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208-178
Image Project Well History File Cover 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. ~~~ - ~ ~ ~ Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: o.„,,;,,~ IllllMtlllllllllll DI AL DATA Diskettes, No. ^ Other, No/Type: o ~,~~~~a,a uiuimoiuiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ^ Other:: ~s~ Project Proofing III IIIIIIIIIII VIII BY: Maria Date: ~ ~s~ Scanning Preparation ~_ x 30 = _~ + =TOTAL PAGES (Count does not include cover sheet) BY: Marra / Date: /~ //~ ~s~ Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: !~/~ f ~l0 ~S~ Stage 1 If NO in stage 1, page(s) discrepancie/s were found: YES NO BY: Maria Date: ~s~ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II I (III ReScanned III 111111 VIII V III BY: Maria Date: ~s/ Comments about this file: Quality Checked III 111111 III II'I III 10/6/2005 Well History File Cover Page.doc T RECEIVED , e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON SEP 2 4 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations [✓J Perforate 11 Other U Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other El Re -enter Suspended Well 0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development El Exploratory ❑ - 208 -178 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 22437 -60 -00 7. Property Designation (Lease Number): S jn 8. Well Name and Number: 1 j L ;..,1 ADL0028304 • 1 a $ E -34L1 9. Logs (List Togs and submit electronic and printed data per 20AAC 10. Field /Pool(s): To Be Submitted PRUDHOE BAY / PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11749 feet Plugs measured None feet true vertical 9079.13 feet Junk measured 11700 feet Effective Depth measured 11711 feet Packer measured See Attachment feet true vertical 9079.05 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 31 - 111 31 - 111 1490 470 Surface 3634 10 -3/4" 45.5# NT8OLHE 30 - 3664 30 - 3662.09 5210 2480 Intermediate None None None None None None Production 9331 7 -5/8" 29.7# NT -95HS 29 - 9360 29 - 8731.17 8180 5120 Liner See Attachment See Attachment See Attachment See Attachment + See Attachment See Attachment Perforation depth Measured depth See Attachment feet JAN 2 g� 17 2�1J True Vertical depth See Attachment feet SCANNED Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -80 28 - 9090 28 - 8655.45 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment - See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to wen operation: 368 22099 11 0 1357 Subsequent to operation: 336 18560 6 0 1416 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 t Service p Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas ❑ WDSPL Li GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ sUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Sum = Sys Title Petrotechnical Data Technician 7Offlpir Signatur- 45741P Phone 564 -4035 Date 9/24/2012 Form 10-404 Revised Ilika DMS SEP 2 5 yfl12 i a; , "/ Submit Original Only \ I 13 • • Daily Report of Well Operations ADL0028304 ACTIVITY DATE 1 1 - : w V= Oes • •sec ive: • w Organoseal /SqueezeCrete ** *Continued from WSR 8- 26 -12 * ** Continue milling cement from 11210' to top of bridge plug at 11420'. PT wellbore to 1000 psi for 15 min and lost 500 psi. Time mill composite