Hours Task Code NPT Phase I' Description of Operations 5/12/2009 13:00 - 13:30 0.50 CLEAN P DECOMP RIH to 1800'. 13:30 - 14:30 1.00 CLEAN P DECOMP -Cut and slip drilling line (59.5') -Inspect brake bands and linkage. 14:30 - 15:30 1.00 DHB P DECOMP -Run down to 1912' MU top drive. -Ta sand @ 1962'. PU 10' and break circulation w/ 8 BPM 310 psi. -Wash down sand and latch RBP @ 1987'. Retrieve RBP. 15:30 - 16:30 1.00 CLEAN P DECOMP -Pump hi-vis sweep and circulate S/S. 8 BPM C~ 350 psi. -Rack back 1 stand. Blow down top drive. 16:30 - 17:00 0.50 CLEAN P DECOMP POOH f/ 1912' to 201' (DCs). 17:00 - 18:00 1.00 CLEAN P DECOMP -Rack back 2 std 4-3/4" DCs. 18:00-18:30 0.50 WHSUR~P 18:30 - 19:30 1.00 BOPSU P 19:30 - 00:00 4.50 BOPSU P 5/13/2009 100:00 - 01:00 I 1.00 BOPSUp P 01:00 - 02:00 I 1.001 BOPSUR P 02:00 - 03:00 I 1.001 CLEAN I P -Clear rig floor. DECOMP Pull wear bushing. DECOMP RU to test BOP. DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test components to 250 psi low - 3500 psi high x 5 min each on chart w/ 4" test jt. Test upper rams w/ 4" & 4-1/2" test jts to 250 psi low - 3500 psi high x 5 min each on chart. Test bottom rams w/ 4-1/2" test jt to 250 psi low - 3500 psi high x 5 min each on chart. Test witnessed by WSL, Tourpusher and AOGCC Rep (Jeff Jones). -Perform accumulator test: 1. System pressure: 3000 psi. 2. Pressure after close: 1700 psi 3. 200 psi attained C~ 31 sec. 4. Full pressure attained (~ 2 min 36 sec. 5. Nitrogen: 4 bottles x 2190 psi avg. DECOMP Finish testing BOP: -Test bottom rams w/ 2-7/8" test jt to 250 psi low - 3500 psi high x 5 min each on chart. -Test annular preventer w/ 2-7/8" test jt to 250 psi low - 3500 psi high x 5 min each on chart. -Test witnessed by WSL, Tourpusher and AOGCC Rep (Jeff Jones). Summary of test: 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. 4" Inside BOP, 4" FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP). DECOMP -RD testing equipment. -Install wear bushing. -Blow down choke and kill line. DECOMP -Mobilize 2-7/8" DP handling equipment to rig floor. -RU power tongs. Printed: 5/18/2009 9:57:41 AM • BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: WORKOVER Start: 5/1/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: NABOBS 2ES Rig Number: 2 Date From - To Hours Task Code NPT `Phase Description of Operations 5/13/2009 03:00 - 06:00 3.00 CLEAN P DECOMP -MU 3-3/4"junk mill. -PU 2-7/8" PAC DP 1x1 75 'ts). 06:00 - 07:30 1.50 CLEAN P DECOMP MU XOs, bumper sub, jars, pump out sub and 2 std 4-3/4" DCs. 07:30 - 10:00 2.50 CLEAN P DECOMP n 4" DP to 9050'. 10:00 - 12:00 2.00 CLEAN P DECOMP Dis lace well w/ clean seawater. 6 BPM ~ 3050 psi. -Obtain parameters: PUW 165k /SOW 155k / ROTW 160k. 1 k torque @ 50 RPM. 12:00 - 12:30 0.50 CLEAN P DECOMP -Wash down ~ 3 BPM / 440 psi and enter tubing stump. -Cont. washing down in tubing stump C~ 3 BPM / 790 psi and 12:30 - 13:30 1.00 CLEAN P DECOMP -Drill out Fasdrill plug. 50 RPM C~ 1-3k torque. 2-5k WOB. 3 BPM ~ 790 psi. -Well on vac after drilling out plug. -Work through 3 times. 13:30 - 16:00 2.50 CLEAN P DECOMP -Cont RIH f/ 9200' to 10480'. MU top drive and pump 15 bbls seawater away every 15 min. -Tap plug remains C~ 10480' and push them to 11109' (bottom slotted liner). -Rotate and wash down pushing plug remains to 11271' (bottom of 4-1/2" lined. 16:00 - 16:30 0.50 CLEAN P DECOMP -Mobilize f5~e~tectors to rig floor. -LD 1 std 4" DP. Blow down top drive. -Pumping 15 bbls seawater every 15 min (60 bph). 16:30 - 17:00 0.50 CLEAN P DECOMP Inspect and service top drive, blocks and drawworks. 17:00 - 23:00 6.00 CLEAN P DECOMP POOH and LD 4" DP (282 jts total). -Cont. pumping 15 bbls seawater in hole every 15 min. (60 bph). 23:00 - 23:30 0.50 CLEAN P DECOMP LD 6 jts 4-3/4" DCs, jars, bumper sub, pump out sub and XOs. 23:30 - 00:00 0.50 CLEAN P DECOMP -Clear rig floor of BHA tools. -C/O elevators and RU power tongs to LD 2-7/8" DP. -Cont. pumping 15 bbls seawater in hole every 15 min. (60 bph). 5/14/2009 00:00 - 00:30 0.50 CLEAN P DECOMP Lubricate rig and inspect top drive. 00:30 - 03:30 3.00 CLEAN P DECOMP POOH and LD 75 jts 2-7/8" PAC DP. -LD 3-3/4"junk mill. -Clear rig floor. -Cont. pumping 15 bbls seawater in hole every 15 min. (60 bph). 03:30 - 04:00 0.50 WHSUR P DECOMP Pull wear bushing 04:00 - 06:00 2.00 BUNCO P RUNCMP RU to run 4-1/2" 13Cr Vam Top tubing and completion: -MU XO to floor valve. -Install long bales, elevators and compensator. -Install power tongs and torque turn equipment. -Load jewelry in pipe shed. -Cont. pumping 15 bbls in hole every 15 min. (60 bph). 06:00 - 12:00 6.00 BUNCO P RUNCMP -MU 7" x 4-1/2" Unique Overshot assy + XN nipple assy + 1 jt 4-1/2" 12.6# 13Cr Vam Top tubing (w/ Bakerlok collar) + X nipple assy w/ RHC-M plug + 7" x 4-1/2" S-3 Packer assy + X nipple assy. -Run 4-1/2" 12.6# 13Cr Vam Top and completion eauipment to 3400'. -Bakerlok all connections below packer. Printed: 5/18/2009 9:57:41 AM BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: 13-13 Common W ell Name: 13-13A Spud Date: 11/11/1982 Event Nam e: WORKO VER Start : 5/1/2009 End: Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 5/5/2003 Rig Name: NABOB S 2ES Rig Number: 2 Date From - To Hours Task Code NPT Phase Description of Operations 5/14/2009 06:00 - 12:00 6.00 BUNCO P RUNCMP -Torque turn connections to 4440 ft-Ibs. -Pumping 15 bbls seawater every 15 min (60 bph). 12:00 - 12:30 0.50 BUNCO P RUNCMP Inspect and service top drive, blocks and drawworks. 12:30 - 18:30 6.00 BUNCO P RUNCMP -Cont. running 4-1/2" 12.6# 13Cr Vam Top tubing and completion equipment to 9089'. Total jts run: 215. -Obtain parameters: PUW 152k /SOW 140k (blocks weight 50k). -PU jt #216. Run down and taq top of tubing stump @ 9119'. Swallow tubing stump w/ Unique Overshot and observe first set of shear pins @ 9123' (bottom of Unique Overshot). Shear pins w/ 12k. -PU jt #217. Cont running down and observe second set of shear pins @ 9131' (bottom of Unique Overshot). Shear pins w/ 12k. Bottom out on tubing stump @ 9133' (bottom of Unique Oveerhot). -Pumping 15 bbls seawater every 15 min (60 bph). i 18:30 - 20:00 1.50 BUNCO P RUNCMP Space out completion and land on tubing hanger: -LD jts # 217, 216 and 215. ', -MU 5.82' & 3.84' pup jts to jt #214. '~ -MU jt #215 and RIH. -MU tubing hanger and landing jt. -Land tubing hanger. RILDS. 20:00 - 23:30 3.50 BUNCO P RUNCMP -RU to reverse circulate. -Pump down IA 140 bbls seawater followed by 280 bbls seawater w/ corrsion inhibitor @ 3BPM / 160 psi. No returns while pumping. 23:30 - 00:00 0.50 BUNCO P RUNCMP -RD return line in tubing. -RU to pump down tubing. -Dro ball-and-rod. -Fill tubing and purge air w/ seawater. 5/15/2009 00:00 - 01:30 1.50 BUNCO P RUNCMP -Cont. filling tubing and purging air w/ seawater. -Pressure u tubin to 3500 si and set acker. -Hold 3500 six 30 min on chart. Test ood. -Bleed down pressure in tubin to 1500 si. 01:30 - 03:30 2.00 BUNCO P RUNCMP -Line to um down IA. Fill IA and ur a air w/ seawater (50 bbls to fill . -Pressure up IA to 3500 psi and hold x 30 min on chart. Test -Bleed off pressure in tubing. Observe DCK-2 valve shear @ 2500 psi differential f/ IA. -Cont. bleeding off tubing and IA. -Pump down IA, taking returns out tubing. 3BPM @ 460 psi. -Pump down tubing, taking returns out IA. 3BPM @ 250 psi. 03:30 - 05:00 1.50 WHSUR P RUNCMP -LD landing jt. -FMC Rep. dry rod in TWC. -Test TWC f/ below to 1000 psi x 10 min on chart. -Test TWC f/above to 3500 six 10 min on chart. 05:00 - 06:00 1.00 BOPSU P RUNCMP -Blow down lines to stack. -Vac out stack. 06:00 - 07:30 1.50 BOPSU P RUNCMP ND BOP. -Barriers in place: Production packer set and tested, tubing hanger w/TWC tested. Printed: 5/18/2009 9:57:41 AM ~ i BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: 13-13 Common Well Name: 13-13A Spud Date: 11/11/1982 Event Name: WORKOVER Start: 5/1/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/5/2003 Rig Name: NABOBS 2ES Rig Number: 2 ..Date From - To ~ Hours I Task Code ~ NPT Phase Description of Operations 5/15/2009 07:30 - 10:30 3.00 WHSUR P RUNCMP -NU adapter flange and tree. -Test adapter flange to 5000 psi x 30 min per FMC Rep. -Fill tree w/diesel. Test tree to 5000 psi x 10 min. 10:30 - 12:00 1.50 WHSUR P RUNCMP -RU DSM lubricator on tree. -Test lubricator to 500 osi x 5 min on chart. -RD lubricator. Pull lubricator to rig floor and keep there. 12:00 - 14:00 2.00 WHSUR P RUNCMP -RU Little Red Services. Test lines to 3500 psi. -Little Red pump 145 bbls 70 F diesel down IA, taking returns out tubing. 3 BPM ~ 400 psi. 14:00 - 15:30 1.50 WHSUR P RUNCMP Allow diesel to u-tube. SIMOPS: Slip on drilling line to LD top drive while u-tubing diesel. 15:30 - 18:00 2.50 WHSUR P RUNCMP -Bleed off and suck lines. -Install lubricator. Set BPV. RD lubricator. -Test BPV f/ below to 1000 psi x 10 min on chart w/diesel (u: Little Red to test). -Bleed off and suck lines. RD Little Red. 18:00 - 19:30 1.50 WHSUR P RUNCMP -Remove secondary valve in IA and pump in flanges. -Install blank flanges and gauges. -Secure tree and cellar. OA=Opsi/IA=Opsi/TBG=Opsi. 19:30 - 00:00 4.50 RIGD P POST -RD stand pipe, cement line and mud manifold and remove f/ rig floor. -Remove mud bucket and hand slips f/ rig floor. -RD torque tube and link tilt yoke. Remove IBOP. -RD rig tongs. Tie off hanging lines. -Install bale brace. Release riq /close operations in well 13-13A. Printed: 5/18/2009 9:57:41 AM • ~~G~~L~ U~ ~~ L~2~~~~~' % ,.a..a.µ~o~..~. •~.A58A OII, A1~TD GA5 J 333 W 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~T COMr-IIS5I01'IT / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem ~ ~~:~ Engineering Team Leader ~ ~ ~~~ ~ `~ L ~~ BP Exploration Alaska Inc. ~~'~`~- PO Box 196612 Anchorage AK 99519-6612 ~~~ d ~ ~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-13A Sundry Number: 309-129 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. Sincerely, Cathy P. Foerster Commissioner DATED this ~ day of April, 2009 Encl. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM111~ION APPLICATION FOR SUNDRY APPROVAL qty 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ®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 203-036 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20852-01-00 - 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 13-13A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028315 ~ 77.2' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12- PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11263' ~ 9018' - 11263' - 9018' - 9179' None in L n h M D Coll tru ural r 7' 7' 1 rf 586' 13-3/8" 2586' 586' 4 2670 Int rme i 15' - / " 8 1 298' 687 47 Lin r 884' 7" ' - 9344' 1 4' - 887 ' 724 10 Liner 079' 4-1/2" 184' - 112 876 ' - 018' 84 75 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Section: 9537' -11095' 8982' - 9017' 4-112", 12.6# L-80 9191' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 9155' 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 erations: April 20, 2009 ~ ®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 Mehrdad Nadem, 564-5941 Printed Name D Reem Title Engineering Team Leader Prepared By N~ne/Number: Signature C Phone 564-5743 Date ¢ s ~ ~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Wei,<S'~; ~ O f ~"~ S„~~ ^ Plug Integrity I~BOP Test ^ Mechanical Integrity Test ^ Location Clearance ®~/'~ ~~ ry Other: ~`~pSl~ rUh~"T~~j"'i ~ ~~~ P5 ~ M\'n~~v ~ Urt~~~ ~a.~~ ~Ilaska Cll & Gay C~n~x Cnmf~l~s~siofl Subsequent Form Required: ~~Dy Ah~hara APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date ~ - / - ~ ~ Form 10-403 Revised Oj~`/2006 ~ ~ ~~ ~ L ~ A~~ ~ t# z~Q~ Submit In Duplicate ,~"~~3~~ ~~~ ~i~ 09 a ~~-~~ ~a ~~ • by GP 13-13A Expense Rig Workover Scope of Work: Repair IA x OA communication to gas. Pull 4-~/z" ,12.6#, L-80 completion, cut and pull 9-5/8" casing above cement top, run and cement to surface 9-5/8" casing, test 9-5/8" casing, run 4-1/2" 13CR-80 completion. MASP: 2419 psi Well Type: Producer Estimated Start Date: April 20, 2009 Production Engineer: Olivia Bommarito Intervention Engineer: Mehrdad Nadem Pre-Rip Work Reauest: F 1 MIT-OA to 2,000 si. CMIT - T x IA to 3,500 si. S 2 Pull PX lu C~ 9,179'. Drift the 4-1/2" for FasDrill. E 3 Set FasDrill plug at 9,161' in the middle of the first 10' pup joint below the S-3 production packer (reference tubing tally dated 05-05-2003), pressure test the FasDrill to 3500 si to verif it as a com etent barrier. E 4 Power Jet cut 4-~/z" L-80 tubing at 9,104' MD, in the middle of the first full joint above the acker. F 5 Circulate well with clean seawater and freeze rotect to 2000'. 6 6 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 7 Set a BPV in the tubin han er. O 8 Verify that the well has a competent cellar. Remove the wellhouse & flow line. Level the ad as needed for the ri . O 9 Excavate the cellar as needed to line the cellar around the wellhead with impermeable, s ra -sealed Herculite. Execution of this ste de ends on the result of MIT-OA. Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-~/z" x 6" VBR pipe rams and test with 4" and 4-1/2" test joints. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-~/z" tubing string down to the cut. 3. Run USIT log from the tubing stub to 13-3/8" shoe in corrosion mode and in cement detection mode from the 13-3/8" shoe to surface. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 1500 psi for 15 minutes.. 5. Cut and pull 9-5/8" casing from above the top of cement. Note: Pipe rams will not be changed to~~~y~ 9-5/8" as the well has two tested barriers (FasDrill and RBP) to the reservoir. 6. Run and fully cement new 9-5/8" casing gsurface. `~Qa~dv~~ ~~csS~~i~~s~ ~S~l 7. Retrieve bridge plug. 8. Drill FasDrill and push to the bottom of the production liner. `"((t~ 9. Run 4-1h" 13Cr-80 stacker packer completion with Baker S-3 packer. • 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2000' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = FMC WELLHEAD = ACTUATOR = AXELSON KB. ELEV - 77.20' BF. ELEV - 52.46' KOP = ..... .............8615' Max Angle = 96° @ 10158' Datum MD = 9541' Datum TV D = 8915' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 13-13A I 2586' I S TES: 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS Minimum ID = 3.813" @ 2170' 4-1 /2" HES X NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2976 2976 1 MMG-M DOME RK 16 03/13/08 5 3899 3899 1 MMG-M DMY RK 0 01/06/08 4 5782 5713 21 MMG-M DOME RK 16 03/13/08 3 6427 6308 24 MMG-M DMY RK 0 01 /06!05 2 7726 7494 29 MMG-M SO RK 20 03/13/08 1 8287 7995 24 MMG-M DMY RK 0 01/06/08 9-5/8" X 7" ZXP LTP, ID = 6.290" I TOP OF WHIPSTOCK I MILLOUT WINDOW (13-13A) 8615' - 8631' 4-1/2" HES X NIP, ID = 3.813" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 65 @ 9537' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE SLOTTED LNR - 11095 ~ C i 05/05/03 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 9201' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 9597' ~TD~- 7" LNR, 29#, L-80, .0383 bpf, ID = 6.276" 9344' ` ` ~ . ` `, ~- u~ 4-1/2" SOLID LNR 12.6#, L-80, .0152 bpf, ID = 3.958" 9537' 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11095' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/28/82 ORIGINAL COMPLETION 01/15/08 DAV/PJC GLV GO (01/06/08) 05/07/03 DAV/KK RIGSIDEfRACK(13-13A) 02/06/08 JLJ/PJC HES NIP CORRECTION 08/28/03 TLWTLH CORRECTIONS 03/13/08 GJF/TLH GLV GO 09/04/03 TLWKK HES X NIP DEPTH CORRECTION 11/21/08 BSEITLH PX PLUG SET (10/20/08) 10/09/05 RPWTLH WAIVERSFTY NOTE DELETED 05/31/06 DTM WELLHEAD CORRECTIONS PRUDHOE BAY UNff WELL: 13-13A PERMff No: r`2030360 API No: 50-029-20852-01 SEC 14, T10N, R14E, 396.1' FNL & 2443.36' FEL BP 6cploration (Alaska) 7" X 4-1/2" BKR S-3 PKR ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 4-1/2" PX PLUG (10/20/08) 9191' 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 9193' 7" X 5" BKR HMC LNR HGR, ID = ? 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9190' TREE = FMC WELLHEAD = ACTUATOR = AXELSON KB. ELEV = 77.20' $F. ELEV = 52.46' KOP = 8615' Max Angle = 96° @ 10158' Datum MD = 954 1' Datum TV D = _ 8915' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~13-13A Proposed s TES: 2,200`- 4-1/2" HES "X" Nipple 2,280` 9-5/8", 47#, L-80 Hyd-563 2,280` -- 9-5/8" ECP 2586' 2,300`-9-5/8" CSG Patch Gas Lift Mandrels 9-5/8" X 7" ZXP LTP, ID = 6.290" 4-1 /2" TBG, 12.6" 13CR-80, ID=3.958" 9,104` 9-5/8" x 7" ZXP LTP, ID=6.290" 8,460` MILLOUT WINDOW (13-13A) 8615' - 8631' ST MD TVD TYPE 4 45 4- x - 3 5822 5750 4-1/2" x 1-1/2" 2 7288 7100 4-1/2" x 1-1 /2" 1 8287 7995 4-1 /2" x 1 " 9,054` HES 4-1/2" "X" Nipple, ID=3.813" $,990` BKR 7" x 4-1/2" S-3 , 9CR PKR 9,022` HES 4-1 /2" "X" Nipple, ID=3.813" 9,054` HES 4-1/2" "XN" Nipple, ID=3.725" 9,104` 19-5/8" x 4-1/2" 13CR Unique Overshot PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 65 @ 9537' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SLOTTED LNR 9537 - 11095 C 05/05/03 47#, L-80, ID = 8.681 " ~-~ 9201' ~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ I TD I 4-1/2" 7" X 4-1/2" BKR S-3 PKR ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 4-1/2" PX PLUG (10/20/08) 9191' 4-1/2" WLEG, ID = 3.958" ELMD TT NOT LOGGED 9193' 7" X 5" BKR HMC LNR HGR, ID = ? 