plug and push to PBTD/11,699' CTD. POOH, FP w/50/50 meth. Close Swab /SSV, Pop -Off well. 8/27/2012 « < »> CTU #8 w/ 1.5" CT (CTV =19.4 bbls) Objective: GSO w/ Organoseal /SqueezeCrete MIRU after planned maintenance. RIH w/ 1.73" 3 bladed opticut mill w/ agitator. Mill from 11189- 11210' and had excellent wt transfer. POH to change to Tess aggressive mill. RIH and begin milling. ** *Continued on WSR 8- 8/26/2012 27 -12 * ** CTU #8 w/ 1.5" CT (CTV =19.4 bbls) Objective: GSO w/ Organoseal /SqueezeCrete RIH w/1.75" milling assembly. Progress very slow, not getting wgt to mill, hydraulicing, POOH change to larger water course type mill. Mill ahead w/ 3 bladed mill from 11171 - 11195' and still stacking, cannot make steady progress. POH. FP wellbore w/ 20 bbls McOH to 2200'. RDMO to SWS yard for planned maintenance. Will return after planned maintenance and resume milling with tools not yet 8/24/2012 available on the Slope Job incomplete CTU #8 w/ 1.5" CT (CTV =19.6 bbls) Objective: GSO w/ Organoseal /SqueezeCrete Continue pumping across perf w /OGSeaI, 140 bbl's of organoseal into perfs. Tractor pump contols not working. Circ down 21 bbls of Organoseal thru CT. Bullheaded from top perf and perfs locked up after 5 bbls into 4 bbl liner volume. Held 3200 psi for 1 hr. Bled pressure down to 1000 psi and contaminated cement in liner with biozan to 11145', but could not get deeper due to lockup type conditions. Pumped 80 bbls biozan while jetting cement from liner and pulling OOH. Set down lubricator /injector, perform chain inspection, change pack offs, cut 100' pipe. MU lubricator /injector, BOT 1.75" milling assembly. 1.75" max OD x 8/23/2012 16.89' OAL, Test & RIH. «» CTU #8 w/ 1.5" CT (CTV =19.6 bbls) Objective: GSO w/ Organoseal /SqueezeCrete Continue RIH w/ composite plug. Set composite plug at 11420'. POH. MU and RIH w/ Cementing BHA; 1.5" ctc, two stingers, 1.5" cmt nozzle (oal= 12.5') to 8845' and park. Finish liquid pack of wellbore with a total of 254 bbls NH4CI at AIR 0.9 bpm /1560 psi. Fill CT w/ 20 bbls Organoseal, then pump 100 bbls Organoseal down BS at AIR 0.3 bpm 1800 psi. Displace BS with 58 bbls 1% KCI at AIR 0.3 bpm/1975 psi, Swap to SWS pumpers displace OGSeaI down 8/22/2012 CT reciprocating across perfs. « »> • • CTU #8 w/ 1.5" CT (CTV =19.6 bbls) Objective: GSO w/ Organoseal /SqueezeCrete Bullhead liquid packed wellbore with 150 bbls NH4CI. Pumped down CT while reciprocating over perfs and acidized w/ 53 bbls 12% HCI followed by 55 bbls 9:1 mud acid. Over displaced with 134 bbls NH4CI. Final injection rate 1.85 bpm @ 1400 psi whp. POH. When at surface, tractor radiator developed leak and had to shutdown pumping 134bbIs into 250bbIs NH4CI flush. LRS on location to continue pumping flush. RIH to w/ PDS GR /CCL and flag coil. LRS pumped 116bbIs NH4CL, for a total of 250bbIs flush. 