12.6#, L-80, .0152 bpf, ID = 3.958" 9190' ~ ~ ~ . 7" LNR 29#, L-80, .0383 bpf, ID = 6.276" 9344' ~ ~ , 4-1/2" SOLID LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 9537' \~/ 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11095' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/28/82 ORIGINAL COMPLETION 01/15/08 DAV/PJC GLV GO (01/06/08) 05/07/03 DAV/KK RIG SIDETRACK (13-13A) 02/06/08 JLJ/PJC HES NIP CORRECTION 08/28/03 TLH/TLH CORRECTIONS 03/13/08 GJFlTLH GLV GO 09/04/03 TLH/KK HES X NIP DEPT-H CORRECTION 11/21/08 BSE/TLH PX PLUG SET (10/20/08) 10/09/05 RPH/TLH WANER SFTY NOTE DELETED 05/31/06 DTM WELLHEAD CORRECTIONS PRUDHOE BAY UNfT WELL: 13-13A PERMfT No: 2030360 API No: 50-029-20852-01 SEC 14, T10N, R14E, 396.1' FNL 8 2443.36' FEL BP Exploration (Alaska) Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 14, 2009 9:26 AM To: 'Reem, David C' Cc: Nadem, Mehrdad; Regg, James B (DOA) Subject: RE: DS 13-13A (203-036) Dave and Mehrdad, Home run. I will place a copy of this message in the well file. Where it is possible to run two sets of pipe rams, I strongly support having stack(s) equipped as planned here. Call or message with any questions. Tom Maunder, PE AOGCC From: Reem, David C [mailto:ReemDC@BP.com] Sent: Tuesday, April 14, 2009 8:39 AM To: Maunder, Thomas E (DOA) Cc: Nadem, Mehrdad Subject: RE: DS 13-13A (203-036) Tom, how does this sound.....? Doyon 14 will be blessed with this well. They'll have their drilling stack which will have the following (top-to- bottom)Annular, 3-1/2" x 6" VBRs, Blind rams, flow-cross, 2-7/8" x 5" VBRs. Ought to have the bases covered. DCR From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 13, 2009 11:54 AM To: Nadem, Mehrdad Cc: Reem, David C; Regg, James B (DOA) Subject: DS 13-13A (203-036) Mehrdad and Dave, I am reviewing the sundry to workover this well. It is noted that the BOP will be equipped with 3-1/2 x 6" rams. At the end of the workover, it is intended to drill out the FasDrill and push to bottom. I suspect that 2-7/8" DP will be used to accomplish this task. Based on the depths given in the proposed drawing, there is -2160' between the proposed tubing cut depth and PBTD. Why will the well not be equipped with rams to cover all tubulars that likely will be used in the well? Based on the tubing and DP sizes likely to be employed, 2-7/8 x 5" rams will provide a minimum of 1 ram coverage on all sizes. I look forward to your reply. Tom Maunder, PE AOGCC 4/14/2009 • • -~ ~° --,. ~~..- .~ , `'~, ~~~- MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~L.aserFiche\CvrPgs_Inserts~Microfilm Marker.doc e e WELL LOG TRANSMITTAL ,aD?;ì-03& I 35lt:fJ February 16, 2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 13-13A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 13-13A: LAS Data & Digital Log Images: 50-029-20852-01 1 CD Rom /~l~ c:> lOW ~1:J9 r J~ J..c~ DATA SUBMITTAL COMPLIANCE REPORT 7/12/2005 Permit to Drill 2030360 Well Name/No. PRUDHOE BAY UNIT 13-13A Operator BP EXPLORATION (ALASKA) INC ~(.{ l ~ ) Id.r ,{¿~3 API No. 50-029-20852-01-00 MD 11263 ,- TVD 9018./ Completion Date 5/5/2003 ....- Completion Status 1-01L Current Status 1-01L UIC N ----- ---- ---- -~---------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~~~C__ _ ___ DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, PWD, RES, ABI Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data Type iLkPt I %t Electr Digital Dataset Med/Frmt Number Name Directional Survey Directional Survey Log Log Scale Media Run No 1 1 Interval Start Stop 8588 11263 8588 11263 OH/ CH Open Open Received Comments 5/13/2003 5/13/2003 MWD ~pt ~ D Name Interval Start Stop 1-3 8619 11263 Open 6/2/2003 1-3 8441 11196 Open 6/2/2003 MWD-GR, EWR4, ROP-MD ----- - -- --- - Sample Set Sent Received Number Comments 11992 LIS Verification 11992 Induction/Resistivity Well Cores/Samples Information: ADDITIONAL INFORMATION Well Cored? Y / t Chips Received? .... Y / N Formation Tops @/N /)v ÚN Daily History Received? Analysis _Y / N Received? ----------~ ------ Comments: Compliance Reviewed By: , ~~.:) Date: J lr -;---~-=-~-¡:.:::::::;;::.~- / À- lY_)-_k~ ~ 1. Status of Well Lm Oil 0 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 su rface 855' NSL, 1076' WEL, SEC. 14, T10N, R14E, UM At top of productive interval 736' SNL, 2487' WEL, SEC. 23, T10N, R14E, UM At total depth 1212' SNL, 1315' WEL, SEC. 23, T10N, R14E, UM X = 685982, Y = 5928824 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool RKB = 77.2' ADL 028315 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 4/27/2003 5/3/2003 5/5/2003 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 11263 9018 FT 11263 9018 FT Lm Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, PWD, RES, ABI 23. CASING SIZE 20" 13-3/8" 9-5/8" 7" 4-1/2" WT. PER FT. 91.5# 72# 47# 26# 12.6# (' ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 7. Permit Number 203-036 8. API Number 50- 029-20852-01 9. Unit or Lease Name X = 686169, Y = 5930896 Prudhoe Bay Unit X = 684798, Y = 5929271 10. Well Number 13-13A 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2212' MD 1900' (Approx.) GRADE H-40 L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED Surface 79' 30" 500 sx AS II Surface 2586' 17-1/2" 2300 sx Fondu, 400 sx Permafrost 'C' Surface 8615' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' 8460' 9344' 8-1/2" 198 sx Class 'G' 9184' 11263' 6-1/8" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Section Flow Tubing Casing Pressure CALCULATED Press. 247 24-HoUR RATE MD TVD 9537' - 11095' 8982' - 9017' 27. Date First Production May 29,2003 Date of Test Hours Tested 5/30/2003 7.2 25. TUSING RECORD DEPTH SET (MD) 9191' SIZE 4-1/2", 12.6#, L-80 PACKER SET (MD) 9155' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 155 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR Oll-Bsl TEST PERIOD 2,511 Oll-Bsl GAs-McF 8,249 GAs-McF WATER-Bsl 5,483 WATER-Bsl CHOKE SIZE 80° GAS-Oil RATIO 3,285 Oil GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. sUbmR~l::: ~ No core samples were taken. rorm 10-407 Rev. 07-01-80 .,'~i.';'. \ . i :") t': .\-;-:: ; !;! r' 7, /.... ~. ;1~.,)~/j';J....·,. \ t; if[EiFK]) r i:. ""..""/~~""''''' ': ;~;;~\ ~1iiW¡:1I.:¡;t;."'I~11 J..¡¡IJ",', ','i'~' "\oo"':\¡''''{~'~IJ~':~' RISIDMS BFl (~ ¡:.: JUN 0 4t Alaska Oi\ & Gas JUN Q 1nn~ Ancht\z'¡g¡~e OR'GNA~ 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. Sag River 9375' 8892' Shublik 9409' 8914' Sadlerochit 9540' 8984' RE.CE~\lE: JUN 0 4 2003 Ahnsk~ Oil & C~:m5, Anchorage 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 ~AA..Lf. ~ Title Technical Assistant Date OCo -tJ-f...æ 13-13A 203-036 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any £:ttachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: Common Name: 4/27/2003 5/112003 FIT FIT 1 3-1 3 13-13A TestTyp~ Test Depth (TMD) 8,615.0 (ft) 9,344.0 (ft) BPEXPLORA TION Leak-Off Test· 5 u m mary Test Depth (TVD) 8,297.0 (ft) 8,871.0 (ft) AMW 11.00 (ppg) 8.60 (ppg) Surface Pressure 520 (psi) 650 (psi) leak Off Pressure (BHP) 5,261 (psi) 4,613 (psi) Page 1 of 1 EMW 12.21 (ppg) 10.01 (ppg) ~Oc Printed: 5/12/2003 11 :24:22 AM ( ~' BP EXPLORATION Operations Summary Report Page 1 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-13 13-13A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/21/2003 Rig Release: 5/5/2003 Rig Number: Spud Date: 11/11/1982 End: 5/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/20/2003 10:00 - 15:30 5.50 MOB P PRE Turnkey rig move. Prep rig for move, RDMO C 11 a to center of Pad. Safety meeting wI all personnel for rig move. 15:30 - 20:30 5.00 MOB P PRE Move Sub Base fl C Pad to DS 13, 11.2 miles 20:30 - 00:00 3.50 MOB P PRE Move Pits, Camp and Shop, while Lay herculitefor Sub Base, MIRU on DS 13 - 13a, raise and pin derrick, and cattle chute, bridal dn, pin top drive to blocks, hang bridal lines. 4/21/2003 00:00 - 01 :30 1.50 MOB P PRE Finish moving pits, camp and shop to DS 13 01 :30 - 04:00 2.50 MOB P PRE Move in, spot pits, camp and shop, spot cuttings tank, Ru electrical hook ups and lines 04:00 - 04:30 0.50 RIGU P PRE Pre spud meeting. accept rig 0400hrs, 4/21/2003 04:30 - 06:00 1.50 WHSUR P DECOMP Install secondary annulus valve, Ru line from wellhead to cutting tank, taking on seawater. Test surface circ lines. 06:00 - 09:30 3.50 CLEAN P DECOMP Circ freeze protect from well wI 8.4 ppg seawater. 210 GPM @ 620 psi. 09:30 - 10:30 1.00 WHSUR P DECOMP Dry rod BPV. Test from below to 1000 psi. O-K. Blow down surface circ lines, 10:30 - 13:00 2,50 WHSUR P DECOMP ND tree and adapter flange. Terminate control lines. Function LDS. 13:00 - 15:00 2.00 BOPSURP DECOMP NU BOPE. 15:00 - 15:30 0.50 WHSUR P DECOMP Install test dart in BPV. 15:30 - 16:00 0.50 BOPSUR P DECOMP PU & run test jt. 16:00 - 22:00 6.00 BOPSURP DECOMP Test BOPE to BP & AOGCC regs. 250 psi low 13500 psi high. Test witnessed by Jeff Jones of AOGCC. LD test jt. 22:00 - 22:30 0.50 WHSUR P DECOMP Pull test dart from BPV. 22:30 - 23:30 1.00 WHSUR P DECOMP RU DSM lubricator. Pull BPV, RD DSM lubricator. 23:30 - 00:00 0.50 PULL P DECOMP MU Baker tandem spear. Engage tbg hanger. Unseat same wI 250k. Work 4 1/2" tbg free wI 275k. Pull tbg hanger to rig floor. String wt 140k. 4/22/2003 00:00 - 00:30 0.50 PULL P DECOMP LD Baker Tandem 4 1/2" spear. LD tbg hanger. 00:30 - 02:00 1.50 PULL P DECOMP Circ 'Soap' sweep surface to surface. 400 GPM @ 1700 psi. RU 4 1/2" handling equip. RU Camco control line spooling equip. 02:00 - 09:30 7,50 PULL P DECOMP POH LD 4 1/2" tbg. Recover 206 jts 41/2" BTC, L80 tbg. 9 GLM's, 1 SSSV, 1 seal assy. 20 SS bands. Tbg was only 30% cut by 'Jet' cutter. 09:30 - 10:30 1.00 PULL P DECOMP RD 4 1/2" handling equip. Clean & clear rig floor. 10:30 - 11 :00 0,50 EVAL P DECOMP Test casing 3500 psi. O-K. 11 :00 - 11 :30 0,50 TA P DECOMP PU & MU Baker 'Multi string' casing cutter. 11 :30 - 12:00 0.50 BOPSUR P DECOMP PU test plug & test jt. Test lower pipe rams to BP & AOGCC regs 250 psi low I 3500 psi high. LD test jt & plug. 12:00 - 13:00 1.00 T A P DECOMP RIH wI 'Multi sring' cutter to 169 ft. 13:00 - 13:30 0.50 TA P DECOMP Displace well to 'Dead' crude oil. 126 GPM @ 850 psi. 13:30 - 14:30 1.00 TA P DECOMP PU to 130 ft. Cut 9 5/8" casing. POH LD casing cutter. 14:30 - 15:00 0.50 TA P DECOMP Clean & clear rig floor. 15:00 - 16:00 1.00 WHSUR P DECOMP PU pulling tool. Attempt to pull 9 5/8" pack off. No success. LD pulling tool. 16:00 - 18:00 2.00 TA P DECOMP MU Baker 9 5/8" casing spear. Engage 9 5/8" casing at surface. Work pipe up to 200k, obtain movement. Pull to rig floor. Release spear LD same. 18:00 - 19:30 1.50 TA P DECOMP LD 9 5/8" casing. Recover 100 ft & pack off. 19:30 - 20:00 0.50 TA P DECOMP RIH wI muleshoe to 320 ft. 20:00 - 21 :00 1.00 TA P DECOMP Reverse circ 'Dead' crude oil. 168 GPM @ 230 psi. Printed: 5/12/2003 11:24:31 AM ill \ ,~: BP EXPLORATION Operations Summary Report Page 2 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 3-1 3 13-13A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/21/2003 Rig Release: 5/5/2003 Rig Number: Spud Date: 11/11/1982 End: 5/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/22/2003 20:00 - 21 :00 1.00 TA P DECOMP Clear rig floor. POH LD mule shoe 21 :00 - 22:30 1.50 TA P DECOMP PU & RIH w/ 647 ft of 5" HWDP, 133/8" RTTS prk w/ 'Storm' valve. Set pkr @ 120 ft, w/ valve @ 110ft. P/U Wt 60k, S/O Wt 60k. Test below pkr 1000 psi O-K. 22:30 - 23:00 0.50 TA P DECOMP Displace well w/ 'Soap' sweep & clean seawater. 300 GPM @ 60 psi. 23:00 - 23:30 0.50 TA P DECOMP POH LD running tool for 13 3/8" RTTS. 23:30 - 00:00 0.50 TA P DECOMP Clear & clean rig floor. 4/23/2003 00:00 - 01 :30 1.50 BOPSUR P DECOMP ND BOP. Rack back on stump. 01 :30 - 04:30 3.00 WHSUR P DECOMP Strip down & remove well head to 13 3/8" csg stub. 04:30 - 00:00 19.50 WHSUR P DECOMP Dress 13 3/8" csg stub. Preheat to 600 degrees. Weld on FMC SOW. Cool down head to 275 degrees. Test w/ Nitrogen - failed. Identify leak and dress same. Preheat to 600 degrees. Re weld head in leak area. Wrap & let cool down. 4/24/2003 00:00 - 05:30 5.50 WHSUR P DECaMP Allow 13 3/8" FMC saw to cool. 05:30 - 06:30 1.00 WHSUR P DEcaMP RU test equip. test 1560 psi / 15 mins. 06:30 - 09:00 2.50 WHSUR P DECOMP NU FMC csg I tbg spool. Test 1000 psi / 15 mins. 09:00 - 11 :30 2.50 BOPSUR P DECOMP Drop 'Mud Cross' off of BOP. NU BOP & secondary annulus valve. 11 :30 - 13:00 1.50 BOPSUR P DECOMP PU test jt. Body test BOP to BP & AOGCC regs. 250 psi low I 3500 psi high. LD test jt. 13:00-14:00 1.00 EVAL P DECaMP Test casing to 1000 psi / 15 mins, 14:00-17:00 3.00 PULL P DECOMP RIH wI retrieving tool for 13 3/8" RTTS. Displace well to 'Dead' crude. 126 GPM @ 170 psi. Latch RTTS, unseat pkr stripping thru Hydril as precaution. POH LD RTTS. 17:00 - 23:30 6.50 TA P DECaMP MU 9 5/8" back off assy. RIH & space out @ 154 ft. Fill pipe wI diesel. Back off 9 5/8" stub. Initial pressure 5500 psi, final pressure 800 psi. Total of 6.25 turns. 23:30 - 00:00 0.50 PULL P DECOMP POH LD 9 5/8" back off assy. 4/25/2003 00:00 - 01 :30 1.50 FISH P DECOMP Fin LD Back off assy, 01 :30 - 02:30 1.00 FISH P DECOMP Clear & clean rig floor. 02:30 - 04:00 1.50 FISH P DECOMP MU 9 5/8" csg spear. RIH & engage 9 5/8" csg stub @ 134 ft. Back out w/1 0 turns. POH LD spear & 28.25 ft 9 5/8" csg wI collar. Inspect threads on collar O-K. 04:00 - 05:00 1.00 FISH P DECaMP Clear & clean rig floor. 05:00 - 10:00 5.00 CASE P PROD1 RU 9 5/8" csg handling equip. MU Baker 'Screw In' guide w/ collar. RIH w/ 9 5/8" 47#, L- 80, BTC csg tagged @ 158', screwed into 9 5/8" csg, make up torque 9200 ftlbs 10:00 - 13:00 3.00 CASE P PROD1 RIH wI std of 4" DP inside 9 5/8" casing, displaced dead crude from well with seawater, POH wI std of 4" DP. Clean rig floor, handling tools and equipment. 13:00 - 14:30 1.50 WHSUR P PROD1 Split tubing head fl casing head, PU BOP stackltubing head -2' 14:30 - 16:00 1.50 WHSUR P PROD1 Install 9 5/8" emergency slips, did not fit, were sitting to high in bowl. Slips were designed for a 12" bowl depth. Casing head installed had a 10" bowl depth. 16:00 - 17:00 1.00 WHSUR N SFAL PROD1 Pulled and removed emergency slips 17:00 - 18:30 1.50 WHSUR N SFAL PROD1 Sent emergency slips to Baker machine shop, removed bottom junk ring, and primary seal packing element. Cut and beveled bottom of slips to a 45 degree shoulder. Removed and cut off a total of 2.30". 18:30 - 20:00 1.50 WHSUR N SFAL PROD1 Installed 9 5/8" emergency slips with 200,000 Ibs of 95/8" Printed: 5/12/2003 11 :24:31 AM ( BP EXPLORATION Operations Summary Report Page 3 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 3-13 13-13A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/21/2003 Rig Release: 5/5/2003 Rig Number: Spud Date: 11/11/1982 End: 5/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/25/2003 18:30 - 20:00 1.50 WHSUR N SFAL PROD1 string weight. 20:00 - 21 :30 1.50 CASE N SFAL PROD1 RU casing cutter, cut 9 5/8" casing 6" above casing head, dressed stump for packoff 21 :30 - 23:30 2.00 WHSUR N SFAL PROD1 Slacked off stack and tubing head, NU to casing head, break BOP stack at tubing head, install mud cross, NU BOP's 23:30 - 00:00 0.50 WHSUR N SFAL PROD1 MU packoff running tool to a stand of 5" HWDP 4/26/2003 00:00 - 04:00 4.00 WHSUR N SFAL PROD1 RIH wi 9 5/8" pack-off on 1 stand of 5" HWDP, unable to seat pack-off after serveral attempts, POH, RIH wi pack-off on 1 stand of 6 1/4" DC's, swallowed casing stump, bottomed out on top of emergency slips, lock down groove sitting 3/8" high above lock down studs, unable to run in lock down studs. Consulted wi FMC Anchorage office. 