8/21/2012 pooh. good data.. lob in progress ** T /I /O= 0/1130/5 ( Assist CTU) Rig to choke skid. Pump 116 bbls Ammonia Cloride / water down IA to Assist CTU. Standby for CTU. RDMO. CTU on well © departure. Pad Operator 8/21/2012 notified. FLUIDS PUMPED BBLS 30 50/50 METH 20 METH 80 FRESH WATER 116 AMMONIA CLORIDE / WATER 55 9:1 MUD ACID 1082 NH4CL 53 12% HCL 234 ORGANOSEAL 20 SQUEEZE CRETE 79 BIOZAN 1798 1% KCL 259 SAFE LUBE 3826 TOTAL • • Perforation Attachment ADL0028304 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base E -34L1 2/11/09 PER 10350 10850 9077.05 9075.5 E -34L1 8/23/12 SQZ 10350 10850 9012.15 9010.6 E -34L1 2/11/09 PER 11100 11200 9009.49 9010.41 E -34L1 8/23/12 SQZ 11100 11200 9009.49 9010.41 E -34L1 2/11/09 PER 11260 11400 9010.67 9010.08 E -34L1 8/23/12 SQZ 11260 11400 9010.67 9010.08 E -34L1 2/11/09 PER 11600 11700 9012.27 9014.11 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0028304 SW Name Type MD TVD Depscription E -34L1 PACKER 8973 8535.96 3 -1/2" Baker HB Packer E -34L1 PACKER 9030 8564.24 3 -1/2" Baker L -3 Packer E -34L1 PACKER 9146 8611.93 4 -1/2" TIW Top Packer I I Casing / Tubing Attachment ADL0028304 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 31 - 111 31 - 111 1490 470 LINER 402 4 -1/2" 12.6# L -80 9146 - 9548 8676.83 - 8753.96 8430 7500 PRODUCTION 9331 7 -5/8" 29.7# NT -95HS 29 - 9360 29 - 8731.17 8180 5120 TUBING 9062 3 -1/2" 9.2# L -80 28 - 9090 28 - 8655.45 10160 10530 SURFACE 3634 10 -3/4" 45.5# NT8OLHE 30 - 3664 30 - 3662.09 5210 2480 LINER 2770 2 -3/8" 4.43# L -80 8979 - 11749 8604.07 - 9079.13 • • • WE W AD = FMC E-34 S� NOTES: WELL ANGLE > 70" 9144'. 1 ACTUATOR = BAKER C L 1 KB. ELEV = 65.0' BF. ELEV = 30.20' I KOP = 4287' Max Angle = 96' (a 10289 -- 1 2104' H3-12" OTIS SSSV LANDING NP, D = 2.75" 1 Datum MD = WA • Datum TVD = __. .. 8800 SS GAS LIFT MANO S 10 -314' CSG, 45.5#1, 3 55, D = 9.953' H 3664' ' ST MD _ TV D DEV TYPE V LV LATCH PORT DATE C 3 4247 10 MMG DOME RK P 16 09/01/12 2 7021 6861 20 MMG SO RK r 20 09/01/12 1 8280 8052 18 MMG CMY RK ' 0 01/26/94 1S 8973' 1- 13-12" BTT KB LTPw /SEAL ASSY, D = 1.810" 8979' H 2.70" BTT OEPLOY MBYT SLV, D = 2.250' 1 Minimum ID = 1.81" @ 8973' I F --- I 9004' H3 -1/2" PKR SWS NIP, ID = 2.75" I 3 -1/2" BTT KB LINER TOP PKR S x- I 9030' —{75/8' X 3 BKR L PREM PKR, D = 3.874" I I r — I 9064' —13-12" PARKER SWS NP, I) = 2.75" I ' 9077' I�3 -1/2" SVKN NO GO NP, D = 2.74' MILLED (1222/08) 1 3-12" TBG, 9.2#, L-80, .0087 bpf, D = 2.992" H 9090' I--- -1 N. I 9090' H3 - 1/2 - WLEG, D = 2.992' I 9088' H ELMD TT LOGGB) 02/04/94 1 TOP OF 412' LNR 1 — 914$" - 0---I 9146' H7-5/8" X 4-1/2" TIN PKR W SET SLV, D = 3.96' 1 t I 1 I 9174' I— IPORTED PPE I 1 1 1 7 -5/8" CSG, 29.7#, NT-95, D = 6.875" H 9360' I ---, I i ' 1 I 1 1 IVVHPSTOCK w / RA (g 9548' (02/01/091 9640' I 1 MILLOUT WINDOW (E L1) 9540' - 9548' 14 SLID LNR, 12.80, L ID = 3.953' H — 9540 I PERFORATION SUMMARY REF LOG: BH MWDGR 02/10/09 ANGLE AT TOP PEW: 88° @ 11600' I I h. Note: Refer to Production DB for tickets! pelf data SIZE SPF 11i9RVAL Opn/Sqz DATE E.34 C 4-12' SLID '9214 - 10718 0/C 01/24/94 t (//1 E-34L1 — J 1.56" 6 10350 -10850 S 08/23/1 h l'\ I — 11700" 1—IFSH CEP MIMES 1.56' 6 11100 - 11200 S 08/23/12 (0828/12) ) 1.56' 6 11260 -11400 S 08123/12 4‘ ��. 1.56" 6 11600 - 11700 0 02/11 PBTD 11711' 2-3/8' LNR, 4.4* 1-80 STL. —1 11749" .i .0039 bpi', ID = 1.995" a *�� • (E34) 9540' - 10718' CLOSED (BELOW WS) ate DATE REV BY C pe&Nrs DATE REV BY COMMHNTS PRUDHOE MY UNIT 01/26184 ML ONG HOME COMPLETION 08/30/12 CJS/JMD PERF CORRECTION (08/28/12) WILL: E-34 / L1 02/12/06 NORDICI CTD INCIETRACK (E.34A) 09/05/12 SWCIJAC GLV CIO (09/01/12) FERMI' No: 1932020 (2081780) 08/19/12 PJC WANG CORRECTION 09/16/12 PJC PERF CORRECTION AR No: 50 -029- 22437 -00 (60) 08/20/12 PJC DRAWtIG CORRECTIONS SEC 6, T11 N, R14E, 168' FTC & 500' FIi 08/22/12 MSS/MD GLV CIO (08/18/12) 0829112 CJS/JM) SOZ PBRFS & SET ASH (08/23- 28/12) BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 4/5/2010 Permit to Drill 2081780 W 11 N / e ame No. PRUpHOE BAY UNIT E-34L1 Operator BP EXPLORATION (ALASI(A) INC API No. 50-029-22437-60-00 MD 11749 TVD 9079 Completion Date 2/11/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~- / / -- _ __ _._ DATAINFORMATgN - - -- Types Electric or Other Logs Run: MWD, GR, ROP, RACLX, RACHX, RPCHX, GR, CAL, RES, DEN, PO (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset ~ ~~ ~ ,,,, o...- Infarvni ~y meairrmt pumper Name - Scale ~~~~~ Media No Start Stop ""' CH Received Comments Rpt LIS Verification 9314 11749 Open 4/10/2009 LIS Veri, GR, ROP, RAD, C Lis ~~,~ // 17838~fnduction/Resistivit RAD, RPD, RPS y 9314 11749 Open 4/10/2009 LIS Veri, GR, ROP, RAD, RAD, RPD, RPS 9 Induction/Resistivity 25 Col 9540 11749 Open 4/14/2009 MD MPR, GR 2-Feb-2009 09 Induction/Resistivity ~°S Col 9540 11749 Open 4/14/2009 TVD MPR, GR 2-Feb-2009 o ; Gamma Ray 25 Col 9540 11749 Open 4/14/2009 MD GR 2-Feb-2009 D C Lis 17978C~eutron 9595 11741 Open 5/4/2009 LIS Veri, GR, CNT, SDN, DIL 09 Neutron 5 Blu 9542 11421 Case 5/4/2009 Multi Ex, CNL, PCMS, Litho-Dens, Indution, GR 8- Feb-2009 D D Asc Directional Survey 34 11749 Open 4/18/2009 Pt Directional Survey 34 11749 Open 4/18/2009 weu r .,.e~ie., ..~,._ ~_r_...Y_., ._~...r.__ .........w....... Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 4/5/2010 Permit to Drill 2081780 Well Name/No. PRUDHOE BAY UNIT E-34L1 MD 11749 TVD 9079 ADDITIONAL INFORMATION Well Cored? Y 1~ Chips Received? Y / N Analysis 15"t1~ Received? Completion Date 2/11/2009 Operator BP EXPLORATION (ALASF(A) INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? ~J' N Formation Tops L~ N API No. 50-029-22437-60-00 UIC N Comments: Compliance Reviewed By: Date: ~~ -r.~~ BAKER HUGHES ~~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: April 15, 2009 Please find enclosed directional survey data for the following wells: K-06B J-05C E-34L1 J-OSCL1 05-27BPB 1 07-02B OS-27B 07-20B 07-29D Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~ ,State of Alaska AOGCC DATE: ~ C~ ~ Cc: State of Alaska, AOGCC • INTEQ L®g Data Transmittal ®rm To: State of Alaska -A®GCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: E-34L1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) ' 1 LDWG lister summary 0 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) G 1 color print - MPR/Directional Measured Depth Log (to follow) ~~ LAC Job#: 2444741 ?m_~. ~_~__ _ ~ g~4.. __ __r.A, ~u.r_ ~'' Sent by: Catrina Guidry Date: 04/09/09 ; Received by: ~~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING. & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 i~. `~ " -~ ~Iti DIES d~~' ~~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, March 18, 2009 11:29 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU E-34L1 / PTD # 208-178 Hi Art, Please reference the following well: Well Name: PBU E-34L1 Permit #: 208-178 API #: 50-029-22437-60-00 Top Perf MD: 10350' Bottom PerF MD: 11700' This well began Production on March 13, 2009 Method of Operations is: Flowing Date of Test: 03/13/09 Hours Tested: 8 24-Hour Rate /Oil-Bbl: 1,430 24-Hour Rate /Gas-Mcf: 21,316 24-Hour Rate /Water-Bbl: 4 Test Rate /Oil-Bbl: 477 Test Rate /Gas-Mcf: 7,105 Test Rate /Water-Bbl: 1 Choke Size: 128 Gas-Oil Ration: 14,906 Flow Tubing Pressure: 900 Casing Pressure: 1,300 Oil Gravity-API: Not Available 3/18/2009 STATE OF ALASKA ALASK~IL AND GAS CONSERVATION CO SSION ~,i.