04:00 - 04:30 0.50 WHSUR N SFAL PROD1 Retrieved 9 5/8" pack-off 04:30 - 05:30 1.00 WHSUR N SFAL PROD1 Sent 9 5/8" pack-off to Baker machine to be cut down by 3/8" from bottom, as per FMC recommendations. Notified BP Anchorage base. 05:30 - 06:30 1.00 WHSUR N SFAL PROD1 Install 9 5/8" pack-off, RILDS 06:30 - 07:00 0.50 WHSUR P PROD1 Test 9 5/8" pack-off to 3800 psi, hold for 15 minutes, OK 07:00 - 07:30 0.50 WHSUR P DECOMP Set mouse hole, set wear ring 07:30 - 09:00 1.50 WHSUR P DECOMP Body test BOP (tighten upper mud cross bolts) and 95/8" casing at 250 psi and 3500 psi, chart and hold for 30 minutes 09:00 - 1 0:30 1.50 STWHIP P WEXIT PJSM, MU Mill Assy, RIH wi BHA to 971', C/O elevators 10:30 - 12:00 1.50 STWHIP P WEXIT PU 4" DP, RIH to 1936', pipe handler on top drive not working 12:00 - 12:30 0.50 STWHIP P WEXIT Service Top Drive 12:30 - 13:30 1.00 STWHIP N SFAL WEXIT Trouble shoot Top Drive, C/O pressure switch, pipe handler working 13:30 - 18:30 5.00 STWHIP P WEXIT PU 4" DP, RIH, tagged at 8788' SLM 18:30 - 20:00 1.50 STWHIP P WEXIT Displaced well to 11.1 ppg LSND mud at 13 bpm, 3470 psi, 541 gpm, up wt 190k, dn wt 175k, rot wt 180k 20:00 - 21 :00 1.00 STWHIP P WEXIT POH wi 1 stand of 4'DP, slip and cut drill line 21 :00 - 00:00 3.00 STWHIP P WEXIT POH to 2184' 4/27/2003 00:00 - 00:30 0.50 STWHIP P WEXIT POH to BHA 00:30 - 02:00 1.50 STWHIP P WEXIT POH wI Mill Assy, LD jars 02:00 - 05:30 3.50 STWHIP P WEXIT PJSM, RU E-line, run 9 5/8" EZ Drill wi CPST setting tool and CCL to 8720', run CCL log, spot EZ Drill 4' above collar, set EZ Drill at 8648' ELM, had good surface indication of packer setting, slack off wi E-line, taking weight verifing EZ Drill was set. POH RD E-line. 05:30 - 07:00 1.50 STWHIP P WEXIT PJSM, PU 9 5/8" whipstock assy, RIH to 83' 07:00 - 08:00 1.00 STWHIP P WEXIT MU MWD, upload tool, surface test MWD at 490 gpm wi 1800 psi 08:00 - 09:30 1.50 STWHIP P WEXIT RIH wI BHA to 1041', C/O elevators 09:30 - 13:30 4.00 STWHIP P WEXIT RIH wI BHA on 4' DP to 8640', tagged EZ Drill, filled pipe and functioned MWD at 3283', OK 13:30 - 14:00 0.50 STWHIP P WEXIT Orient whipstock to 16 degrees LHS, set whipstock 14:00 - 18:30 4.50 STWHIP P WEXIT Milled window in 9 5/8" 47#, L-80 casing f/8615' to 8631' WOB 10 -15K, RPM 100 Flow at 487 gpm, 3235 psi Torque on 6 - 7K, Torque off 5-6K P/U 200K, S/O 175K, Rt 180K 18:30 - 21 :00 2.50 STWHIP P WEXIT Drill fl 8631' to 8647' WOB 10 - 15K, RPM 100 Flow at 487 gpm, 3235 psi Printed: 5/12/2003 11 :24:31 AM ( { BP EXPLORATION Operations Summary Report Page 4 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-13 13-13A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/21/2003 Rig Release: 5/5/2003 Rig Number: Spud Date: 11/11/1982 End: 5/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/27/2003 18:30 - 21 :00 2.50 STWHIP P WEXIT To~ueon6-7K, To~ueoff~6K P/U 200K, SIO 175K, Rt 180K Recovered 85 Ibs of metal shavings 21 :00 - 22:00 1.00 STWHIP P WEXIT Sweep hole, rotate through window several times wI pumps and without. No problems 22:00 - 22:30 0.50 STWHIP P WEXIT Perform FIT to 12.2 ppg EMW w/11.0 ppg mud to 520 psi, pumped 1.1 bbls, recovered 1 bbl 22:30 - 00:00 1.50 STWHIP P WEXIT Slugged pipe, POH wI 4' DP 4/28/2003 00:00 - 02:00 2.00 STWHIP P WEXIT POH to BHA at 1041', test choke manifold 02:00 - 03:30 1.50 STWHIP P WEXIT POH wI BHA, LD mills, upper mill in gauge, clear and clean floor. 03:30 - 04:30 1.00 STWHIP P WEXIT P/U and M/U 'Johnny Whacker'. Flush out the stack, flowline, possum belly and shaker beds. Function the rams, service the wear bushing. 04:30 - 08:00 3.50 BOPSURP INT1 RU, Test BOPE to BP & AOGCC regs. 250 psi low 13500 psi high. Chuck Schieve wI AOGCC waived witnessing BOP Test. LD test jt., Retrieved test plug, install wear ring 08:00 - 10:00 2.00 DRILL P INT1 PJSM, MU 1.22 degree motor and 8 1/2" PDC bit, PU MWD wI GR-PWD-Dir, orient MWD to motor, RIH wI BHA 10:00 - 10:30 0.50 DRILL P INT1 Fill pipe, shallow hole test MWD at 1087' wI 490 gpm, 1550 psi 10:30 - 14:00 3.50 DRILL P INT1 PU 4" DP, RIH to 8520, fill pipe every 3500' 14:00 - 15:30 1.50 DRILL P INT1 Madd Pass f/8520' to 8635', washed to 8647' 15:30 - 00:00 8.50 DRILL P INT1 Dir drill wI 1.22 degree motor and survey wI GR-PWD-DIR from 8,647' to 8,925'. MW inlout 11.1 ppg; P/U 205K, SIO 170K, RT 184K; ART = 1.08 hrs, AST = 4.83hrs, ADT = 5.91 hrs Slide I Rotate 278' (8,647' - 8,925') Slide at TF -35 to -45 Flow rate 500 gpm, on btm 3,250 psi, off btm 3100 psi. WOB 5-7K, Rap 25-60 fph Rotate at 40 RPM Flow rate 500 gpm, on btm 3,350 psi, off btm 3100 psi. Torque on btm 6000 - 9000; Torque off btm 6000 - 7000 WOB 10K, Rap 70 - 115 fph 4/29/2003 00:00 - 12:00 12.00 DRILL P INT1 Dir drill wI 1.22 degree motor and survey wI GR-PWD-DIR from 8,925' to 9,305'. MW inlout 11.1 ppg; P/U 220K, SIO 185K, RT 195K; ART = 1.74 hrs, AST = 6.57 hrs, ADT = 8.31 hrs Slide I Rotate 380' (8,925' - 9,305') Slide at TF -25 to -60 Flow rate 500 gpm, on btm 3,820 psi, off btm 3550 psi. WOB 5 - 9 K, Rap 25-60 fph Rotate at 80 RPM Flow rate 500 gpm, on btm 3,900 psi, off btm 3,700 psi. Torque on btm 6000 - 9000; Torque off btm 6000 -7000 WOB 10 -15K, Rap 70 - 115 fph 12:00 - 13:00 1.00 DRILL P INT1 Rotate 39' (9,305' - 9,344') Printed: 5/12/2003 11 :24:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( ( BP EXPLORATION Operations Summary Report 1 3-13 13-13A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/21/2003 Rig Release: 5/5/2003 Rig Number: Page 5 of 8 Spud Date: 11/11/1982 End: 5/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/29/2003 12:00 - 13:00 1.00 DRILL P INT1 Rotate at 70 RPM Flow rate 500 gpm, on btm 3,900 psi, off btm 3,700 psi. Torque on btm 6000 - 9000; Torque off btm 6000 - 7000 WOB 8K, ROP 65 fph ART = 0.60 hrs, AST = 0.007 hrs, ADT = 0.60 hrs 13:00 - 14:30 1.50 DRILL P INT1 CBU at 12 bpm and 3,500 psi. P/U weight 215K, S/O weight 168K, Rotating weight 190K 14:30 - 15:00 0.50 DRILL P INT1 POH from 9,344' to 8,557'. 15:00 - 16:30 1.50 DRILL P INT1 Service TO, adjust brakes. 16:30 - 17:00 0.50 DRILL P INT1 RIH from 8,557' to 9,344'. No problems. 17:00 - 18:30 1.50 DRILL P INT1 Circulate sweep at 12 bpm and 3,500 psi. Spot liner running pill. 18:30 - 21 :30 3.00 DRILL P INT1 POOH from 9,344' to 1,087'. Overpull of 5 - 10K. 21 :30 - 23:00 1.50 DRILL P INT1 LID BHA from 1,087' to 67'. 23:00 - 00:00 1.00 DRILL P INT1 Flush MWD with water. Download and confidence test MWD. 4/30/2003 00:00 - 01 :30 1.50 DRILL P INT1 Complete LID BHA components from 68'. 01 :30 - 02:30 1.00 CASE P LNR1 Clear rig floor. R/U to run 7", 26#, L-80 casing. 02:30 - 03:00 0.50 CASE P LNR1 PJSM with crew regarding running !" liner. P/U float equipment and check same. 03:00 - 04:30 1.50 CASE P LNR1 P/U total of 21 joints of 7", 26#, L-80, BTC-M casing. Average M/U torque 8,500 ft.lbs. 04:30 - 05:00 0.50 CASE P LNR1 M/U hanger I packer. C/O handling equipment. Liner hanging weight 47K. 05:00 - 05:30 0.50 CASE P LNR1 RIH with 1 stand to 1,012'. Circulate liner volume at 5 bpm and 150 psi. 05:30 - 09:00 3.50 CASE P LNR1 RIH with drill pipe from 1,012' to 8,577'. 09:00 - 09:30 0.50 CASE P LNR1 Circulate drill pipe and liner volume at 4 1/2 bpm and 780 psi. 09:30 - 10:00 0.50 CASE P LNR1 RIH with drill pipe from 8,577' to 9,323'. 10:00 - 10:30 0.50 CASE P LNR1 R/U rotary cement head. Tag bottom at 9,344' and P/U 1 foot off bottom. P/U weight 178K, S/O weight 147K. 10:30 - 12:00 1.50 CASE P LNR1 Circulate and condition hole. Stage pumps to 7 bpm at 1,600 psi. PJSM with all personnel. 12:00 -13:30 1.50 CEMT P LNR1 Pump 5 bbl water, test lines to 4,500 psi. Pump 25 bbl 12.2 ppg Mud PUSH, 41 bb115.8 ppg 'G' cement. Drop dart and displace with 118 bb111.2 ppg mud. Bump plug with 4,000 psi. CIP at 13:15 hrs, 04/30/2003. Check floats, held. 13:30 - 15:30 2.00 CEMT P LNR1 Release from hanger, CBU at 12 bpm and 3,500 psi. Approximately 1/2 bbl cement return. Rotate down and weight set packer with 70K 15:30 - 16:00 0.50 CEMT P LNR1 RID rotary cement head. 16:00 - 16:30 0.50 CEMT P LNR1 Pump dry job. POH from 8,439' to 8,253'. 16:30 - 17:30 1.00 CEMT P LNR1 Slip and cut 107' drilling line. 17:30 - 19:30 2.00 CEMT P LNR1 POOH from 8,253'. 19:30 - 20:00 0.50 CEMT P LNR1 Break out and LID running tool. Clear rig floor. 20:00 - 22:00 2.00 DRILL P PROD1 M/U 6 1/8" BHA to 212'. Up load MWD. 22:00 - 22:30 0.50 DRILL P PROD1 Shallow pulse test MWD. 22:30 - 00:00 1.50 DRILL P PROD1 RIH with drill pipe from 212' to 3,947'. 5/1/2003 00:00 - 01 :30 1.50 DRILL P PROD1 RIH with drill pipe from 3,947' to 9,174'. Fill pipe at 5,815'. 01 :30 - 02:30 1.00 EVAL P PROD1 Test 9 5/8" X 7" to 3,500 psi for 30 minutes. Record test. 02:30 - 03:30 1.00 DRILL P PROD1 Service top drive. Install blower hose, Grease gripper. Printed: 5/12/2003 11 :24:31 AM (' I( BP EXPLORATION Operations Summary Report Page 6 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-1 3 13-13A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/21/2003 Rig Release: 5/5/2003 Rig Number: Spud Date: 11/11/1982 End: 5/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/1/2003 03:30 - 05:00 1.50 DRILL P PROD1 Wash down from 9,174' at 280 gpm and 2,600 psi. Tag LlC at 9,259'. Drill out LlC and cement to FIC at 9,299'. Drill cement to 9,340'. P/U weight 168K, S/O weight 148K, Rot weight 160K. Torque on 6,000 ft-Ibs, Torque off 4,500 ft-Ibs. 10 RPM. 05:00 - 07:00 2.00 DRILL P PROD1 Displace well at 9,340' from 11.1 ppg mud to 8.6 ppg QuickDrillN at 325 gpm and 1,750 psi. 07:00 - 07:30 0.50 DRILL P PROD1 Drill out shoe and 20' new formation to 9,364'. 07:30 - 08:00 0.50 DRILL P PROD1 Circulate and condition hole at 9,364'. Perform FIT to 650 psi with 8.6 ppg mud (EMW of 10.0 ppg.) Blow down surface equipment. 08:00 - 12:00 4.00 DRILL P PROD1 Directional drill from 9,364' to 9,485'. ART = 1.00 hrs, AST = 2.00 hrs, ADT = 3.00 hrs P/U weight 168K, S/O weight 148K, Rot weight 160K. Slide I Rotate 121' (8,925' - 9,305') Slide at TF -30 to -50 to initiate build I LH turn Flow rate 325 gpm, on btm 2,200 psi, off btm 1,900 psi. WOB 8 - 10 K, ROP 40-60 fph Rotate at 20 RPM Flow rate 325 gpm, on btm 2,200 psi, off btm 1,900 psi. Torque on btm 6,000; Torque off btm 4,000 WOB 8 -10K, ROP 50 - 80 fph 12:00 - 00:00 12.00 DRILL P PROD1 Directional drill from 9,485' to 9,924'. ART = 0.00 hrs, AST = 7,12 hrs, ADT = 7.12 hrs P/U weight 180K, S/O weight 152K, Rot weight 165K. Slide 252' (9,485' - 9,737') Slide at TF 0 to -20 to maximize build rate to horizontal Flow rate 310 - 325 gpm, on btm 2,200 psi, off btm 2,000 psi. WOB 9 - 14K, ROP 20-120 fph Slide 187' (9,737' - 9,924') Slide at TF -75 to -90 to maximize LH turn rate, while maintaining inverted drilling inclination. Flow rate 310 gpm, on btm 2,300 psi, off btm 1,950 psi. WOB 12 - 15K, ROP 50-80 fph 5/2/2003 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill from 9,924' to 10,840'. P/U weight 185K, SIO weight 145K, Rot weight 165K. Slide 916' (9,924' - 10,840') Slide at TF -75 to -130 to maintain LH turn and decrease inclination. Flow rate 310 - 325 gpm, on btm 2,350 psi, off btm 2,100 psi. Printed: 5/12/2003 11:24:31 AM I~' {' BP EXPLORATION Operations Summary Report Page 7 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 3-13 13-13A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/21/2003 Rig Release: 5/5/2003 Rig Number: Spud Date: 11/11/1982 End: 5/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/2/2003 00:00 - 00:00 24.00 DRILL P PROD1 WOB 10 - 20K, Rap 50-125 fph ART = 0.00 hrs, AST = 12.78 hrs, ADT = 12.78 hrs 5/3/2003 00:00 - 06:00 6.00 DRILL P PROD1 Directional drill from 10,840' to 11,263'. TD reached at 11,263'. ART = 2.49 hrs, AST = 1.22 hrs, ADT = 3.71 hrs P/U weight 180K, SIO weight 145K, Rot weight 165K. Slide I Rotate 423' (10,840' - 11,263') Slide at TF -60 Flow rate 325 gpm, on btm 2,350 psi, off btm 2,100 psi. WOB 10 K, Rap 50-100 fph Rotate at 60 RPM Flow rate 325 gpm, on btm 2,500 psi, off btm 2,300 psi. Torque on btm 7,000; Torque off btm 6,000 WOB 5 -10K, Rap 125 fph 06:00 - 08:00 2.00 DRILL P PROD1 Circulate Hi Vis sweep around at 8 bpm and 2,460 psi. 08:00 - 10:30 2.50 DRILL P PROD1 POOH from 11,263' to 9,300'. Overpull of -30K at 9,880' and 9,720'. Depths correspond with shale stringers in the heel portion of the well path. Reamed through to clean up. 10:30 - 11 :00 0.50 DRILL P PROD1 Service top drive and crown. 11 :00 - 12:00 1.00 DRILL P PROD1 RIH from 9,300' to 11,263'. Hanging up at 9,440' and from 9,510' - 9,540', Would not fall through without working down. 12:00 - 13:30 1.50 DRILL P PROD1 CBU at 11,263' at 330 gpm and 2,300 psi. Monitor well, static. 13:30 - 14:30 1,00 DRILL P PROD1 POOH with drill pipe from 11,263' to 9,301'. No problems. Monitor well. 14:30 - 15:30 1.00 DRILL P PROD1 RIH to 11,263'. No problems. No fill on bottom, 15:30 - 17:00 1.50 DRILL P PROD1 Pump Hi Vis sweep at 11,263'. CBU at 330 gpm and 2,350 psi. 17:00 - 17:30 0.50 DRILL P PROD1 Spot a liner running pill at 11,263'. 330 gpm and 2,300 psi. Monitor well. 17:30 - 18:30 1.00 DRILL P PROD1 POH with drill pipe from 11,263' to 9,270'. No problems. Monitor well. 18:30 - 19:00 0.50 DRILL P PROD1 Drop dart at 9,270', Shear circulating sub at 3,800 psi. Slug pipe. Remove blower hose, Blow down surface equipment. 19:00 - 20:00 1.00 DRILL P PROD1 LID 58 drill pipe singles, from 9,270' to 7,495'. 20:00 - 22:30 2.50 DRILL P PROD1 POH with drill pipe from 7,495' to 212'. 22:30 - 23:30 1.00 DRILL P PROD1 PJSM. LID BHA from 212' to 49'. 23:30 - 00:00 0.50 DRILL P PROD1 Download MWD data. 5/4/2003 00:00 - 00:30 0.50 DRILL P PROD1 Continue read MWD. Confidence test. LID MWD 00:30 - 01 :30 1.00 CASE P CaMP Clear floor. R/U to run 41/2", 12.6#, L-80, solid I slotted liner. PJSM with crew regarding running production liner. 01 :30 - 03:00 1.50 CASE P CaMP P/U and run 41/2", 12,6#, L-80, IBT-M liner to 2,058'. Run a total of 50 joints, (4 joints solid liner, 38 joints slotted liner, 8 joints solid liner). Average MIU torque 3,800 ft-Ibs. 03:00 - 04:00 1.00 CASE P CaMP MIU Baker 7" X 5" liner hanger. Mix and insert Jell-Pack. P/U one stand and circulate liner volume at 4 bpm and 160 psi. 04:00 - 07:00 3,00 CASE P CaMP RIH with liner on drill pipe from 2,058' to 9,279'. 07:00 - 07:30 0.50 CASE P CaMP Circulate drill pipe volume at 4 bpm and 450 psi. P/U weight 160K, SIO weight 150K. 07:30 - 08:30 1.00 CASE P CaMP RIH with liner from 9,279' to 11,263'. P/U weight 180K. It was necessary to work through tight area from 9,500' to 9,550'. Printed: 5/12/2003 11 :24:31 AM t '~, BP EXPLORATION Operations Summary Report Page 8 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-13 13-13A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/21/2003 Rig Release: 5/5/2003 Rig Number: Spud Date: 11/11/1982 End: 5/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/4/2003 07:30 - 08:30 1.00 CASE P CaMP Depth corresponds with base of Shublik and transition to TSAD. 08:30 - 09:30 1.00 CASE P CaMP Set liner on bottom at 11,263'. Circulate down 29/32" ball. Pressure up to 2,000 psi to set hanger. Continue pressure up to 2,800 psi to shear and release from hanger. Pressure up to 4,500 psi and shear ball seat. P/U 20'. P/U weight 170K. 09:30 - 12:00 2.50 CASE P CaMP Pump 30 bbl Hi Vis spacer. Displace well to clean sea water at 12 bpm and 1,800 psi. Reciprocate pipe. Clean surface equipment, pump dry job, blow down top drive. 12:00 - 14:00 2.00 CASE P CaMP LID drill pipe from 9,184' to 5,943'. 14:00 - 15:30 1.50 CASE P CaMP Service top drive. Slip and cut drilling line. 15:30 - 18:30 3.00 CASE P CaMP LID drill pipe from 5,943'. 18:30 - 19:30 1.00 CASE P CaMP LID running tool, clear rig floor. Pull wear bushing. 19:30 - 20:00 0.50 RUNCOIVP CaMP R/U 4 1/2" tubing equipment. 20:00 - 20:30 0.50 RUNCOIVP CaMP PJSM with crew regarding running completion. 20:30 - 21 :00 0.50 RUNCOIVP CaMP P/U and M/U 4 1/2" tail pipe and packer assembly. Baker-Lok connection below packer. 21 :00 - 00:00 3.00 RUNCOIVP CaMP P/U 4 1/2", 12.6#, L-80, IBT-M tubing to 6,197'. Used BOL 2000 thread compound. Average M/U torque 3,800 ft-Ibs. 5/5/2003 00:00 - 02:00 2.00 RUNCOIVP CaMP P/U 41/2",12.6#, L-80, IBT-M tubing from 6,197' to 9,085', Tag at 9,192'. No space out pups required. Run total of 217 joints 4 1/2",12.6#, L-80, IBT-M tubing. 02:00 - 03:00 1.00 RUNCOIVP CaMP M/U FMC tubing hanger. 03:00 - 03:30 0.50 RUNCOIVP CaMP Land tubing and RILDS. 03:30 - 07:00 3.50 RUNCOIVP CaMP PJSM regarding circulation to seawaterlcorrosion inhibitor. R/U to reverse in seawater and corrosion inhibitor. Test lines to 3,500 psi. Reverse circulate seawater/corrosion inhibitor at 3 bpm and 130 psi. 07:00 - 09:00 2.00 RUNCOIVP CaMP Drop 1 7/8" ball and rod. Pressure to 3,500 psi to set packer. Test tubing to 3,500 psi for 30 minutes, bleed to 1,500 psi. Test annulus to 3,500 psi for 30 minutes. Bleed tubing pressure to shear OCR valve. 09:00 - 10:00 1.00 RUNCOIVP CaMP Dry rod TWC (FMC). Test from below to 1,000 psi. Blow down surface equipment. 10:00 - 12:00 2.00 BOPSUR P CaMP N/D BOPE 12:00 - 14:30 2.50 WHSUR P CaMP N/U tree and adapter flange. Pressure test to 5,000 psi. 14:30 - 15:00 0.50 WHSUR P CaMP DSM pull TWC with lubricator. 15:00-17:30 2.50 WHSUR P CaMP R/U Little Red HOT Oil services. Test lines to 2,500 psi. Reverse circulate 155 bbl diesel freeze protection to 2,200'. U-tube diesel. 17:30 - 18:00 0.50 WHSUR P CaMP Set BPV and test from below to 1,000 psi. 18:00 - 19:00 1.00 WHSUR P CaMP RID secondary annulus valve and secure tree. Rig RELEASED at 19:00 hrs. Printed: 5/12/2003 11 :24:31 AM { ~03- 03f::; 13-May-03 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 13-13 A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 8,588.20' MD Window / Kickoff Survey: 8,615.00 I MD (if applicable) Projected Survey: 11,263.