~ ~ a v ~®..s'K~ ~~~~ ~~ 2009 /~ l WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,!~I~§~~ iii has Cons. Commission _L..rnnG 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 2/ 2009 12. Permit to Drill Number 208-178 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/2/2009 - 13. API Number 50-029-22437-60-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/8/2009- 14. Well Name and Number: PBU E-34L1 168 FNL, 500 FEL, SEC. 06, T11 N, R14E, UM Top of Productive Horizon: 692' FSL, 2039' FWL, SEC. 32, T12N, R14E, UM 8. KB (ft above MSL): 64.90' Ground (ft MSL): 30.2 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 977' FSL, 3703' FWL, SEC 32, T12N, R14E, UM 9. Plug Back Depth (MD+TVD) 11709 9079 Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 664445 y- 5976895 Zone- ASP4 10. Total Depth (MD+TVD) 11749 9079 16. Property Designation: ADL028304, ADL028299 TPI: x- 666961 y_ 5977812 Zone- ASP4 Total Depth: x- 668618 y- 5978134 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submi I r ni n rinted information er 20 5.0 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, ROP, RACLX, RACHX, RPCLX, RPCHX, GR, CAL, RES, DEN, POR WiU,DOLtJ ~ ~ ~ ~'~~'B~TYD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT r WT. PER FL GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED, 20" 1.5# H-4 1' 111' 1' 111' 30" 6 sx Ar is Set A r x. 1 - /4" 4 NT H 2' - / " 1 4 PF 'E" 7-5/8" 29.7# NT9 HS 33' 360' 33' 8731' 9-7/8" x Class'G' 4-1/2" 12. - 0 1 77' 8 4' 6-3/4" Uncem n Slo ed Lin r 2-/" 4. 7' 117 4' ' 23. Open to production or inject ion? ®Yes ^ No 24. TusiNC RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SizE DEPTH SET MD PACKER SET MD 1.56" Gun Diameter 6 SPF 3-1/2", 9.3#, L-80 9090' 9030' , MD TVD MD TVD 10350' - 10$50' 9077 - 9076' 11100' - 11200' 9074' - 9075' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.:' 11261)' - 11400' 9076' - 9075' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11600' -11700' 9077' - 9079' 2100' Freeze Protected with McOH 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HouR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ~ ~~f~9;_ ~ ~:. • _,~ Form 10-407 Revised 02/200 ` 44;`I ~~ CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and fonmations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top Shublik 9621' 8769' None Top Sadlerochit 9725' 8833' TCGL /Top Zone 3 9824' 8922' BCGL /Top Zone 2 'C' 9896' 8982' 23S6 /Top Zone 2 'B' 9949' 9017' 22TS 10036' 9061' Formation at Total Depth (Name): 22TS 10036' 9061' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true nd correct to the best of my knowledge. Signed S dra Stewm Title Drilling Technologist Date ~~ w ~ "~ PBU E-34L1 208-178 Prepared ey Namenuumber. Sondra Stewman, 564-4750 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. bear 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. bear 