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED MAY 13 2003 Atalka 05: & Gas Cons. Commi8ekm Anchorage Sperry-Sun Drilling Services North Slope Alaska BPXA PBU EOA DS 13 13-13A DEFIN TIVE ---~ Job No. AKZZ0002409983, Surveyed: 3 May, 2003 Survey Report 12 May, 2003 Your Ref: API 500292085201 Surface Coordinates: 5930896.34 N, 686168.56 E (70012' 58.1631" N, 148029' 53.6811" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~. Surface Coordinates relative to Project H Reference: 930896.34 N, 186168.56 E (Grid) Surface Coordinates relative to Structure Reference: 1755.16 S, 295.26 E (True) Kelly Bushing: 77.200 above Mean Sea Level Elevation relative to Project V Reference: 77.20ft Elevation relative to Structure Reference: 77.20ft spef"'"'f"'"'Y-su", DRILLING seRVIc:es A Halliburton Company Survey Ref: 5vy4023 DriflQuest 3.03.02.005 Page 20f5 12 May, 2003 - 9:27 .----------.------------- Sperry-Sun Drilling Services DEF\NI\\fE Survey Report for PBU_EOA as 13 -13-13A Your Ref: API 500292085201 Job No. AKZZ0002409983, Surveyed: 3 May, 2003 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) (0/100ft) 8588.20 21.250 238.000 8195.52 8272.72 1096.90 8 1087.71 W 5929772.95 N 685108.23 E 1544.44 Tie On Point AK-6 BP_-'FR-AK 8615.00 21.110 238.260 8220.51 8297.71 1102.01 8 1095.93 W 5929767.64 N 685100.14 E 0.629 1553.81 Window Point 8688.15 26.400 234.780 8287.44 8364.64 1118.338 1120.44 W 5929750.72 N 685076.04 E 7.478 1582.53 8782.06 29.980 226.280 8370.23 8447.43 1146.61 8 1154.48 W 5929721.61 N 685042.71 E 5.720 1626.48 8876.59 33.450 225.020 8450.63 8527.83 1181.36 8 1189.99 W 5929686.00 N 685008.07 E 3.737 1676.14 8970.57 35.510 221.620 8528.11 8605.31 1220.08 S 1226.44 W 5929646.39 N 684972.58 E 2.999 1729.32 9063.05 41.020 216.450 8600.71 8677.91 1264.61 S 1262.35 W 5929600.98 N 684937.78 E 6.887 1786.33 9155.48 45.600 211.780 8667.97 8745.17 1317.12S 1297.79 W 5929547.61 N 684903.65 E 6.044 1848.80 9247.92 48.210 210.930 8731.12 8808.32 1374.768 1332.90 W 5929489.12 N 684869.97 E 2.902 1914.76 9289.11 49.010 209.170 8758.35 8835.55 1401.51 S 1348.37 W 5929462.00 N 684855.16 E 3.748 1944.80 9317.74 48.960 209.170 8777.14 8854.34 1420.378 1358.90 W 5929442.88 N 684845.10 E 0.175 1965.72 9352.21 48.950 205.030 8799.78 8876.98 1443.51 8 1370.74 W 5929419.47 N 684833.84 E 9.057 1990.64 9383.03 49.570 201.410 8819.90 8897.10 1464.96 8 1379.94 W 5929397.79 N 684825.17 E 9.123 2012.52 9411.30 51.340 198.210 8837.90 8915.10 1485.478 1387.32 W 5929377.11 N 684818.30 E 10.741 2032.46 9444.33 53.990 194.610 8857.93 8935.13 1510.668 1394.72 W 5929351.75 N 684811.52 E 11 .808 2055.81 9475.79 57.510 191.840 8875.64 8952.84 1535.97 8 1400.65 W 5929326.30 N 684806.21 E 13.346 2078.23 9502.42 60.450 189.540 8889.36 8966.56 1558.39 8 1404.88 W 5929303.78 N 684802.54 E 13.291 2097.38 9537.27 64.990 187.520 8905.33 8982.53 1589.01 8 1409.46 W 5929273.05 N 684798.71 E 14.008 2122.72 9568.05 68.520 184.920 8917.48 8994.68 1617.128 1412.52 W 5929244.88 N 684796.35 E 13.847 2145.19 9595.70 71.410 183.460 8926.95 9004.15 1643.02 S 1414.41 W 5929218.93 N 684795.10 E 11 .569 2165.26 9631.39 74.840 181.660 8937.31 9014.51 1677.14 S 1415.93 W 5929184.79 N 684794.42 E 10.754 2191.01 ~~ 9663.20 79.390 181.490 8944.40 9021.60 1708.138 1416.78 W 5929153.79 N 684794.33 E 14.313 2214.04 9690.82 82.450 179.670 8948.76 9025.96 1735.39 8 1417.06 W 5929126.53 N 684794.73 E 12.848 2233.98 9724.67 86.540 178.780 8952.01 9029.21 1769.08 8 1416.60 W 5929092.87 N 684796.02 E 12.363 2258.07 9755.10 89.840 178.100 8952.97 9030.17 1799.48 S 1415.77 W 5929062.50 N 684797.60 E 11.072 2279.51 9783.34 91.730 174.970 8952.58 9029.78 1827.668 1414.07 W 5929034.37 N 684800.00 E 12.946 2298.75 9817.71 93.270 170.960 8951.08 9028.28 1861.738 1409.86 W 5929000.41 N 684805.04 E 12.487 2320.53 9849.11 93.270 167.150 8949.29 9026.49 1892.50 8 1403.91 W 5928969.79 N 684811.75 E 12.114 2338.71 9877 .33 93.150 163.570 8947.71 9024.91 1919.768 1396.79 W 5928942.72 N 684819.54 E 12.673 2353.54 9911.94 93.830 159.650 8945.60 9022.80 1952.53 8 1385.90 W 5928910.22 N 684831.24 E 11.4 75 2369.77 Sperry-Sun Drilling Services Survey Report for PBU_EOA as 13 - 13-13A Your Ref: API 500292085201 Job No. AKZZ0002409983, Surveyed: 3 May, 2003 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) r/100ft) 9943.12 95.930 156.270 8942.95 9020.15 1981.32 S 1374.24 W 5928881.73 N 684843.60 E 12.728 2382.59 9971.43 96.180 151.750 8939.96 9017.16 2006.62 S 1361.91 W 5928856.74 N 684856.55 E 15.901 2392.41 10005.49 95.250 147.410 8936.57 9013.77 2035.84 S 1344.75 W 5928827.96 N 684874.42 E 12,969 2401.74 10036.58 94.880 143.810 8933.82 9011.02 2061.39 S 1327.26 W 5928802.84 N 684892.54 E 11.595 2408.19 10065.00 94.450 141.570 8931.51 9008.71 2083.92 S 1310.09 W 5928780.75 N 684910.26 E 8.000 2412.67 -~ .",-~ . 1 0098.70 95.380 137.660 8928.62 9005.82 2109.49 S 1288.35 W 5928755.72 N 684932.63 E 11.884 2416.19 10129.80 96.060 134.710 8925.52 9002.72 2131.82 S 1266.92 W 5928733.93 N 684954.60 E 9.688 2417.59 10158.13 96.240 131.460 8922.49 8999.69 2151.05 S 1246.36 W 5928715.20 N 684975.63 E 11 .424 2417.34 10192.25 93.770 128.630 8919.51 8996.71 2172.92 S 1220.34 W 5928693.99 N 685002.18 E 10.985 2415.24 10223.28 90.860 126.060 8918.26 8995.46 2191.72 S 1195.69 W 5928675.80 N 685027.28 E 12.507 2411 .87 10250.88 90.310 123.360 8917.98 8995.18 2207.43 S 1173.01 W 5928660.65 N 685050.35 E 9.983 2407.61 10285.21 89.880 119.490 8917.92 8995.12 2225.33 S 1143.72 W 5928643.48 N 685080.07 E 11.342 2400.38 10314.89 89.380 117.370 8918.11 8995.31 2239.46 S 1117.62 W 5928630.00 N 685106.51 E 7.339 2392.62 10343.79 88.890 114.240 8918.55 8995.75 2252.04 S 1091.61 W 5928618.07 N 685132.82 E 10.961 2383.79 10378.94 88.640 110.850 8919.30 8996.50 2265.51 S 1059.16 W 5928605.40 N 685165.59 E 9,668 2371.17 10408.08 88.150 108.350 8920.12 8997.32 2275.28 S 1031.72W 5928596.31 N 685193.27 E 8.739 2359.33 10437.93 87.100 106.330 8921.36 8998.56 2284.17 S 1003.25 W 5928588.13 N 685221.94 E 7.622 2346.14 10472.47 87.720 103.730 8922.92 9000.12 2293.11 S 969.93 W 5928580.00 N 685255.48 E 7.731 2329.65 10503.21 89.200 101.410 8923.74 9000.94 2299.80 S 939.94 W 5928574.06 N 685285.62 E 8.950 2313.81 10531.17 89.940 98.670 8923.95 9001.15 2304.67 S 912.41 W 5928569.86 N 685313.26 E 1 0.150 2298.36 10563.64 90.430 94.660 8923.85 9001.05 2308.44 S 880.17 W 5928566.89 N 685345.59 E 12.442 2278.86 10593.69 90.190 91.910 8923.69 9000.89 2310.16 S 850.17 W 5928565.91 N 685375.62 E 9.186 2259.42 .'-" 1 0625.39 89.510 88.710 8923.77 9000.97 2310.34 S 818.48 W 5928566.52 N 685407.31 E 10.320 2237.69 10659.37 88.890 85.300 8924.24 9001.44 2308.56 S 784.55 W 5928569.13 N 685441 .18 E 10.199 2213.02 10690.31 88.400 82.420 8924.98 9002.18 2305.25 S 753.80 W 5928573.20 N 685471.84 E 9.440 2189.42 10718.79 87.590 79.470 8925.97 9003.17 2300.77 S 725.70 W 5928578.37 N 685499.82 E 10.735 2166.80 10752.45 87.280 77.600 8927.48 9004.68 2294.09 S 692.74 W 5928585.86 N 685532.60 E 5.626 2139.23 10783.30 86.670 73.950 8929.11 9006.31 2286.52 S 662.89 W 5928594.17 N 685562.26 E 11.979 2113.17 10811.05 86.480 71.000 8930.77 9007.97 2278.18 S 636.47 W 5928603.15 N 685588.46 E 10.634 2088.91 10845.65 86.91 0 67.710 8932.76 9009.96 2266.00 S 604.16 W 5928616.13 N 685620.47 E 9.574 2057.81 10874.29 87.710 65.410 8934.11 9011.31 2254.63 S 577.91 W 5928628.15 N 685646.43 E 8.494 2031.47 10904.96 88.210 62.580 8935.20 9012.40 2241.19 S 550.37 W 5928642.26 N 685673.63 E 9.364 2002.75 10949.43 88.150 61.630 8936.61 9013.81 2220.39 S 511.08 W 5928664.02 N 685712.39 E 2.139 1960.60 10999.17 88.580 61.090 8938.03 9015.23 2196.56 S 467.45 W 5928688.92 N 685755.43 E 1.387 1913.25 11093.43 89.260 60.680 8939.81 9017.01 2150.71 S 385.11 W 5928736.79 N 685836.61 E 0.842 1823,27 ----~ --_._---~--_. ---.-----_.--------- 12 May, 2003 - 9:27 Page 3 of5 DrillQlIest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA as 13 -13-13A Your Ref: API 500292085201 Job No. AKZZ0002409983, Surveyed: 3 May, 2003 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 11187.17 89.690 60.510 8940.67 9017.87 11218.25 89.810 60.560 8940.80 9018.00 11263.00 89.810 60.560 8940.95 9018.15 Local Coordinates Northings Eastings (ft) (ft) 2104.68 S 2089.40 S 2067.40 S 303.45 W 276.39 W 237.42 W All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 223.590° (True). Magnetic Declination at Surface is 25.933°(24-Apr-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11263.00ft., The Bottom Hole Displacement is 2080.99ft., in the Direction of 186.551 ° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8588.20 8615,00 11263.00 8272.72 8297.71 9018.15 1096.90 S 1102.01 S 2067.40 S 1087.71 W 1095.93 W 237.42 W Tie On Point Window Point Projected Survey 12 May, 2003 - 9:27 Page 4 of5 Global Coordinates Northings Eastings (ft) (ft) 5928784.81 N 5928800.76 N 5928823.71 N 685917.11 E 685943.78 E 685982.20 E Dogleg Vertical Rate Section (0/100ft) 0.493 0.418 0.000 BPXA Comment 1733.63 1703.90 1661.10 Projected Survey ~.... ____·_____~_r DrillQlIest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 13 - 13-13A Your Ref: API 500292085201 Job No. AKZZ0002409983, Surveyed: 3 May, 2003 BPXA North Slope Alaska Survey tool program for 13-13A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) - 0.00 8588.20 0.00 8588.20 8272.72 11263.00 8272.72 BP High Accuracy Gyro (13-13) 9018.15 AK-6 BP _IFR-AK (13-13A) ------- 12 May, 2003 - 9:27 Page 50f5 DrillQuest 3.03.02.005 i1 a03~u30 13-May-03 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 13-13 A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 8,588.20 I MD Window / Kickoff Survey: 8,615.00 I MD (if applicable) Projected Survey: 11,263.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED MAY 13 2003 AJaska o¡~ &. Gæ Coni. Comm_n Anmomge Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 13 13-13A MWD ...~'=--> Job No. AKMW0002409983. Surveyed: 3 May. 2003 Survey Report 12 May, 2003 Your Ref: API 500292085201 Surface Coordinates: 5930896.34 N. 686168.56 E (70012' 58.1631" N. 148029' 53.6811" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 .-~, Surface Coordinates relative to Project H Reference: 930896.34 N, 186168.56 E (Grid) Surface Coordinates relative to Structure Reference: 1755.16 S, 295.26 E (True) Kelly Bushing: 77.20ft above Mean Sea Level Elevation relative to Project V Reference: 77.20ft Elevation relative to Structure Reference: 77.20ft 5pe"""""'Y-5U1'l DRILLING SERVices A Halliburton Company Survey Ref: 5vy4024 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 13 -13-13A MWD Your Ref: AP/500292085201 Job No. AKMW0002409983, Surveyed: 3 May, 2003 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) (0/100ft) 8588.20 21.250 238.000 8195.52 8272.72 1096.90 5 1087.71 W 5929772.95 N 685108.23 E 1544.44 Tie On Point MWD Magnetic 8615.00 21.110 238.260 8220.51 8297.71 1102.01 S 1095.93 W 5929767.64 N 685100.14 E 0.629 1553.81 Window Point ß68B.1 G 2ß.400 235.410 B287.44 8364.64 1118.18 5 1120.54W 5929750.86 N 685075.94 E 7.398 1582.50 8782.06 29.980 227.050 8370.23 8447.43 1146.045 1154.93 W 5929722.17 N 685042.25 E 5.668 1626.38 8876.59 33.450 225.330 8450.63 8527.83 1180.465 1190.75W 5929686.87 N 685007.28 E 3.793 1676.02 '- 8970.57 35.510 222.020 8528.11 8605.31 1218.955 1227.45 W 5929647.49 N 684971.54 E 2.962 1729.20 9063.05 41.020 217.130 8600.71 8677.91 1263.155 1263.79 W 5929602.41 N 684936.31 E 6.795 1786.26 9155.48 45.600 210.290 8667.98 8745.18 1315.905 1298.79 W 5929548.81 N 684902.62 E 7.088 1848.60 9247.92 48.210 210.210 8731.13 8808.33 1374.21 5 1332.79 W 5929489.68 N 684870.07 E 2.824 1914.28 9289.11 49.010 208.480 8758.37 8835.57 1401.14 5 1347.93 W 5929462.38 N 684855.59 E 3.701 1944.22 9317.74 48.960 209.170 8777.16 8854.36 1420.075 1358.35 W 5929443.21 N 684845.65 E 1.827 1965.11 9352.21 48.950 205.030 8799.80 8877.00 1443.20 5 1370.18 W 5929419.79 N 684834.39 E 9.057 1990.03 9383.03 49.570 201.410 8819.91 8897.11 1464.66 5 1379.38 W 5929398.11 N 684825.72 E 9.123 2011.91 9411 .30 51.340 198.380 8837.92 8915.12 1485.155 1386.79 W 5929377.44 N 684818.81 E 10.368 2031.87 9444.33 53.990 195.040 8857.95 8935.15 1510.30 S 1394.33 W 5929352.11 N 684811.90 E 11.357 2055.28 9475.79 57.510 192.160 8875.65 8952.85 1535.57 5 1400.43 W 5929326.70 N 684806.43 E 13.506 2077.79 9502.42 60.450 1 90.140 8889.38 8966.58 1557.965 1404.83 W 5929304.21 N 684802.57 E 12.811 2097.04 9537.27 64.990 187.790 8905.35 8982.55 1588.54 5 1409.65 W 5929273.51 N 684798.52 E 14.339 2122.51 9568.05 68.520 185.320 8917.50 8994.70 1616.635 1412.87 W 5929245.35 N 684795.99 E 13.633 2145.08 9595.70 71.410 183.400 8926.97 9004.17 1642.53 S 1414.84 W 5929219.42 N 684794.66 E 12.320 2165.19 9631.39 74.840 181.560 8937.33 9014.53 1676.655 1416.31 W 5929185.27 N 684794.03 E 10.802 2190.92 9663.20 79.390 181.250 8944.42 9021.62 1707.645 1417.07 W 5929154.27 N 684794.04 E 14.335 2213.89 9690.82 82.450 179.850 8948.78 9025.98 1734.91 5 1417.33 W 5929127.01 N 684794.45 E 12.157 2233.82 9724.67 86.540 178.890 8952.02 9029.22 1768.59 5 1416.96 W 5929093.34 N 684795.65 E 12.408 2257.96 9755.10 B9.840 178.320 8952.99 9030.19 1798.99 5 1416.22 W 5929062.97 N 684797.14 E 11.005 2279.47 9783.34 91.730 175.420 8952.60 9029.80 1827.185 1414.68 W 5929034.82 N 684799.38 E 12.256 2298.82 9817.71 93.270 171.650 8951.10 9028.30 1861.305 1410.81 W 5929000.82 N 684804.08 E 11.839 2320.87 9849.11 93.270 167.820 8949.31 9026.51 1892.145 1405.23 W 5928970.12 N 684810.42 E 12.178 2339.35 9877.33 93.150 164.510 8947.73 9024.93 1919.495 1398.49 W 5928942.94 N 684817.83 E 11.719 2354.52 9911.94 93.830 162.340 8945.62 9022.82 1952.60 S 1388.64 W 5928910.09 N 684828.50 E 6.559 2371.71 12 May, 2003 - 9:29 Page 2 0'5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 13 -13-13A MWD Your Ref: API 500292085201 Job No. AKMW0002409983, Surveyed: 3 May, 2003 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) (0/100ft) 9943.12 95.930 156.880 8942.97 9020.17 1981.71 S 1377.82 W 5928881.26 N 684840.03 E 18.702 2385.33 9971.43 96.180 152.440 8939.98 9017,18 2007.14 S 1365.77 W 5928856.12 N 684852.70 E 15.621 2395.45 10005.49 95.250 149.510 8936.59 9013.79 2036.78 S 1349.33 W 5928826.91 N 684869.87 E 8.985 2405.57 10036.58 94.880 144.700 8933.84 9011.04 2062.77 S 1332.52 W 5928801.33 N 684887.32 E 15.457 2412.81 10065.00 94.450 141.950 8931.53 9008.73 2085.49 S 1315.60 W 5928779.04 N 684904.79 E 9.762 2417.60 10098.70 95.380 137.260 8928.64 9005.84 2111.05 S 1293.85 W 5928754.02 N 684927.17 E 14.138 2421.12 .---- 10129.80 96.060 134.190 8925.54 9002.74 2133.21 S 1272.25 W 5928732.41 N 684949.31 E 10.063 2422.27 1 0158.13 96.240 134.390 8922.50 8999.70 2152.87 S 1252.09 W 5928713.24 N 684969.95 E 0.947 2422.61 10192.25 93.770 128.390 8919.52 8996.72 2175.33 S 1226.60 W 5928691.42 N 684995.98 E 18.953 2421.31 10223.28 90.860 129.000 8918.27 8995.47 2194.71 S 1202.40 W 5928672.64 N 685020.65 E 9.581 2418.66 10250.88 90.310 128.250 8917.99 8995.19 2211.94 S 1180.84 W 5928655.95 N 685042.63 E 3.370 2416.27 10285.21 89.880 126.360 8917.93 8995.13 2232.75 S 1153.53 W 5928635.82 N 685070.44 E 5.646 2412.51 10314.89 89.380 124.690 8918.12 8995.32 2249.99 S 1129.38 W 5928619.18 N 685095.01 E 5.873 2408.35 10343.79 88.890 124.920 8918.56 8995.76 2266.48 S 1105.65W 5928603.28 N 685119.14 E 1.873 2403.94 10378.94 88.640 126.890 8919.32 8996.52 2287.09 S 1077.19 W 5928583.38 N 685148.10 E 5.648 2399.24 10408.08 88.150 114.490 8920.14 8997,34 2301.93 S 1052.19W 5928569.16 N 685173.46 E 42.570 2392.75 10437.93 87.100 105.770 8921.38 8998.58 2312.19 S 1024.22 W 5928559.60 N 685201.68 E 29.398 2380.89 10472.47 87.720 103.350 8922.94 9000.14 2320.86 S 990.82 W 5928551.75 N 685235.28 E 7.226 2364.15 10503.21 89.200 100.870 8923.76 9000.96 2327.30 S 960.78 W 5928546.05 N 685265.47 E 9.392 2348.10 10531.17 89.940 96.220 8923.97 9001.17 2331.46 S 933.14 W 5928542.58 N 685293.20 E 16.840 2332.05 10563.64 90.430 93.100 8923.87 9001.07 2334.10 S 900.78 W 5928540.74 N 685325.62 E 9.727 2311.65 10593.69 90.190 92.770 8923.71 9000.91 2335.63 S 870.77 W 5928539.94 N 685355.65 E 1.358 2292.07 10625.39 89.510 88.900 8923.79 9000.99 2336.10 S 839.08 W 5928540.26 N 685387.35 E 12.395 2270.56 10659.37 88.890 85.760 8924.26 9001.46 2334.51 S 805.15 W 5928542.68 N 685421.23 E 9.418 2246.01 - 10690.31 88.400 84.130 8924.99 9002.19 2331.79 S 774.34 W 5928546.16 N 685451.97 E 5.500 2222.79 10718.79 87.590 80.650 8925.99 9003.19 2328.02 S 746.13 W 5928550.63 N 685480.07 E 12.538 2200.62 10752.45 87.280 78.090 8927.50 9004.70 2321.82 S 713.08 W 5928557.64 N 685512.96 E 7.653 2173.34 10783.30 86.670 74.670 8929.13 9006.33 2314.56 S 683.15 W 5928565.63 N 685542.70 E 11 .246 2147.44 10811.05 86.480 71.690 8930.79 9007.99 2306.55 S 656.63 W 5928574.30 N 685569.01 E 10.741 2.123.36 10845.65 86.910 68.430 8932.78 9009.98 2294.77 S 624.17 W 5928586.87 N 685601.18 E 9.488 2092.44 10874.29 87.710 66.130 8934.12 9011.32 2283.72 S 597.78 W 5928598.57 N 685627.28 E 8.494 2066.25 10904.96 88.210 63.310 8935.22 9012.42 2270.63 S 570.07 W 5928612.34 N 685654.66 E 9.332 2037.66 10949.43 88.150 61 .440 8936.63 9013.83 2250.03 S 530.69 W 5928633.91 N 685693.52 E 4.205 1995.58 10999.17 88.580 60.920 8938.05 9015.25 2226.06 S 487.13 W 5928658.95 N 685736.48 E 1.356 1948.19 11093.43 89.260 60.460 8939.82 9017.02 2179.92 S 404.95 W 5928707.09 N 685817.49 E 0.871 1858.11 ---- 12 May, 2003 - 9:29 Page 3 0£5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 13 -13-13A MWD Your Ref: API 500292085201 Job No. AKMW0002409983, Surveyed: 3 May, 2003 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 11187.17 89.690 60.520 8940.68 9017.88 11218.25 89.810 60.660 8940.82 9018.02 11263.00 89.810 60.660 8940.97 9018.17 Local Coordinates Northings Eastings (ft) (ft) 2133.75 S 2118.49 S 2096.56 S 323:37 W 296.30 W 257.29 W All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 223.590° (True). Magnetic Declination at Surface is 25.933°(24-Apr-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11263.00ft., The Bottom Hole Displacement is 2112.29ft., in the Direction of 186.996° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~) Comment 8588.20 8615.00 11263.00 8272.72 8297.71 9018.17 1096.90 S 1102.01 S 2096.56 S 1087.71 W 1095.93 W 257.29 W Tie On Point Window Point Projected Survey 12 May, 2003 - 9:29 Page 4 of5 Global Coordinates Northings Eastings (ft) (ft) 5928755.26 N 5928771.19 N 5928794.07 N 685897.91 E 685924.60 E 685963.05 E Dogleg Vertical Rate Section (°/1 OOft) 0.463 0.593 0.000 BPXA Comment 1768.42 1738.70 1695.92 Projected Survey ~ .~ DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 13 - 13-13A MWD Your Ref: API 500292085201 Job No. AKMW0002409983. Surveyed: 3 May. 2003 BPXA North Slope Alaska Survey tool program for 13-13A MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8588.20 0.00 8588.20 8272.72 11263.00 8272.72 BP High Accuracy Gyro (13-13) 9018.17 MWD Magnetic (13-13A MWD) .~ .~ 12 May, 2003 - 9:29 Page 5 of5 DrillQuest 3.03.02.005 ,.,1\ ß ) Bií. BAIŒR MUGØlS . ~~__ .._...'_ ,_ M 0.._ ,.._..,. ~~~.. ~.~,~~_~"._.~'_. iNrEQ '\ ObP BP-GDB Baker Hughes INTEQ Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB OS 14 Well: 14-06 Wellpath: 14-06A Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 6/16/2004 Time: 17:10:01 Page: Co-ordinate(NE) Reference: Well: 14-06, True North Vertical (TVD) Reference: 16: 062/26/197900:0073.0 Section (VS) Reference: Well (0.00N,O.00E,313.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB OS 14 TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5939577.43 ft 674150.48 ft Latitude: Longitude: North Reference: Grid Convergence: 70 14 26.346 N 148 35 36.726 W True 1.32 deg Well: 14-06 Slot Name: 06 ì 14-06 W ell Position : +N/-S -993.65 ft Northing: 5938611.42 ft Latitude: 70 14 16.572 N . A) +E/-W 1182.38 ft Easting : 675355.42 ft Longitude: 148 35 2.360 W ~ (J) m Position Uncertainty: 0.00 ft il fT1 u (J Wellpath: 14-06A Drilled From: 14-06 a 500292032801 Tie-on Depth: 10064.00 ft C·1 m Current Datum: 16 : 06 2/26/1979 00:00 Height 73.00 ft Above System Datum: Mean Sea Level -- Magnetic Data: 5/7/2004 Declination: 25.29 deg N < I c:::» Field Strength: 57592 nT Mag Dip Angle: 80.84 deg c:> m Vertical Section: Depth From (TVD) +N/-S +E/-W Direction .þ¡... ft ft ft deg ~ 31.00 0.00 0.00 313.00 Survey Program for Definitive Well path Date: 6/16/2004 Validated: Yes Actual From To Survey ft ft 2700.00 10000.00 10064.00 11801.00 Version: Toolcode 2 Tool Name 1 : Camera based gyro multisho (2700.00-1~O-MS MWD (10064.00-11801.00) MWD Camera based gyro multishot MWD - Standard Annotation MD TVD ft ft 10000.00 8877.95 TIP 10064.00 8931.22 KOP 11801.00 9000.84 TO Survey: MWD Start Date: 5/20/2004 CoilTrak Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/1000 10000.00 33.50 242.00 8877.95 8804.95 -2442.69 -2794.67 5936104.56 672618.50 377.98 0.00 10064.00 33.82 242.64 8931.22 8858.22 -2459.17 -2826.08 5936087.36 672587.48 389.72 0.75 10094.33 45.49 244.64 8954.53 8881.53 -2467.71 -2843.41 5936078.42 672570.35 396.57 38.70 10125.52 54.30 251.00 8974.61 8901.61 -2476.62 -2865.49 5936069.00 672548.49 406.64 32.24 10159.93 64.63 246.00 8992.08 8919.08 -2487.52 -2892.99 5936057.45 672521.25 419.31 32.51 10202.70 76.44 240.20 9006.32 8933.32 -2505.79 -2928.84 5936038.36 672485.84 433.07 30.42 10232.39 85.83 237.00 9010.89 8937.89 -2521.06 -2953.84 5936022.51 672461.20 440.94 33.37 10263.96 91.40 227.76 9011.65 8938.65 -2540.30 -2978.80 5936002.69 672436.70 446.07 34.16 10303.26 98.19 225.32 9008.37 8935.37 -2567.22 -3007.21 5935975.13 672408.92 448.49 18.35 10333.43 98.90 219.91 9003.88 8930.88 -2589.17 -3027.40 5935952.72 672389.25 448.29 17.89 10358.44 99.30 214.98 8999.92 8926.92 -2608.77 -3042.41 5935932.77 672374.70 445.90 19.53 )ôL/- O~ lo þ ) llii. ObP BP-GDB BAKIR HUGHES Baker Hughes INTEQ Survey Report .n ._..' ...,,_._ ,,_ ___.__...~~__.,~__,._~.,. INTEQ Company: BP Amoco Date: 6/16/2004 Time: 17:10:01 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 14-06, True North Site: PB DS 14 Vertical (fVD) Reference: 16 : 06 2/26/1979 00:00 73.0 Well: 14-06 Section (VS) Reference: Well (0.00N,0.00E,313.00Azi) Wellpath: 14-06A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lncl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 10388.83 101.51 222.43 8994.43 8921.43 -2632.08 -3061.08 5935909.04 672356.58 443.66 25.18 10414.32 104.03 225.67 8988.79 8915,79 -2649.94 -3078.36 5935890.78 672339.72 444.11 15.85 10443.60 104.33 231,38 8981.62 8908.62 -2668.74 -3099.62 5935871.49 672318.90 446.84 18.93 10483.84 103.99 238.13 8971.76 8898.76 -2691.24 -3131.46 5935848.26 672287.59 454.79 16.29 10526.47 100.61 244.12 8962.67 8889.67 -2711.33 -3167.92 5935827.33 672251.62 467.75 15.85 10564.27 100.76 241.70 8955.66 8882.66 -2728.24 -3200.99 5935809.66 672218.95 480.40 6.30 10600.37 99.46 244.21 8949.33 8876.33 -2744.40 -3232.64 5935792.77 672187.69 492.53 7.73 10628.81 98.56 250.57 8944.87 8871.87 -2755.19 -3258.56 5935781.38 672162,03 504.12 22.31 10657.70 96.66 255.30 8941.04 8868.04 -2763.58 -3285.92 5935772.35 672134.87 518.41 17.51 10687.85 93.59 260.08 8938.34 8865.34 -2769.98 -3315.25 5935765.27 672105.70 535.50 18.79 10721.95 88.48 261.42 8937.73 8864.73 -2775.46 -3348.89 5935759.01 672072.20 556.36 15.49 10756.16 83.59 264.34 8940.09 8867.09 -2779.69 -3382.74 5935753.99 672038.46 578.23 16.64 10790.43 83,28 268.30 8944.01 8871.01 -2781.88 -3416.71 5935751.02 672004.55 601.59 11.52 10825.06 82.41 276.77 8948.33 8875.33 -2780.36 -3451.00 5935751.74 671970.24 627.70 24.40 10855.67 80.19 280.24 8952.97 8879,97 -2775.89 -3480.92 5935755.51 671940.22 652.63 13.35 10886.07 80.10 286.63 8958,17 8885.17 -2768.93 -3510.04 5935761.79 671910.96 678.67 20.71 10915.70 80.79 292.19 8963.10 8890.10 -2759.23 -3537.58 5935770,85 671883.19 705.44 18.65 10945.89 80.10 297.95 8968.11 8895.11 -2746.62 -3564.54 5935782.83 671855.95 733.75 18.95 10981.24 79.54 304.06 8974.37 8901.37 -2728.71 -3594.35 5935800.04 671825.74 767.76 17.09 11016.61 79.75 312.55 8980.73 8907.73 -2707.16 -3621,62 5935820.95 671797.97 802.41 23.62 11046.58 77.92 317.23 8986.54 8913.54 -2686.42 -3642.45 5935841.20 671776.67 831.79 16.49 11080.97 79.27 321.41 8993.34 8920.34 ~2660,86 -3664.41 5935866.24 671754.12 865.28 12.54 11113,23 80.51 327.12 8999.01 8926.01 -2635.09 -3682.95 5935891.57 671734.99 896.41 17.84 11143.71 80.37 332.67 9004,08 8931.08 -2609.10 -3698.02 5935917.20 671719,32 925.16 17.96 11182,71 79.44 339.62 9010.92 8937.92 -2574.01 -3713.54 5935951.92 671702.98 960.45 17.71 11218.97 80.55 344.07 9017.22 8944.22 -2540.08 -3724.66 5935985.57 671691.08 991.71 12.47 11256.59 83.58 352.27 9022.43 8949.43 -2503.65 -3732.29 5936021.81 671682.61 1022.14 23.04 11286.58 85.92 357.68 9025.17 8952.17 -2473.91 -3734.90 5936051.48 671679.31 1044.33 19.58 11324.33 90.14 6.25 9026.47 8953.47 -2436.25 -3733.60 5936089.16 671679.73 1069.06 25.29 11358.23 89.58 9.84 9026.55 8953.55 -2402.69 -3728.86 5936122.82 671683.69 1088.48 10.72 11389.56 90.51 17.97 9026.53 8953.53 -2372.31 -3721.34 5936153.37 671690.50 1103.70 26.12 11428.34 90.76 22.33 9026,10 8953.10 -2335.91 -3707.98 5936190.06 671703.01 1118.76 11.26 11462.79 92.38 25.63 9025.16 8952.16 -2304.45 -3693.99 5936221.84 671716.26 1129.98 10.67 11508.41 93.27 33.76 9022.90 8949.90 -2264.90 -3671.44 5936261.90 671737.89 1140.46 17.91 11548.23 93.45 43.26 9020.56 8947.56 -2233.83 -3646,71 5936293.53 671761.88 1143.57 23.82 11581,13 94.51 47.55 9018.28 8945.28 -2210.79 -3623.35 5936317.10 671784.70 1142,19 13.40 11622.31 96.28 53.29 9014.40 8941 .40 -2184.68 -3591.77 5936343.94 671815.67 1136.90 14.53 11657.44 96.67 58.02 9010.44 8937.44 -2165.00 -3562.96 5936364.29 671844.01 1129.26 13.42 11692.92 93.37 56.16 9007.34 8934.34 -2145.79 -3533.29 5936384.18 671873.22 1120.66 10.67 11754.03 93.47 47.71 9003.68 8930.68 -2108.22 -3485.31 5936422.86 671920.31 1111.19 13.80 11801.00 93.47 47.71 9000.84 8927.84 -2076.67 -3450.62 5936455.20 671954.25 1107.34 0.00 BP Amoco WELLPATH DETAILS Parent Wellpath: Tie on MD: 14-06A 500292032801 14-06 10064.00 Rig: Ref. Datum: Nordic 2 16 : 06 2/26/1979 00:00 73.00ft V.Sectfon Origin Origin Angle +N/-S +EI·W 313.00· 0.00 0.00 Starting From TVD 31.00 REFERENCE INFORMATION Co-ordinate (N/E¡ Reference: Well Centre: 14-06, True North Vertical (NO Reference: System: Mean Sea Level Section (VS Reference: Slot - 06 (O.OON,O.OOE) Measured Depth Reference: 16: 062/26/197900:00 73.00 Calculation Method: Minimum Curvature ëa550 ~8600 an ~650 .c .. ~700 Q _8750 ca .!:! 8800 1:: ~8850 G.I 28900 I- 8950 ANNOTATIONS TVD MD Annolalion ¡¡¡[if' 000 -25Uoe -31899<1 Pdo,gcn ~~ ~~ t~~ ~ª 8804.95 10000.00 TIP 8858.22 10064.00 KOP 8927.84 11801.00 TO 8350 8400 8450 8500 Ot)P :5-2000 = -2100 o o ... -2200 - - + -2300 - .c 1:: -2400 . o ~-2500 -: . . .. f-2600 ~ ~ -2700 -2800 -1500 -1600 -1700 -1800 -1900 -2900 -3000 -3100 -3200 rei. BtIL. INTEQ LEGEND 14-06.14-06A,Plan 1>6 14-06 (14-06) 14-06A MWD T ^M Azimuths to True North Magnetic North: 25.29· Magnetic Field Strength: 57592nT Dip Angle: 80.84° Date: 5/7/2004 Model: bggm2003 Rak2r Hll'.JnsS Survey: MWD (14-06I14-06A) Created By: Digital Business Client UserDate: 611612004 .ø:~-- .-"... :2 ~, ,", ·-i~~~~~ /J í é Ccntac! jnfor:n8tion I 14-06.14-06A.Plan ~ ~ r..... . . . .... .... ..' .y//\..."t..~.IP \ . .114-06(14-06\;~/f· ~ u\_<=j;2n u,o'u . - . . -------- -- -.--- - - . -.. -.. -- - --- - - -- -4400 -4300 -4200 -41 00 -4000 -3900 -3800 -3700 -3600 -3500 -3400 -3300 -3200 -3100 -3000 -2900 -2800 -2700 -2600 -2500 -2400 -2300 -2200 -21 00 -2000 -1900 -1800 West(-)/East(+) [100ft/in] - ...~ , ~-_.- . - ; .,- --~-- U·.·... .m_:~~- 9000 9050 9100 /14-06 (14-06)1;, . -50 0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 1850 Vertical Section at 313.00° [50ft/in] 6/16/200'1 5:13 PM ') ) 3°3'-03(0 , \ q~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska May 15, 2003 RE: MWDFormationEvaluationLogs 13-13A, AK -MW -2409983 1 LDWG formatted Disc with verification listing. llPI#: 50-029-20852-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNJNG AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun DriUing 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: S· ed~ '^' \ .. -.....,~ (\ ....'.....,......... >0... tgn :, ~~\ ~'- ,''V,"" \...:\ '-~.u.;_J:1_~..x_~jY\ F{E~CE¡\lED I! I~' I 0 n ,-.r".,~,":;' tJUi'~ ~~ C..Jj\JJ ÞJŒ~~+~3 (};·1 ~:~: :~:~;;~i~·::~·,. '~_:·~'~-~~;;·:i:.~~o~ /~;: (:h:0r.t1"i~':;' K~~~0 13-13A (J>TD #2030360) Former Class 137-A well-Return to product ion ) ) Subject: 13-13A (PTD #2030360) Former Class 137-A well- Return to product ion Date: Wed, 28 May 2003 15:55:32 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP .com> To: "AOGCC Winton Aubert (E-mail)..<Winton_Aubert@admin.state.ak.us>. "AOGCC Jim Regg (E-mail)..<Jim_Regg@admin.state.ak.us> CC: "AOGCC Field Inspectors (E-mail)..<AOGCC_Prudhoe_Bay@admin.state.ak.us>. "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>; "AOGCC Bob Fleckenstein (E-mail)..<Bob_Fleckenstein@admin.state.ak.us> Hi Winton and Jim, The 13-13 well (PTD #1821780) was classified as a 137-A well following the A-22 incident in August 2002. The 13-13 well was subsequently P&A'd in March 2003 and the 13-13-A sidetrack was drilled and completed in May 2003. In conjunction with the sidetrack, the wells tubing was replaced. As part of the completion process, we performed an MIT-T and an MIT-IA to 3500 psi (thereby establishing two barriers between the formation and surface). The completed MIT form is attached. This well was returned to production as the 13-13A (PTD #2030360) on May 27, 2003. If you have any questions, please let me know. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 «MITP PBU 13-13 05-05-03.xls» «13-13 5-5-03.xls» '" '·¡I,·A'··..··'··..·.., .... ,'."", ",.,. ,......... ",,,,,,/'1,, ...............'.... ......w'.. I Name: MITP PBU 13-13 05-05-03.xls DMITP PBU 13-13 05-05-03.XIS...·I· Type: Microsoft Excel Worksheet (application/vnd.ms-excel), Encoding: base64 .~ "'" .......... . ..,.. ..".....w."."....,,,._,...... 1.""..............."'.....""".'/1."1",<;.'............."'...".' .m."""",','" "" .w··' ..........'....... '·'''''V ·,II"~"·NI^_W."". .·.··...WI'·...A',"...".......·..v,<A/.\ ........., _"'<)'1. "1,1'1'"",,,,,,,,, ',v. .·...·....'·....'l....v.''"'''" .VA "".1 '.wv.·.·..."w."...".".I..w·' .,...."....J. Name: 13-13 5-5-03.xls DI3-135-5-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 . ..'..1' ,"V,", '" A Av .., , 1.1 '" .~... .'.1 .'1. ., . A 'J'. .1,. ·A..M.v-. A ,- .I.'J'. 1 of 1 5/29120037:47 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I OS-13 05/05/03 Rail / Wesley Packer Depths (ft.) well13-13A I Type Inj. Producer MD/TVD 9,155' 8,745' TUbing P.T.D. Type test MIT-T Test psi 3500 Casing Notes: MIT-T performed after setting new production packer on new production tubing. well13-13A I Type Inj. Producer MD/TVD 9,155' 8,745' TUbing 15001 P.T.D. Type test MIT-IA Test psi 3500 Casing 0 Notes: MIT-IA was performed after setting new production packer on new production tubing. well I Type Inj. MD/TVD TUbing P.T.D. Type tes~ Test psi Casing Notes: weill I Type Inj. P.T.D, Type tes~ Notes: weill I Type Inj. P.T.D. Type tes~ Notes: Pretest ~I Initial 15 Min. 30 Min. 350~ 350~1 350~ Interva1 I P/F P 15001 15001 15001 Interva1 I 3500 3500 3500 P/F P Interva1 P/F Interval P/F I Interva1 P/F MD/TVD Test psi TUbingl Casing MD/TVD Test psi TUbing Casing T est Details: This well is a Class 137-A well that has been rig sidetracked and a new packer and tubing string has been installed. The MIT-T and MIT-IA were performed during the sidetrack operations by the Nabors 2ES crew. The well was put on production on May 27,2003. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 MITP PBU 13-13 05-05-03.xls ), , ) . . WELLHEAD PACKOFF TESTING FORM 2003 WELL: DS:13-13 DATE: 4/26/03 & 5/5103 TESTED BY: FMC O'Neal & Cody TEST FOR: John Cubbon FSO TICKET #: 52716 & 52672 TYPE & GEN: FMC NSBB INITIAL PRESSURE DATA Well Status: New Install TYPE: TBG: CONTROL: o NIA IA: 0 BALANCE: OA: NIA o TubinQ HanQer Test Pass Pressured To: 5000 Press. @ 15 min: 5000 Press. @ 30 min: 5000 Test Port Press. @: 0 Bled to 0 Psi YES 1 NO Were Lockdown Screws Tightened? YES 1 NO Torqued to 450 ftIlbs Comments: New wellhead. Tested tubing hanger void to 5000 psi. Good test. Inner CasinQ HanQer Test Pass Pressured To: 3800 Press. @ 15 min: 3800 Press. @ 30 min: 3800 Test Port Press. @: 0 Bled to 0 Psi YES 1 NO Were Lockdown Screws Tightened? YES 1 NO Torqued to 450 ftIlbs Comments: New wellhead. 9-5/8 set on slips. Tested to 3800 psi. Good test. J ~:J&\uŒ :'1 fÆ~fÆ~~~fÆ AI'!ASKA. ORAND GAS CONSERVA.TION COltDllSSION FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit 13:-13A BP Exploration (Alaska) Inc. Permit No: 203-036 Surface Location: 855' NSL, 1076' WEL, SEC. 14, T10N, R14E, UM Bottomhole Location: 1222' SNL, 1277' WEL, SEC. 23, T10N, R14E, 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 pem1Ìts 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, Sy¿u=~ Commissioner BY ORDER O~..J~E COMMISSION DATED this.1f!:ðay of March, 2003 cc: Department of Fish & Game, Habitat Sectión w/o encl. Department of Environmental Conservation w/o encl. , STATE OF ALASKA \ ALASKA __)L AND GAS CONSERVATION COMrv..~!SION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test aI Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 74.5' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028315 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number , 13-13A /' 9. Approximate spud date 04/10/03 /' Amount $200,000.00 14. Number of acres in property 15. Prop9Sed depth (MD and TVD) 2560 /'11081' MD /8995' TVD o 17. Anticipated pressure {S~O AAC 25.035 (e) (2)} 92 Maximum surface 2420 psig, At total depth (TVD) 8800' / 3300 psig Setting Depth Top Bottom Length MD TVD MD TVD 855' 8475' 8261' 9330' 8862' 1901' 9180' 8761' 11081' 8995' 1 a. Type of work 0 Drill aI Redrill ORe-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 x = 686169, Y = 5930896 855' NSL, 1076' WEL, SEC. 14, T10N, R14E, UM At top of productive interval x = 684790, Y = 5929275 732' SNL, 2495' WEL, SEC. 23, T10N, R14E, UM At total depth x = 686020, Y = 5928815 1222' SNL, 1277' WEL, SEC. 23, T10N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well,/' ADL 028314, 4002' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8500' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casina Weight Grade CouDlina 7" 26# L-80 BTC-M 4-1/2" 12.6# L-80 IBT-M Hole 8-1/2" 6-1/8" VJC1Â- J IUI¿cc:s 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantity of Cement (include staae data) 190 sx Class 'G' .,; Uncemented Slotted Liner /' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9600 feet Plugs (measured) IBP Set at 8928' (03/98) true vertical 9231 feet Effective depth: measured 8928 feet Junk (measured) true vertical 8592 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 9228' - 9252', 9254' - 9262', 9270' -9282', 9328' - 9338', 9342' - 9346', 9346' - 9366', 9376' - 9396', 9398' - 9404', 9408' - 9415' true vertical 8875' - 8899', 8900' - 8908', 8916' - 8927', 8971' - 8980', 8984' - 8988', 8988' - 9007', 9017' - 9026', 9038' - 9043', 9047' - 9054' aI Filing Fee 0 Property Plat aI Drilling Fluid Program 0 Time vs Depth Plot 791 20" 2586' 13-3/8" 9201' 9-5/8" 730' 7" Perforation depth: measured 20. Attachments Contact Engineer Name/Number: Phil Smith, 564-4897 Cemented MD TVD 500 sx Arcticset II 79' 79' 2300 sx Fondu, 400 sx Permafrost 'C' 2586' 2586' 500 sx Class 'G', 300 sx PF 'C' 9201' 8850' 325 sx Class 'G' 8867' - 9597' 8534' - 9228' o BOP Sketch 0 Diverter Sketch aI Drilling Program o Refraction Analysis 0 Seabed Report aI 20 AAC 25.050 Requirements Prepared By NamelNumber: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Billlsaacson 'L }~.. L \__ . .....Title ..~eniorDrilling Engineer ,Çòrn~ission',",seOnlY ' Permit Number API Number 20.3 - 0 c 5 h 50- 029-20852-01 Conditions of Approval: Samples Required 0 Yes ~ No Hydrogen Sulfide Measures EI Yes 0 No Required Working Pressure for BOPE 0 2K Other: T.e-~t--gO\>E- tc sÇoc eSt. Approved By .æL-¿Þ7 4-/Æ~ Form 10-401 Rev. 12-01-85 Date M~t(\\ 5, z.oo~ APpr9Jval Da~e. See cover letter , .!]. L ~ ~ for other reauirements Mud Log Required 0 Yes Ið1 No Directional Survey Required .mI Yes 0 No o 3K D4K D5K D10K D15K 0 3.5K psi for CTU C,omm, issioner . . '0\' ' by order of the commission Date P?I//~J ¿~i~ l¡çr~¡cate ~JZ;0!'7 ¡{l,:r / / e r ') ) I Well Name: IDS 13-13A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Sidetrack Horizontal Producer Surface Location: Estimated Target Location: Sadlerochit Zone 2 Bottom Hole Location: x = 686,168.56 8551 FSL, 1076' FWL X = 684,790.00 732' FNL , 2785' FWL X = 686,020.00 12221 FNL , 1277' FEL Y = 5,930,896.34 Sec. 14, T10N, R14E Umiat Y = 5,929,275.00 TVDss 8890 Sec. 23, T10N, R14E Umiat Y = 5,928,815.00 TVDss 8920 Sec. 23, T10N, R14E Umiat /' I AFE Number: I PBD_ 4P2046 I I Estimated Start Date: 1 04/10/03 1 MD: 111,081' I I RiQ: 1 Nabors 2ES / I OperatinQ days to complete: 120 I 1 I TVD: 18995' 1 BF/MS: 146.0" I I RKB: 174.5' I Well DesiQn (conventional, slim hole, etc.): I Horizontal Sidetrack I Objective: 1 Zone 4B, Sadlerochit ",,/ CasinQITubinQ Program Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg C.D. / / MDrrVD MDrrVD 81/2" 7" 26.0# L-80 BTCM -855' 8475' I 8261' 9330' I 8862' 61/8" 4 ¥2" Slotted 12.6# L-80 IBT-m -1900' 9180' I 8761' 11,081'/8995' Tubing 4 ¥2" 12.6# L-80 IBT-m -9150' GL 9150'1 8740' Directional KOP: 18,500' MD Maximum Hole Angle: Close Approach Well: Survey Program: DS13-13A Sidetrack -29.0° in original well bore at 7700' MD. -92.0° through reservoir section of planned sidetrack from 9720' MD to 89.40 to TO at 11,081' MD. There are no close approach issues of concern: The closest well to the 13- / 13A Plan is DS13-35 with a center-center distance of 1070' and allowable deviation of 868' at the planned depth of 10,225' MD. This well passes major risk criteria and will not be shut in while drilling. Standard MWO Surveys from kick-off to TO. Page 1 ) Mud ProQram Window Milling Mud Properties: LSND Density (ppg) Viscosity PV 11 .2 50 - 60 1 0 - 13 Drilling Mud Properties: LSND Density (ppg) Viscosity PV 11.2 45 - 55 11 - 15 Production Mud Properties: Quickdril-N Density (ppg) Viscosity PV 8.4 - 8.6 45 - 55 6 - 8 Logging Program 8 %" Intermediate: Sample Catchers - None Drilling: MWD Dir/GR/PWD Open Hole: None Cased Hole: None ') I Whip stock Window 9 5/8" I VP tauO HTHP pH API FI 25 - 35 6-8 <10 9.0 <6 I 8 Y2" Hole Section I VP tauO HTHP pH API FI 20 - 30 4-7 <10 8.5 - 9.0 <6 I 6 1/8" hole section I VP tauO MBT pH API FI 22 - 27 4-7 <3 8.5 - 9.0 NIC 61/8" Production: Sample Catchers - Two, at Company man call out Drilling: MWD Dir/GR/Res/ABI- Real time GR/RES throughout entire interval Open Hole: None Cased Hole: None Cement Proc ram -- Casing Size 7" Intermediate Liner Basis: Lead: None Tail: Based on 85' of 7" shoe track, 705' of 8 Y2" open hole with 40% excess, and 150' of 9 5/8" x 7" liner lap + 185' of 9 5/8" x 4" DP annulus volume. -& Tail TOC: -8475' /' MD (8261 'TVDbkb).- Liner top 4?,,§~/' Fluid Sequence & Volumes: Pre None <::' Flush Spacer Lead Tail Casing Size 14 %" Production Liner Basis: I None: Slotted Liner / OS 13-13A Sidetrack 20 bbls Alpha Spacer at 12.2 ppg None /") 40 bbl 1225 fe I ..,çJ sks of Halliburton 'G' at 15.6 ppg and¿6-9''' dIsk, BHST 200~ 8300' TVDss TT = Batch Mix 4 to 4.5 hrs Page 2 ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. r-' BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- · Maximum anticipated BHP: 3300 psi @ 8800' TVDss -Ivishak · Maximum surface pressure: 2420 psi @ surface ~" (based upon BHP and a full column of gas from TO @ 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 1\ wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Formation Markers Formation Tops (Wp#1) MD TVDss Comments CM2 CM1 THRZ 8038' BHRZ 82031 TJE Not Picked TJD 8226' TJC 8,824 8410' TJB 9,197 8699' TJA 9,202 8703' TSGR 9,330 8781' TSHU 9,365 8810' TSADITZ4B 9,533 88921 TZ4A Not Penetrated TD 11,081 8920' GOC/MGOC Not present in the area MHOT 8970' Not Penetrated MOWC 9010' Not Penetrated TD Criteria: Drill 13-13A to well plan (400' shy of Fault 2) OR stop short of PTD if Sw's are too high to make a viable producer. This would require drilling a prolonged section of consistently low resistivity formation. The GPB subsurface group in collaboration with Drilling will call TD prior to plan if resistivity measurements dictate. Net pay will not be a TD pick criteria. Sidetrack and Complete Procedure Summary DS 13-13A Sidetrack Page 3 ) ') Sidetrack and Complete Procedure Summary Ria Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace wJ"'to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull 4 %" tubing from cut. .-' ~ 5. Pressure test the well to 3500 psi. Be prepared to pick up an RTTS if casing test fails. / 6. Run GRlJB on e-line to 8650'. ~" 7. RIH with Halliburton 9 5/8" composite bridge plug and set at 2000'. Pressure test to 3500 psi. 8. RIH with multi-string cutter. Displace the top 100' of casing with dead crude and cut the 9 5/8" casing in the center of the second joint below the mandrel hanger. /" 9. Pull 9 5/8 packoff, RIH with spear and recover the cut section of 95/8" casinjJ. 10. Make up 13 3/8" storm packer and set just above the top of the 1J-318"casinQ.Ætub. Circulate to seawater above the bridge plug. 't "~/6" \W"..!.l- 11. Pick up a 13 3/8" test packer and test the bridge plug to 1000 psi. "./ 12. Drain the BOP stack. ND BOPs and tubing spool. ND and remove casing spool. 13. Remove support clamps from the 13 3/8" casing head and cut off the original base flange. 14. Dress off the 13 3/8" casing stub and install a new bell nipple and FMC Big Bore starting head. /' 15. Install FMC casing and..tubing spools. 16. NU and test BOPs. / 17. RIH w/ bridge plug recovery tool. Swap the seawater for dead crude and recover the bridge plug. 18. RIH with 9 5/8" back-off tool and back off the cut stub. / 19. Spear the cut stub, POH, LD spear and fish. 20. Make up the new top joint of 9 5/8" BTC on a Baker guide sub, screw into existing 9 5/8" casing. 21. Hang off the casing on slips, install packoff and wear ring. 22. Test 95/8" casing to 3500 psi again against the bridge PlUg./' 23. Pick up an 8 %" mill and mill the composite bridge plug. RIH to top of tubing stub and circulate the well to milling fluid. POH. ' 24. RIH with 95/8" bottom-trip whipstock and milling assembly. /' 25. Orient and set bottom trip whipstock such that KOP is at 8625' MD. Mill window, POOH. ,/ J.- 26. RIH with 8 %" drilling assembly to top of window. Perform FIT to 12.5 ppg. l .....;;? vJ~ 27. Kick off and drill 8 %" section (±700') to top of Sag River formation. POH. I I J._.", ·£!.L.~~v ' 28. Run and cement 7" 26# drilling liner. Displace with drilling mud. ~4" ,/) 29. RIH with 6 1/8" drilling assembly, test casing and liner lap to 3500 psi, drill out the .þridge eJUg and 30. ~~~~~:~~t mud to Flo Pro drill-in fluid. Perform FIT to 10 ppg EMW. ~;-:.~ 31. Drill the 61/8" production hole (±1750') as per directional plan to TO well at ±11,081' MO./ 32. Short trip, CBU, spot liner running pill, POH. / 33. Run a 4 %", 12.6#, slotted x solid L-80 production liner to TO. Circulate the well to clean seawater at the liner top, POOH. / 34. Run 4 %", 12.6# L-80 completion tying into the 4 %" liner top. 35. Set packer and test the tubing and annulus to 3500 psi for 30 minutes. .-' 36. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 37. Freeze protect the well. 38. Rig down and move off. /' Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. OS 13-13A Sidetrack Page 4 ) ) .¡;<I/_\l:V.I:U;--;··I-'·I\l/ur"'¡I~-'·-"'~--I IJ .V ··Il\_\·--I···II\.....~!.:.I.'I·I¡'-;·'-.-, TII.'.IIoI':\' ··/I'-:n·I..,.......'.I'A·--n'r·.'I' MVI Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move to OS13-13. The two closest wells are OS13-12 and OS13-14, each on 120' centers. OS13-29 across the pad is 185' away from DS13-13. ~ OS13 is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Closest BHL Wells 13-12 30ppm H2S (1/24/2003) 13-28 No recorded H2S readings 13-14 25ppm H2S (1/27/2003) 13-35 No recorded H2S readings The maximum level recorded of H2S on the pad was 161 ppm on DS13-33 in 1999. The / most recent DS13-33 reading was 50 ppm in March 2002. » Post Permit to Orill and Summary of Orilling Hazards in the dog house and camp prior to spud n.. "y,",;rf¡:·'¡';-.'\'-'~'I_n-"¡'I-"'..v,..· .\I¡..j.!........,...., . ......0.. ...... ........ ..".... .. .. ".....¥...... .·:·;";·:·I-;'T;:Î:ur,,'I~. .;..\.1\.1. .\.,....... ,...;T;-··.-~..,... Job 2: De-complete Well Hazards and Contingencies ~ The perforated intervals and lower section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. ~ A braden head clamp and support rings on the wellhead help provide structural integrity for the weight of the BOPs. Leave the rings on until the well is secure and the BOPs are nippled down. Avoid lateral movement of the BOPs on the wellhead. U/_I:,oI¡,Hlill~Io""',- ~ '1.\1 ¡1-~,~\oI11 _ '._:J¡~I.I_\IH-. II-V.I.\; -~-~ L~; U, ~11\1~1 Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. . \' ..;... ........\..;... ..... "... ................ .......; ...... ............., Job 4: Drill 8 112" Intermediate Hole Hazards and Contingencies » The well will be kicked off in the Kingak shale so wellbore stability is a major concern. Ensure the mud weight does not drop below the minimum stated requirement. Use PWO to ensure good drilling and connection practices. » : In the worst-case scenario of 8.5 ppg pore pressure at the Sag River depth, / 12.0ppg at the 9 5/8" casing window, and 11.2 ppg mud in the hole, the kick Job 6: Install 7" Intermediate Drillina Liner Hazards and Contingencies » Minimize surge while RIH with the drilling liner. The pad data sheet lists several wells where lost circulation occurred during the cement job. DS 13-13A Sidetrack Page 5 ) ') II '.....!' #"\"~'ì'':' ',~j~'''' "I' _\0'"'\ ',/'10"11111',..\\1\ . . . \'.\ "'n-AI: \ VlV·_IIW'.\ "·-¡I'I..\II'I'II. I,H_'t'/hlll'-- U'JI ,I, --.-_I\.;¡O;'....'_~\,:_-_:V.I-_\P\\:\-\I'\\I-I- ;-II'~V\ 1.·-.....-.1. ;~-~-1...- ~\'I-'-_H-_\:_~_....-_.\;---\-_U'·\ '",'I!HIWW'_WT\\A.",,:.'\\· -'I Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies )ì;> There are no anticipated fault crossings while drilling 0513-138. » There is ±15' uncertainty on the depth of the top of Zone 4. To avoid drilling too much Shublik, hold 70° inclination until TZ4 is penetrated, then build to horizontal. Geosteering should emphasize staying below the Shublik while drilling the horizontal section. » The parent well has been frac'd (300' away at the 7" shoe). The frac should not have propagated as far as the planned sidetrack profile, but unrestricted LCM use is okay in the intermediate section and in the production section up until penetrating zone 48. "., ....... .."...."..... ."''', ................".... Job 9: Install 4112" Production Liner Hazards and Contingencies )ì;> Differential sticking is a concern. The 8.5 ppg Quickdril will be -400 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~;v..H-_U.'\....!.,_,UI.¡¡.\~.~I~- _W\""\'4:.<.nwl."'r_~.fI\-1 I' -; -: :11' ~\.'I: "",\1"'·1" ; ;\~U'HIHH"'I": '-,I"H'HHII L~:lx_a-U:_-,"'-.'\;"I; - '~\I\-"AI~A HL- X\IVj_\'".,.un\l.\.~U\H\HU~-- AI.~U_III.:_'U' _'UH"L~U ., ~-x ~LI.I-I~-· _ ~ _ -:It.,.n-, """1...-: I' -,-: '-.'(0'. -",,, -:' I ." r...n·-1"1"",:, Job 12: Run Completion Hazards and Contingencies )ì;> 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. ... .... ·-"~"'U"IU"W¡¡,H:· '.',., ·',.H Job 13: ND/NU/Release Ria Hazards and Contingencies )ì;> Though there are no close proximity surface issues, 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 about the pad and while positioning on the hole. ~'101-. .'1'1. - ..~..".,;"n . 1.- - - 1\",-......-.-. .;\"...- .. ,.. ,.~'~-"'I"... .,-~\. -. ,-.-..,.1";.......... ....,.--, .. -,,-;.,.. - ;-.;......T,- -. ".I""~. - - -.....1 --......" \,,\,0\"0-0\.. -. 1..\-.1'-- - ... ;-04.¡'¡'\" ...... ..\.. . .... .1.;"...,..1. .1, ~-. -.. ;, ...~1---"'- ............,.. .n., .....,.-.~j-.-",.... .--"'----, -. ..... ,.-nn'--;~L- -.. ....-,-,-.- -,-, .,\'or.- -,-.." ,.- -.. ,... ....", OS 13-13A Sidetrack Page 6 TREE = GRA Y GEN 3 WELLHE4\D = GRAY ACTUAtÖR; 'AXELSON Kä.'ËLBi"; 89' BF. ELEV = ? KOP = '" 46Óo' Max Angle = 29 @ 7700' DatÚmMÖ;9242' ...,...,.."...",.".,....".,..'"""..,.",'...... . Datum lV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2586' ~ ) Minimum ID = 3.250" @ 2888' 4-1/2" Merla Patch (Set 8/9/92) Chern Cut -8652' I TOP OF 7" LNR l-i 8867' 13-13 Pre-Rig e I L I )sAFElY NOTES: TROUBLE WELL - TX IA COMM, FTS PATCH @ 2888', 3.25" ID MERLA OX X FORM COMM (to 133/8" BRADENHEAD CLAMP). SECURED LONG-TERM WITH IBP IN TT. 1 2200' l-i 4-1/2" OTIS DBE SSSV NIP, ID = 3.813" 1 ~I 2888' l-i 4-1/2" MERLA PATCH SET 08/09/92, ID = 3.520" GAS LIFT rv1ANDRELS DEV TYÆ VLV LATCH PORT DATE 1 OTIS RA 15 OTIS RA 23 OTIS RA 22 OTIS RA 28 OTIS RA 24 OTIS RD 21 OTIS RO-5 21 OTIS RO-5 21 OTIS RA ST MD lVD 1 2895 2895 2 4805 4799 3 6199 6101 4 7210 7029 5 7856 7609 6 8265 7975 7 8592 8277 8 8701 8379 9 8775 8448 .... ~ 8801' l-i 4-1/2" BOTPBRASSY 1 Z ---i 8822' l-i 9-5/8" X 4-1/2" BOT 3-H PKR 1 z ~ I B ]I I I 14-1/2" TBG-PC, 12.6#, N-80, 0.0152 bpf, ID = 3.958" l-i 8936' ~ TOe -9050' 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9201' ÆRFORA TION SUMrv1ARY REF LOG: BHCS ON 11/24/82 ANGLE AT TOP ÆRF: 18 @ 9228' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9228-9262 0 08/09/92 3-3/8" 4 9270-9282 0 08/09/92 3-1/8" 4 9328-9338 0 04/11/84 3-1/8" 4 9342-9366 0 01/17/86 3-1/8" 4 9376-9404 0 01/17/86 3-1/8" 4 9408-9415 0 01/17/86 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" l-i 9597' ~-i 9600' DATE 11/28/82 05/19/87 11/20/00 10/25/01 03/03/03 REV BY DATE SIS-JH RNlTP PGS COMMENTS ORIGINAL COMPLETION RWO (CHANGEOUTTBG) CONVERTED TO CANV AS CORRECTIONS Proposed Pre-Rig ¡....4 ":::' : :. :'. _ .. .~ ~ :,,' '.' ",. "f '. $. ' I ~ . .no ..' :,: ,',",'0 <>::-'~,:.' ~I .. .,."41 .: . ~ () , .: < . I þ" ,~,. )) ~ s,:.,'·.f ." , .~,'.,,~}'~ ~ ,',4"r . ...¥ . .1) Þ~0· $¡.::c;¡.. ~ ". ., ~ REV BY COMMENTS 8917' l-i 41/2" OTIS XN NO-GO NIP, ID = 3.725" 1 8936' l-i 4-1/2" WLEG 1 8924' l-i ELMTTLOGGED01/17/86 1 l-i CA-RD- T-2 - 07/30/97 1 PRUDHOE BA Y UNrr Wa.L: 13-13 ÆRMrr No: 82-178 API No: 50-029-20852-00 SEC 14, TlON, R14E 2443.26 Fa. 396.1 FNL BP Exploration (Alas ka) TREE = WELLHEA,.D= FMC Big Bore ACTuÄTOR; . AXELSON \'kB'~"'ELËV'" ~.., .. '" " .. ..., '8'~i" BF. ELEV = ? KOP = 4600' Max Angle = 29 @ 7700' Datuïìî"Mb"; . "."... ,. . '924'2' ...',.','.,..,..,...,..",..,.".,....,.,..,...',. Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2586' ~ 13.·.3A Proposed 4 1/2" 12.6# L-BO IBT tubing I 7" 26# L-80 Liner Top llieback l-i 8475' I 1 9 5/8" Whipstock / Window /-) 1-i~62?'/ I q .r '~,/ 1 Chenical Cut l-i -8700' 141/2" BOTPBRAssembly l-i 8801' 1 TOP OF 7" LNR l-i 8867' I 14 1/2" WLEG l-i 8936' I 1 Top Cement l-i 9050' I 19-5/8"CSG,47#, L-80,ID=8.681" l-i 9201' r..4I ABANDONED ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/24/82 ANGLEATTOPÆRF: 18 @ 9228' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9228-9415 SQZ 11/01/02 I I L l If ~ Z L . ~ I I .. €I" ".e© - . .~, . .:~ ,,,;::: .'1..",*" Ii- · 1& " CA-RD- T -2 - 07/30/97 ---.6f e ;- 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" l-i 9597' I f¡_~:: ~-i 9600' I ~ DATE 11/28/82 05/19/87 11/20/00 10/25/01 12/05/02 REV BY SIS-JH RNlTP PGS COMMENTS ORIGINAL COMPLETION RWO (CHANGEOUTTBG) CONVERTED TO CANV AS CORRECTIONS PROPOSED SIDETRACK DATE REV BY 1 2200' l-i ~ ST MD TVD 6 5 4 3 2 1 9050 ) I J Z ) II .. 14 1/2" Solid (uncemented) COMMENTS ):AFETY NOTES: 133/8" x 95/8" annulus I bottom 400' cemented. Arctic-Pack above to surface. 4-1/2" X Nipple, ID = 3.813" GAS LIFT MANDRELS DEV ìYÆ VLV LATCH OTIS RA OTIS RA OTIS RA OTIS RA OTIS RA OTIS RD PORT DATE 9100' 1-i4 1/2" X Nipple 3.813 ID I 9140' l-i 4 1/2" x 7" Baker S-3 Pkr 9160' 1-i4 1/2" X Nipple 3.813 ID 9180' I-iTop 4 1/2" solid x slotted 9330' l-i 7" 26# L-80 rrod-BTC -=====) -i _-9,550' I 41/2" 12.6# L-80 Slotted l-i 11,081' PRUDHOE BA Y UNrr WELL: 13-13A ÆRMrr No: 82-178 API No: 50-029-20852-01 SEC 14, TION, R14E 2443.26 FEL 396.1 FNL BP Exploration (Alas ka) SURVEY PROGRAM Plan: 13·13A y,-pOI (13-13/Plan 13-13A) Dep<h I'm Dep<b To Survey,plan Tool Created By: Ken Allen Date: 10/111 8625.00 11081.15 PIanœd: 13·I3A wpOl V3 MWD Checked: Date: Reviewed: Date: WElL DETAILS Narœ +Ni..g +F1-W NOl1hing Easting Latitude Longituœ Slot 13-13 ·1757.08 296.97 593089633 686168.57 70"12'58.163N 148"29'53.681W 13 TARGET DETAILS Narœ 1VD +Ni·S +Ei·W Northing Easting Shape 13-I3A Tl 8964.52 ·1586.93 ·141822 5929275.00 684790.00 PoinI 13-13A Poly 8964.52 ·148350 ·1555.72 5929375.00 684650.00 Polygon 13-I3A I'M 1 8984.52 -1398A9 -2609.01 5929434.00 683595.00 1'01)'800 13·I3A T4 8994.52 -2077.15 ·199.86 5928815.00 686020.00 Point 13-I3A FItfi2 9004.52 -1915.92 1172.3 5928984.00 686333.00 POI)'I!OD SECTION DETAILS Sec MD Inc Azi TVD +N/-S +FJ-W DLeg TFace vSec Targe 1 8625.00 21.05 238.39 8306.86 -1104.41 -1099.81 0.00 0.00 1204.67 2 8645.00 23.32 236.32 8325.38 -1108.49 -1106.17 12.00 -20.00 1209.34 3 9230.63 49.12 211.31 8796.19 -1367.61 -1322.40 5.00 -40.81 1487.98 4 9350.83 49.12 211.31 8874.84 -1445.26 -1369.63 0.00 0.00 1569.80 5 9527.17 70.00 189.00 8964.52 -1586.93 -1418.22 16.00 -48.98 1715.47 13-13A T1 6 9720.80 92.00 166.76 8995.00 -1775.59 -1410.09 16.00 312.71 1902.48 '-' 7 10276.33 89.44 89.01 8986.69 -2091.01 -1004.53 14.00 -91.00 2177.61 8 11081.15 89.44 89.01 8994.52 -2077.15 -199.86 0.00 0.00 2086.75 13-13A T4 0 Ö REFERENCE INFORMA nON ElPA"""", Co-on1íæ'" fN;E) R"rcrenœ: Well Centre: 13-13, T"" Nonb VertìcaJ (JVD) Relerenœ: 21: 08 1211/199810-.5174.52 . - CaL:ublion Method; Minimum Ct.a\õUuo: Se<lioo (VS) Ref_nœ: Slot - 13 (O.OON.O.ooE) Fro>r Sy"",": ISCWSA Me¿suredDepthRef<renœ: 21: 08 I2fUI998 10-.51 74.5 ...:... þ Sun MethoJ: 1m' Cylird." Nørth Calculation Method: Minimum eun'ature Error Surfoce: Elliplica1' C~ Wamin\ MelMd: Rub 11.....1 CASING DETAILS All TVD depths are No. TVD MD Name Size ssTVD plus 74.52'for RKBE. 8861.52 9330.47 7" 7.000 8994.52 11081.14 4 1/2" 4.500 800er- FORMATION TOP DETAILS No. TVDPath MDPath Formation I 8484.52 8823.55 TJC 2 8773.52 9 I 96.54 Till 3 8777.52 9202.48 TJA 4 8861.52 9330.47 TSGR 5 8884.52 9365.86 TSHU 6 8966.52 9533. I I TSADrrZ4B 820er- Start Dir 12/100' : 8625' MD, 8306.86'TVD ,,/ Start Dir 5/100': 8645' MD, 8325.38'TVD 8400 ~/ "'/, ..C> '.ð ~~"i ~ V~ #" /000 8986.69' TVD I 2400 10276.33' MD, End Dir 2200 9720.8' MD, 8995'TVD /" -&> 13-13A wp('1 /1\ / ~~12· TVJ / SOrt DIT WIOO' 1800 Vertical Section at 185.50° [200ft/in] 108U5' M), 899452' 2000 9230.63' MD, 8796.19' TVD 161100': 9350.83' MD, 8874.84'TVD 00 00 ~ T!N1IDepn I LÞ I / T3AOOYJ4D 1600 3 3 \ 1400 200 " ~ o o [:!. oJ:: 3- 8600 o .. u ',:: ... ::- 2 ¡.... 8800 9000 9200 Plan: 13-13A wpOI (13-13/Plan 13-13A) Created By: Ken Allen Date: 10111/2002 Checked: Date: Reviewed: Date: SURVEY PROGRAM Oep<h fm Oep<h To SUlyeyiPlan Tool 8625.00 11081.15 PIanoed: 13-I3A "J'01 '0'3 MWD REFERENCE INfORMATION Co-ooiim.. (N;E Refë"'''''': Wëll Centre: 13·13, T"" Nonh Wnical (TVD) Rel<rence: 21: 08 12Ilil998 10:517452 Sëctioo (VS) Rëf<reo::e: Slot - 13 (O.ooN,O,OOE) M<asun>J Oep<h Refërenœ: 21: 08 121111998 10:51 7452 CaJcu1atioo MëIhod: MiniImDn C'ur>mure or Arwx(1 Minimum Curn""" ISCWSA T nv CyliOO:r Nonh Elliplial . Casing Rul.:s ßasëd bp o --5tart Ðir~.,625' MD, 830G.8G"='VD Start Dir 5/100' : 8645' MD, &325.3f'TVD --- - .. __n. r 3500 1200 ---~ / 13-13 (13-1') / Dir : 9230.63' .\10, 8"96.19' TVD I \;_11 Å Fltltl 1400 I- Star 61100' : ~350.8~' MD, S874.84' rvl1 ~ "2 ~ ~ 3-IM TI + 1600 ~ 1:: 0 ~ ~ 0 en 1800 .- -2000 WElL DET AIU> Narœ +N'-S 7Ei-W Northing Easting Latitude longitude Slot 13-13 -1757.08 296.97 593089633 68616857 70"12'58.163N 148'29'53,68IW 13 TARGET DETAIlS Narœ TVD +W-S +EI-W Nonhing Easting Shape 13·13A II 896452 -1586,93 -141822 5929275.00 684790,00 Point 13-13A Poly 8964,52 -148350 -1555.n 5929375,00 684650.00 Polygon 13-I3A FIl!II 898452 -138330 -1238.13 5929483,00 684965,00 Polygoo 13-I3A T4 8994.52 -2077.15 -199.86 5928815.00 686020.00 Point 13·I3A FIt#2 9004.52 ·1915.92 117.23 5928984,00 686333,00 Polygon SECTION DETAILS See MD Ine Azi TVD +N/-S +FJ-W DLeg TFace VSec Targel I 8625.00 21.05 238.39 8306.86 -1104.41 -1099.81 0.00 0.00 1204.67 2 8645.00 23.32 236.32 8325.38 -1108.49 -1106.17 12.00 -20.00 1209.34 3 9230.63 49.12 211.31 8796.19 -1367.61 -1322.40 5.00 -40.81 1487.98 4 9350.83 49.12 211.31 8874.84 -1445.26 -1369.63 0.00 0.00 1569.80 5 9527.17 70.00 189.00 8964.52 -1586.93 -1418.22 16.00 -48.98 1715.47 13-13A Tl 6 9720.80 92.00 166.76 8995.00 -1775.59 -1410.09 16.00 312.71 1902.48 ---- 7 10276.33 89.44 89.01 8986.69 -2091.01 -1004.53 14.00 -91.00 2177.61 8 11081.l5 89.44 89.01 8994.52 -2077.15 -199.86 0.00 0.00 2086.75 13-13A T4 Cakul.1lK'If1 M~...I' f..rmrS)'Slcm: Suo Mëlb:x!' ElTOC Surb",,: WamiDJ! Mctml: 000 CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath Fonnation 1 8861.52 9330.47 7" 7.000 I 8484.52 8823.55 TJC 2 8994.52 1108Ll4 41/2" 4.500 2 8773.52 9196.54 TJB 3 8777.52 9202.48 TJA 4 8861.52 9330.47 TSGR 5 8884.52 9365.86 TSHU 6 8966.52 9533.11 TSADffZ4B All TVD depths are ssTVD plus 74. 52' for RKBE. --- ---------- ---- ----- 13-13A Flt#2 -~ -- 1986.69' T\'D -4 13-13A ....1') - 7"\ 4 - /2" --------- t3-13A T4 Total Dep'h: I l(I8 l.l 5' MD, 8':194.52 TV - ----- I -800 -600 -400 -200 0 200 West(-)Æast(+) [200ft/in] I -1000 I 1200 I 1400 -2200- 600 ) BP KW A Planning Report MAP ') ç()~p*~y: ,Field: '. , Site: Wen: Wellpath: :'~P'Ar))q8q "',"""" , PrUdh~e,:BaYi .' PB'D~13 13-13 Plan 13-13A' ,····,".;',p~~::',,(1'¡~t~::~~Zq~2;,;:'i':¡-ti~~: :'1:~¡i~~:,1S "··r.g~: ' "1 ' '. ",,"è~~'.d:inate~E):,Re(~~rife:: '··Wølt;13-13;,¡¡:ijJØNorth···" ........",.....' , ,.Vt:l'ti~al(TVD) :Q.efe..el1c~: ..' 21.: 0812/1'/1,998 1 O:g1 ,74.5 ,.' SectiOD(VS)R~f~re~~:i" Weir (O.OON,O.OOE, 185.50Azi) . S"rVeyCal~ula~onl~:1#bod: Minirnum,Curvature," Db: , Oracle I" :,':: ~ ': ::~ : :':::', :.:':"'.;';' ", I' :~: , :,:;: ":! :;:; , ' ,:.. ::,' ¡ ""'!::.','" I Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 13 TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5932645.45 ft 685828.44 ft Latitude: Longitude: North Reference: Grid Convergence: 13-13 13-13 Well Position: Well: Slot Name: +N/-S -1757.08 ft Northing: +E/-W 296.97 ft Easting: Position Uncertainty: 0.00 ft 5930896.33 ft 686168.57 ft Latitude: Longitude: Wellpath: Plan 13-13A Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 21 : 0812/1/1998 10:51 10/7/2002 57540 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 74.52 ft Plan: 13-13A wp01 Date Composed: Version: Tied-to: Principal: Yes Casing Points Alaska, Zone 4 Well Centre BGGM2002 70 13 15.444 N 148 30 2.303 W True 1.41 deg 13 70 12 58.163 N 148 29 53.681 W 13-13 8625.00 ft Mean Sea Level 26.14 deg 80.79 deg Direction deg 185.50 1017/2002 3 From: Definitive Path 9330.47 8861.52 7.000 8.500 7" 11081.14 8994.52 4.500 6.125 41/2" Formations MD TVD Lithology Dip Angle Dip Direction ft ft deg deg 0.00 THRZ 0.00 0.00 0.00 BHRZ 0.00 0.00 0.00 TJD 0.00 0.00 8823.55 8484.52 TJC 0.00 0.00 9196.54 8773.52 TJB 0.00 0.00 9202.48 8777.52 TJA 0.00 0.00 9330.47 8861.52 TSGR 0.00 0.00 9365.86 8884.52 TSHU 0.00 0.00 9533,11 8966.52 TSADrrZ4B 0.00 0.00 Targets Map Map <- Latitude --> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See: Deg Min See: Dip. Dir. ft ft ft ft ft 13-13A T1 8964.52 -1586.93 -1418.22 5929275.00 684790.00 70 12 42.554 N 148 30 34.849 W 13-13A Poly 8964.52 -1483.50 -1555.72 5929375.00 684650.00 70 12 43.571 N 148 30 38.841 W -Polygon 1 8964.52 -1483.50 -1555.72 5929375.00 684650.00 70 12 43.571 N 148 30 38.841 W -Polygon 2 8964.52 -1490.90 -1255.79 5929375.00 684950.00 70 12 43.499 N 148 30 30.135 W -Polygon 3 8964.52 -1742.62 -986.90 5929130.00 685225.00 70 12 41.024 N 148 30 22.328 W -Polygon 4 8964.52 -1944.16 -116.56 5928950.00 686099.99 70 12 39.042 N 148 29 57.064 W ç~'µP~py: Ø~~(T\~9() Field: .. p~!JdQoeB$Y Site: 'PB.DS13 Well: 13-13' Wellpatb: Plan13.:.13A Targets I I" ',,·..,..,',°'1 ':'" "',',.,',;,' ",':'::'-,":,,":':',:'.' Nàmt . . 'Dêsc...prl~IÌ Dip. . Qir. ···.TVO' ft 8964.52 8964.52 8984.52 8984.52 8984.52 8994.52 -Polygon 5 -Polygon 6 13-13A Flt#1 -Polygon 1 -Polygon 2 13-13A T4 13-13A FIt#2 -Polygon 1 -Polygon 2 9004.52 9004.52 9004.52 Plan Section Information ) BP KW A Planning Report MAP ') (,l)~~;'i....~.~(11'~ª~g~'i",<,/,:'11im~;·· '1():24:j 5,...· ..... ~.~e:' .., ,······'ì ... .. .... Çt)~r¡d~..ª~~)It~te~e.n~:· \lVell:'1~~1~:Trl,jè~øÌ'tl'1i ·..\i' . VeHicaJ"Ø'VD~R__ereD.ce:.· 21··;0812/1/1998.10:51·14;5' Seçtlon (VS)Rere~nce:· . . .' Well (O;OON.O'~OOE, 185.50Azi) Survey Calc~lation~etbQd': MinimiJmCurva~ure 1 Db: Oracle I :: : ¡,: : :' I ,;: ~ ·1.', ;":"";):':':',;:;! I" ';::.¡,:::i:::',:,\ ',,'I"" ·,,fN/.;g , ft -2219.09 -2051.68 +'£I..W ft -123.34 -1029.54 ··:'~=t~~~:: ····.'.·.·i~r.t~...·.·.::.·······, ....~~/~:~!~:~f?".......;...~~...,.~~~~~~:~.......~ t(·ft. 5928675.00 686100.00 5928820.00 685190.00 70 12 36.338 N 148 29 57.261 W 70 12 37.984 N 148 30 23.565 W 70 12 44.557 N 148 30 29.623 W 70 12 44.404 N 148 31 9.418 W 70 12 44.557 N 148 30 29.623 W 70 12 37.734 N 148 29 59.482 W 70 12 39.320 N 148 29 50.278 W 70 12 39.320 N 148 29 50.278 W 70 12 29.093 N 148 29 47.336 W MD ,Jncl ...... Ázifu .... 1::\1'0' +Nl~S ... ;4-El;,.W ··.··..··ôtS.:"..··..·...,B~.'~' ·.··..·..·11grn. .....,....... .......... "TFQ: ... 'T~l'g~t ..... 1,1'1 ft deg deg ft I· .,'··..,·ft'.'..' ft .. deg/1 000 deg/1OQftdeglWOft "deg I . 1 ' ,. ':. I '11'1 8625.00 21.05 238.39 8306.86 -1104.41 -1099.81 0.00 0.00 0.00 0.00 8645.00 23.32 236.32 8325.38 -1108.49 -1106.17 12.00 11.35 -10.37 -20.00 9230.63 49.12 211.31 8796.19 -1367.61 -1322.40 5.00 4.41 -4.27 -40.81 9350.83 49.12 211.31 8874.84 -1445.26 -1369.63 0.00 0.00 0.00 0.00 9527,17 70.00 189.00 8964.52 -1586.93 -1418.22 16.00 11.84 -12.65 -48.98 13-13A T1 9720.80 92.00 166.76 8995.00 -1775.59 -1410.09 16.00 11.36 -11.49 312.71 10276.33 89.44 89.01 8986.69 -2091.01 -1004.53 14.00 -0.46 -13.99 -91.00 11081.15 89.44 89.01 8994.52 -2077.15 -199.86 0.00 0.00 0.00 0.00 13-13A T4 Survey MO Incl ····Azhn TV]) SysTVO ··M~pN' , Map¡¡: VS::,' J)~S........ Tool/Com-råe~t ft, ø~g ··deg ft . ft>. ft ft· lift: d$g110Oft . 8625.00 21.05 238.39 8306.86 8232.34 5929765.20 685096.39 1204.67 0.00 Start Dir 12/100' : 8625' MD, 8645.00 23.32 236.32 8325.38 8250.86 5929760.97 685090.14 1209.34 12.00 Start Dir 5/100' : 8645' MD, 8 8700.00 25.46 232.13 8375.47 8300.95 5929747.22 685072.08 1224.33 5.00 MWD 8800.00 29.60 226.04 8464.14 8389.62 5929716.02 685038.07 1257.88 5.00 MWD 8823.55 30.61 224.83 8484.52 8410.00 5929707.52 685029.87 1266.94 5.00 TJC 8900.00 33.95 221.35 8549.15 8474.63 5929677.01 685002.78 1299.31 5.00 MWD 9000.00 38.44 217.62 8629.84 8555.32 5929630.49 684966.47 1348.30 5.00 MWD 9100.00 43.03 214.58 8705.60 8631.08 5929576.81 684929.42 1404.48 5.00 MWD 9196.54 47.53 212.10 8773.52 8699.00 5929518.59 684893.21 1465.13 5.00 TJB 9200.00 47.69 212.02 8775.85 8701.33 5929516.39 684891.91 1467.42 5.00 MWD 9202.48 47.80 211.96 8777.52 8703.00 5929514.81 684890.98 1469.06 5.00 TJA 9230.63 49.12 211.31 8796.19 8721.67 5929496.60 684880.37 1487.98 5,00 End Dir : 9230.63' MD, 8796.1 9300.00 49.12 211.31 8841.58 8767.06 5929451.13 684854.23 1535.20 0.00 MWD 9330.47 49.12 211.31 8861.52 8787.00 5929431.16 684842.75 1555.94 0.00 7" 9350.83 49.12 211.31 8874.84 8800.32 5929417.82 684835.08 1569.80 0.00 Start Dir 16/100' : 9350.83' M 9365.86 50.73 208.96 8884.52 8810.00 5929407.73 684829.55 1580.25 16.00 TSHU 9375.00 51.72 207.59 8890.25 8815.73 5929401.37 684826.33 1586.82 16.00 MWD 9400.00 54.53 204.02 8905.25 8830.73 5929383.16 684818.09 1605.57 16.00 MWD 9425.00 57.43 200.70 8919.24 8844.72 5929363.82 684810.69 1625.40 16.00 MWD 9450.00 60.41 197.59 8932.15 8857.63 5929343.43 684804.18 1646.20 16.00 MWD 9475.00 63.46 194.65 8943.91 8869.39 5929322.09 684798.59 1667.88 16.00 MWD 9500.00 66.57 191.87 8954.47 8879.95 5929299.92 684793.95 1690.33 16.00 MWD 9527.17 70.00 189.00 8964.52 8890.00 5929275.00 684790.00 1715.47 16.00 13-13A Poly 9533.11 70.65 188.26 8966.52 8892.00 5929269.45 684789.30 1721.05 16.00 TSADITZ4B 9550.00 72.50 186.19 8971.86 8897.34 5929253.51 684787.68 1737.07 16.00 MWD 9575.00 75.28 183.19 8978.80 8904.28 5929229.54 684786.31 1761.08 16.00 MWD 9599.84 78.08 180.29 8984.52 8910.00 5929205.38 684786.17 1785.19 16.00 13-13A FIt#1 -1383.30 -1238.13 5929483.00 684965.00 -1398.50 -2609.01 5929434.00 683595.00 -1383.30 -1238.14 5929483.00 684964.99 -2077.15 -199.86 5928815.00 686020.00 -1915.92 117.23 5928984.00 686333.00 -1915.92 117.23 5928984.00 686333.00 -2955.80 218.62 5927947.00 686460.00 ) ) BP KW A Planning Report MAP ···Company~ BI? AmDco ;i5ât~::I;·.1;(j/j:1I2ô621:·..·........·...· .' ··..1;ì;..~é· 1b:24H~II.' Pag~: .. 3 Fi~ld : PrudooßBay CQ.o..dinate(~E)·Ref~renc:e:: Welt; 13';13, True,North· Site: PBDS13 Vertiçal' (1'VD) , ~êferencé, 21·:0812/1/199810:p174.5 Well: 13~13 I SeÇfloD (VS) Reference:. . Well (OJ)ON,O.OOE.185;50Ázi) Wellpath: Plan 1.3-13Ä Survey Calculation . Method: Minimum Curvature Db: OraCle Survey MD ff 9600.00 78.10 180.28 8984.55 8910.03 5929205.22 684786.18 1785.35 16.00 MWD 9625.00 80.95 177.42 8989.10 8914.58 5929180.67 684787.28 1809.76 16.00 MWD 9650.00 83.82 174.61 8992.41 8917.89 5929156.00 684789.61 1834.20 16.00 MWD 9675.00 86.70 171.82 8994.48 8919.96 5929131.35 684793.17 1858.54 16.00 MWD 9700.00 89.59 169.06 8995.29 8920.77 5929106.83 684797.92 1882.66 16.00 MWD 9720.80 92.00 166.76 8995.00 8920.48 5929086.61 684802.77 1902.48 16.00 Start Dir 14/100' : 9720.8' MD 9725.00 91.99 166.17 8994.85 8920.33 5929082.55 684803.86 1906.45 14.00 MWD 9750.00 91.92 162.67 8994.00 8919.48 5929058.66 684811.16 1929.76 14.00 MWD 9775.00 91.85 159.17 8993.18 8918.66 5929035.26 684819.90 1952.48 14.00 MWD 9800.00 91.77 155.67 8992.39 8917.87 5929012.44 684830.06 1974.53 14.00 MWD 9825.00 91.68 152.17 8991.63 8917.11 5928990.28 684841.60 1995.81 14.00 MWD 9850.00 91.59 148.67 8990.92 8916.40 5928968.86 684854.46 2016.26 14.00 MWD 9875.00 91.49 145.17 8990.25 8915.73 5928948.27 684868.62 2035.79 14.00 MWD 9900.00 91.39 141.67 8989.62 8915.10 5928928.58 684884.00 2054.34 14.00 MWD 9925.00 91.28 138.17 8989.04 8914.52 5928909.86 684900.55 2071.83 14.00 MWD 9950.00 91.16 134.67 8988.51 8913.99 5928892.19 684918.22 2088.20 14.00 MWD 9975.00 91.04 131.17 8988.03 8913.51 5928875.63 684936.94 2103.39 14.00 MWD 10000.00 90.92 127.67 8987.60 8913.08 5928860.24 684956.63 2117.34 14.00 MWD 10025.00 90.79 124.17 8987.23 8912.71 5928846.08 684977.22 2129.99 14.00 MWD 10050.00 90.66 120.68 8986.91 8912.39 5928833.21 684998.64 2141.31 14.00 MWD 10075.00 90.53 117.18 8986.65 8912.13 5928821.66 685020.81 2151.25 14.00 MWD 10100.00 90.40 113.68 8986.44 8911.92 5928811.49 685043.64 2159.77 14.00 MWD 10125.00 90.26 110.18 8986.30 8911.78 5928802.73 685067.04 2166.85 14.00 MWD 10150.00 90.13 106.69 8986.21 8911.69 5928795.41 685090.94 2172.44 14.00 MWD 10175.00 89.99 103.19 8986.19 8911.67 5928789.56 685115.25 2176.54 14.00 MWD 10200.00 89.85 99.69 8986.22 8911.70 5928785.21 685139.86 2179.13 14.00 MWD 10225.00 89.72 96.19 8986.31 8911.79 5928782.37 685164.69 2180.20 14.00 MWD 10250.00 89.58 92.70 8986.47 8911.95 5928781.05 685189.65 2179.74 14.00 MWD 10276.33 89.44 89.01 8986.69 8912.17 5928781.30 685215.97 2177.61 14.00 End Dir : 10276.33' MD, 8986. 10300.00 89.44 89.01 8986.92 8912.40 5928782.29 685239.62 2174.94 0.00 MWD 10400.00 89.44 89.01 8987.89 8913.37 5928786.48 685339.52 2163.65 0.00 MWD 10500.00 89.44 89.01 8988.87 8914.35 5928790.67 685439.42 2152.36 0.00 MWD 10600.00 89.44 89.01 8989.84 8915.32 5928794.85 685539.32 2141.07 0.00 MWD 10700.00 89.44 89.01 8990.81 8916.29 5928799.04 685639.22 2129.78 0.00 MWD 10800.00 89.44 89.01 8991.79 8917.27 5928803.23 685739.13 2118.49 0.00 MWD 10900.00 89.44 89.01 8992.76 8918.24 5928807.42 685839.03 2107.20 0.00 MWD 11000.00 89.44 89.01 8993.73 8919.21 5928811.60 685938.93 2095.91 0.00 MWD 11081.14 89.44 89.01 8994.52 8920.00 5928815.00 686019.99 2086.75 0.00 13-13A T4 11 081.13 89.44 89.01 8994.52 8920.00 5928815.00 686019.98 2086.75 0.00 Total Depth: 11081.15' MD, 89 11081.15 89.44 89.01 8994.52 8920.00 5928815.00 686020.00 2086.75 0.00 MWD - ~ '"1 1110 5 500 Sill ~:o... ~ 20 :'8 ~ 51: 0 ~ 2 78 ~ bill N°lVA\.ID - :'::"':~'''':V:~ 120 DAYS" - >;:::'-\;;¡;¡='''''. ...,,;;- . .~i::~F~~~2i¡~~¡~:;!;:~ri ALASKAÇ>IL & GAS CONSERVATIONCQfv1MIS$ION" 333 W 7T8AVENUE SUITE 100 ANCHORAGE, AK 99501 TO THE ORDER OF: PAY: BP EXPLORATION, (ALASKA) I NcG. PRUDHOE BAY UNIT "' PO BOX 196612 ANCHORAGI:, AK99519-6612 TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 2 ~ i-:~-i ~ S~) ~ ~.J r. --, '\ J ¡1 )3 . ( 3/J- H PERMIT TO DRILL FEE NET INVOICE / CREDIT MEMO 12/19/2002 INV# CK121702N DATE VENDOR DISCOUNT GROSS DESCRIPTION P055005 12/19/2002 P0550"05 DATE CHECK NO. WELL PERMIT CHECKLIST COMPANY 8fJ X WELL NAME fJRrj / Ç? - / jA PROGRAM: Exp _ Dev x.. Redrll--2L Re-Enter _ Serv _ Wellbore seg_ FIELD & POOL ~~o/...) ñ INIT CLASS OfPa'/ / -CJ// GEOL AREA ~c¡ n UNIT# 1/ h 5 c> ON/OFF SHORE.c2LY ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . R N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well nam~ and number. . . . . . . . . . . . . . . . . Y N 4. W ell 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 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 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.. . . . . (J) N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ Ý þr" /lJ. ,4, (Service Well Only) 14. All wells wlin % mile area of review identified. . . . . . . . .. YN ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . & N 16. Surface casing protects all known USDWs. . . . . . . . . . éj) N 17. CMT vol adequate to circulate on conductor & surf csg. . . . ..y.--r.:r N/It- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . -Y--N- 19. CMT will cover all known productive horizons. . . . . . . . . . ~' N 20. Casing designs adequate for C~ T, B & permafrost. . . . . . . ,N ¡J~ (!J _ 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N, -r-S 1-13 S ' 22. If a re-drill, has a 10-403 for abandonment been approved. . .. ~JN ~ /71 0 ~ 23. Adequate wellbore separation proposed.. . . . . . . . . . . . (J/ N 24. If diverter required, does it meet regulations. . . . . . . . . . Y N "'IA;- . 25. Drilling fluid program schematic & equip list adequate. . . . . &-'. N ýþ¡jvf in jÚ I'. Z. f? f7 . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . è!! N, . APPR DATE 27. BOPE press rating approp.riate; test to ,$' () éJ psig. ! N Me.. ¡) ~.L/- ~ P (. i . 'l 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N \+JCÍ!\- ~ {îi . 0 ~ 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . ... N . (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N- r-l/Æ-- GEOLOGY 32. Permit can be issued wlo hydrogen sulfide measures. . . . . Y ;N') APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . lw /1 ~.'~ ~ ~ )')/J J~, :1 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y ¡tJ- ,1, /TI f _ J/)//t..A...J 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . Y. N (Exploratory Only) 36. Contact namelphone for weekly progress reports. ...... N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP~ APPR DATE ð!L... 31Í1/6 3 Ulc ENGINEER COMMISSIONER: J)" Xi SP /(, 0;7 . RR ';>b/~ Dsð2,) i) 10 ~ TM JH JR Rev: 2/25/03 SFD_ WA ./ MW \welLpermiC checklist l , (' \ Comments/lnstructions: Rev: 07/10/02 Ojody\templates } ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME flðu 13-/J,LJ CHECK WHAT APPLIES PTD# 2.0. ~ ... O.':l t:. ADD-ONS (OPTIONS) MlJL TI LATERAL (If API num ber last two (2) digits are between 60-69) "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. HOLE 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). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) 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. ,) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim,plify 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. ') ') 803-030 \'<1<1~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 15 13:53:48 2003 Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/05/1,1) Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNONN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................03/05/15 Origin. .. .. . . . ., . . . . . .. .. STS Tape Name................UNKNOWN Continuation NumbeL·..... .01 Previous Tape Name.......UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Se.rvices Physical Eor Comment Reco.rd TAPE HEADER Prudhoe Bay MWD/MAD LOGS if WELL NAME: API NUMBER: OPEH.ATOR: LOGGING COMPANY: TAPE CREATION DATE: # ,JOB DATA OS 13-13A 500292085201 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 15-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002409983 ...T. SACK J. RALL / L. MWD RUN 2 MW0002409983 ...T. SACK J. RALL / R. MWD RUN 3 MW0002409983 ...T. SACK J. RALL / D. # SURFACE LOCATION SECTION: TOWNSHI P: RANGE: fNL: FSL: FEL: fWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRI C¡{ fLOOR: GROUND LEVEL: 1-1 ION 14E 855 1076 77.20 48.70 il WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRnrG PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) e.~üü 9.62~ 86l~.U 6.125 7.000 9344.0 Ii REt-'LI\RKS : 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS T\RS BIT DSFTIIS. ~ .....;.', . _'....î...._ -;;. " ~c'. ~ ;:..i1' ..~ :".-:.;...,,- ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD. ï..l~ ~..: I, ~ i !'.! ( K~'Df~'\ ~ ) ") 3. THIS WELL v-IAS DRILLED OFF OF A WHIPSTOCK IN THE 13-13 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 8615'MD/8298'TVD: THE BOTTOM WAS AT 8631'MD/8313'TVD. 1. MWD RUN 1 WAS DIRECTIONI\L ONLY TO SET THE WHI PSTOCK - SROP DATA ARE PRESENTED. 5. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER 'rUBE DETECTORS; AND PRESSURE WHILE DRILLING (PWD). UPHOLE (BEHIND CASnIC) SGRC DATA WERE ACÇ¿UIRED WI-IILE RIH FOR RUN 2. THESE DATA ARE MERGED WITH RUN 2 MWD DATA. 6. MWD RUN 3 COMPRISED DIRECTIONAL; DGR: ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4): AND AT-BIT-INCLINATION (ABI). '}. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHI FTED UPWARD 3.5 FEET, PER E-MI\IL Ff{OM D. SCHNORf-<", SP EXPLOHI\'l'ION (ALASKA), INC., DATED 5/14/03. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 3 REPRESENT WELL 13-13A WITH API#: 50-029-20852-01. THIS WELL REACHED A TOTAL DEPTH (TO) OF 11263'MD/9018'TVD. SROP - SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXI? SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SF.SP = SMOOTHED PHASE SHI F"\'-DF.RTVE,[) REST s'r TVT'\,Y (SHALLOW SPACING) . SEMI? = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM Sl:'ACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........1 .0.0 Date of Gcncration.......03/05/15 Maximum Physical Record..65535 F .il e l' ype. . . . . . . . . . . . . . . . LO Previous File Nùme.......STSLIB.OOO Comment Record FILE HEADER FILE NUI'1BER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 ff FILE SUMMARY FEU TOOL CODE ROP FET RPD RPM RPS RPX START DEPTH ST P DEPTH 8441.5 11 96. :;. 8616.0 11 60.0 932ì . 0 11 03.2') 932'.0 II 03.5 9327.0 11 03.5 9327 . 0 11 û3.5 9327.0 11 03.5 GR s ) ) BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (ME:ASLJRED DEPTH) --------- EQUIVALENT LJNSHIFTED DEPTH --------- BASELINE DEPTH 8441.5 11260. () $ GR 8445.0 11263.5 # HERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO MERGE TOP 1 8619.5 2 8445.0 3 9307.0 MERGE BASE 8647.0 9344.0 11263.5 # REHARKS: l'-iERC:ìED MAIN PASS. $ ff Data Format Specification Record Data Record Type..................O Data Specification Block Typc.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing............ .... .....60 .1IN Max fL-anæs per:' r:ecQL-d............ .Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 ~ GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPH MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET M'"viID HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8441.5 11260 9850.75 5638 8441.5 11260 ROP MWD FT/H 0.03 528.65 88.0454 5289 8616 11260 GR MWD API 10.1 534.21 72.6963 5511 8441..5 11196.5 RPX MWD OHMM 0.54 2000 16.3782 3754 9327 11203.5 RPS MWD OI-lMM 0.12 2000 18.0682 3'/S4 932'/ 11203.S RPM MWD OHMM 0.11 1636.22 18.439 3754 9327 11203.5 RPD MWD OI-lMM 0.3 2000 34.8351 3754 9327 11203.5 FET MWD HOUR 0.3'/ 44.23 1. '114 96 3'154 9327 11203.5 First Reading For Entire File..........B441.S Ld.::>l Readlrlg For: Enlir'e File...........11260 File Trailer Service n~me.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O D~te of Gcneration.......03/05/15 Maximum Physical Record..65535 File Type................ LO Next File Name..... .... ..8T8L18.002 Physical SOF Fjle Header Service name.............STSLIB.002 Servic~ Sub Level Name... Version l'-iuIllber.......... .1.Cì.Ci ) Date of Generation.......03/05/15 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: Rl\W MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FI LE SUMMARY VENDOR TOOL CODE R.0P $ 2 ) header data tor each bit run in separate tiles. 1 .5000 START DEPTI1 8619.5 STOP DEPTH 8647.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE '1'OOL TYPE DGR DUAL GÞMMA RÞ~ $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD 'rYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OI1MM) AT TEMPERI\TUn.E (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRÞ.TE Þ.T MT: .MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): ¡';Wk Fkt:QUr:NCY (HZ): REMARKS: $ Data Format Specification Record Data Reeo rd Type.................. 0 Data Specification Block Type.....O Loggi~g Directi0~.................Ð'2~1~ C)pt.i~a1 10<] depth uni.ts...........reet Data Reference Point..............Undef ned Frame Spacing.....................60 .1 N Max frames per record.............Undef ned Absent value..................... .-999 Depth Uni t3. . . . . . . . . . . . . . . . . . . . . . . 27-APR-03 Insite 66.37 Memory 8647.0 8615.0 864'/.0 .0 .0 TOOL 1\fUM8ER 081497 8.500 8615.0 LSND 11. Ob 17.0 8.5 700 3.4 .000 .000 .000 .000 .0 .1 , 2. (I .0 .0 ) ) Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset ChatJtJel DEPT FT 4 1 68 0 1 ROP MWDOIO FT/H 4 1 68 4 :2 Firs·\. Last Name Servi.ce Unit Min ~1ax Mean Nsam Reading Reading DEPT FT 8619.5 8647 8633.25 56 8619.5 8647 ROP MWD010 FT/H 0.03 33.29 7.41446 56 8619.5 8647 First Reading For Entire File..........8619.5 Last Reading For Entire File...........8647 File Trailer Se.cvice name............. STSLIB. 002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/05/15 Maximum Physical Record..65535 Fi 1. e Type................ LO Next File Náme...........STSLIB.003 Physical EOF File Header Service name.............STSLI8.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/05/15 Maximum Physical Record..65535 F i leT ype. . . . . . . . . . . . . . . . LO Previous File Name.......STSLIB.002 ConunenL Record FI LE HEJ\DER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP 3 header data for each bit run in separate files. 2 .5000 START DEPTH 844S.0 8647.5 STOP DEPTH 9306.S 9344.0 $ # LOG HEADER DATA DATC LOGGCD: SOFTWARE SURFACE SOFTWARE VERSION: DOHNHOLE SOFTír-JARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG !VíINH¡Uì'! ANGLE: M.lI.XIMUM .lI.NGLE: 29-APR-03 Insite 66.3' Memory 9344.0 8647.0 9344.0 21. ::: 49. Cí TOOL STRING (TOP TO BOTTOH) VENDOR TOOL CODE TOOL TYPE DGR DUAL G.AJv!.MA RAY TOOL NUMBER 081497 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 2..500 ') ) DRILLER I S CASING DEPTH (FT): 8615.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 11.10 65.0 9.5 1000 3.4 .000 .000 .000 .000 .0 160.0 .0 .0 # NEUTEON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): ~',WH FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record 'fype..................O Data Specification Block Type.....O Logging Direction.................Down Opt.ical log depth units... ...... ..Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Dat.um Speci ficat. ion Block sub-type... 0 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8445 9344 8894.5 1799 8445 9344 ROP MWD020 FT/H 0.31 182.91 60.6361 1391 8647.5 9314 GR MWD020 API ~2. 92 219.33 12') .154 1'124 844~ 9306.5 First Reading For Entire File..........8445 Ldst Reddinÿ Für Entire File...........9344 File TL'a.Ller Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Gcncration.......03/05/15 Maximum Physical Record. .65535 Fi 1 e Type................ LO Next File Name...........STSLIB.004 Fhycical EOr File Headó:;l Service name....... ..... .STSLIB.t)O·l Service SUb Level Name... Version Number.......... .1.0.0 Date of Gener~tiün.......03/05/15 Maximum Physical Record..6SS35 Comment Record E'ILE HEADER FILE NUMBER: RAW MWD Curves and log header data tor each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FI LE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ ) Fil e Type................ LO Previous File Name.......STSLIB.003 4 3 .5000 S'I'ART DEPTH 9307.0 9330.5 9330.5 9330.5 9330.5 9330.5 9344.5 STOP DEPTH 11200.0 11207.0 11207.0 11207.0 11207.0 11207.0 11263.5 # LOG HEADER DATA Dl\TE LOGGED: SOFTWARE SUREKCE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): BOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ElecL,['omag Re¡;3Ì:::>. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD V~SCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MA.":Z CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD Cl\KE 1\'1' MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOff (IN): EWR FREQUENCY (HZ): REM.I1.RKS : .;:, 1/ DaLa formaL SpecificaLio!l Record Di1ti1 Record Type..................O Data Specification Bl,=,ck Type.....O Logging Direction............. ....Down Optic~l log depth Lrnitc. ........ ..Feet ') 03-M1\Y-03 Insite 66.37 Memory 11263.0 934<1.0 11263.0 49.0 96.2 TOOL NUMBER 8'722 5 167218 6.130 9344.0 QUIKDRIL-N 8.60 41. 0 9.0 11000 6.2 .380 .210 .400 .150 75.0 144.U 75.0 75.0 ) ) Data Reference Point..............Undefincd Frame Spacing.....................60 .1IN Max frames pe,c r'ecor:d............. Undefined Absent value...................... -999 Depth Uni 1:8. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE 2T FT 4 1 68 0 1 ROP MWD030 FT / II 4 1 68 4 ¿ GR MWD030 API 4 1 68 8 3 RPX MHD030 OHMM 4 1 68 12 4 RPS MHD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 '7 E'ET MWD030 HOUR 4 1 68 28 8 First Last Name Se.r:vice Unit Min Max Mean Nsam Reading Reading DEPT FT 9307 11263.5 10285.3 3914 9307 11263.5 ROP MWD030 FT/H 0.19 528.65 99.1744 3839 9344.5 11263.5 GR MWD030 API 10.1 b34 .21 47.9047 378'1 9307 11200 RPX HHD030 OHMM 0.54 2000 16.3782 3754 9330.5 11207 RPS HWD030 OHMM 0.12 2000 18.0682 3754 9330.5 11207 RPM MWD030 OHMM 0.11 1636.22 18.439 3754 9330.5 11207 R!?D MWD030 OHMM 0.3 2000 34.8351 3754 9330.5 11207 E'ET MHD030 ¡¡OUR 0.37 44.23 1.71496 3754 9330.5 11207 First Reading For Entire File..........9307 Last Reading For Entire File...........11263.5 Fj.le Trailer Service name.............STSLIB.004 Service Sub Level Name... Ver'sion Numl)er:.......... .1.0.0 Date of Generation.......03/05/15 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.005 Phycical EOF Tdpe Tr'ailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . () 3 / () 5/15 OLigin.................. .STS Tðpe Name................ UNKNOWN Continuation Number......ü1 Next Tape Name........... UN!\.'NŒ\IN Commentc................ .STS LIS Hriting Librury. Scientific Technicul Servicc~ Reel Trdiler Service name.............LISTPE Date.....................03/05/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UN~JOh~ Continuation Number......Ol Nc;.:t Reel N.::¡me.......... .UNKNO\l'¡N Comments.................STS LIS Writing Library. Scientific Technical Services Physica.l EOF Physical EOF ) ) End Of LIS File