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE = cM/ • DRLG DRAFT E -34 SAF OTES: WELL ANGLE > 70° ~ 9162' ~ E-34L1 WELLHEAD= FMC ACTUATOR = KB. ELEV = BAKER 65.C' BF. ELEV = KOP = 30.2C' 4287' Max Angle = 113' ~ 10742' Datum MD = NIA Datum ND = 8800' SS I 10-3/4" CSG, 45.5#, J-55, ID = 9.953" I Minimum ID =1.81" ~ 8973' BTT 3-1/2" Liner Top Packer Liner Top Packer ~ 8973' TOP OF 2-3/8" LNR 8979' C 2104' ~-~3-1/2" OT1S SSSV LANDING NIP, ID = 2.75" C;AS I IFTMANf)RFI S ST MD ND DEV TYPE VLV LATCH PORT DATE 3 4247 4241 10 MMG DOME RK 16 02/28!09 2 7021 6861 19 MMG SO RK 20 02/28!09 1 8280 8052 18 MMG DMY RK 0 9004' I-~3-1/2" PARKER SWS NIP, ID = 2.75" 9030' I-i 7-518" X 3-1 /2" BAKER SA BL-3 PERM PKR, ID = 3.874" 9054' 3-1 /2" PARKER SWS NIP, ID = 2.75" 9077• 3-1 /2" SWN NO GO NIP, ID milled to = 2.74" ~ 3-1 /2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I TOP OF 4-1 /2" LNR ~~ 9146' TOP OF SAGRIVEP. FORMATION 9343' 7-5/8" CSG, 29.7#, ID = 6.875" 9360' 9540' HMiA Window off Mechanical PERFORATION SUMMARY REF LOG: BHI MWD/GR 02/1012009 ANGLE AT TOP PERF: 92° @ 1Q350 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1 5/9 6 10,350'-10,850' O 02111i~'~"i 15/9 6 11,100'-11,200' O 02I11;C~~ 15/9 6 11,260'-11,400' O 02111;11 1 5/9 6 11,600'-11,700' O 0211'i09 9090' 3-1/2° WLEG 9088' ELMD TT LOGGED 02/04/94 9146' I~ 7-518" X 4112" TNV PKR W/ SCOOP HEA D I. I I I ~ 9174' PORTED PIPE I I I I I I I I I I I I I I ~ 9740' TOC 4-1/2" SLTD LNR, 12.61!, NT-80, .0152 bpf, ID = 3.953" 10742' I I I I I I I I I I 1 3/8" Liner, Cemented & Perf'd ~ 11749' PBTD =11,709 ft DATE REV BY COMMENTS DATE REV BY COMMENTS 01126!94 ML OR1G HORIZ COMPLETION 02/12;G9 TK/RW CTD Horizontal Sidetrack 09/06/01 RN/TP CORRECTIONS 02/13109 PJC DRLG CORRECTIONS 07/12/03 CMO/TLP KB ELEVATION, MAX ANGLE 03/03/09 TFA/SV GLV CJO (02/28109) 09/17/03 CMOlTLP DATUM MD 8 LOCATION 10/20/04 CAOlTLH GLV C!O 10/22/08 MSE PROPOSED CTD Lateral PRUDHOE BAY UNIT WELL: E-34L1 PERMIT No: ,208178 API No: SO-029-224370 SEC 6, T11 N, R14E, 168' FNL 8500 FEL BP Exploration (Alaska) ~ ~ BP EXPLORATION Operations Summary Report Page 1 of 12 ~ Legal Well Name: E-34 Common Well Name: E-34 Spud Date: 1/5/1994 Event Name: REENTER+COMPLETE Start: 1/30/2009 End: 2/12/2009 Contractor Name: NORDIC CALISTA Rig Release: 2/12/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/30/2009 16:00 - 18:00 2.00 MOB P PRE PJSM for rig move Move rig from K-pad to E-pad 18:00 - 19:00 1.00 MOB P PRE PJSM for pulling rig over well Begin moving rig over well, when bracket on rear steering arm pulled apart Set rig down and call welder out to repair 19:00 - 00:00 5.00 MOB P PRE Repair bracket c/o gripper blocks on injector 1/31/2009 00:00 - 01:00 1.00 MOB N PRE Finish repairing bracket on rear steering arm 01:00 - 01:30 0.50 MOB P PRE Pull rig over well ACCEPT RIG ~ 01:30 01:30 - 06:00 4.50 BOPSU P PRE NU BOP's and grease Finish changing out gripper blocks on injector 06:00 - 06:15 0.25 BOPSU P PRE PJSM for testing BOP 06:15 - 14:00 7.75 BOPSU P PRE Test BOP 14:00 - 14:15 0.25 RIGU P PRE PJSM for pulling BPV. 14:15 - 16:00 1.75 RIGU P PRE PU lubricator, test to 1,300psi, RIH & pull BPV, LD Lubricator 16:00 - 18:30 2.50 RIGU P PRE Fill well, pit volume ~ start 327bb1s Pull coil across to injector while filling well 18:30 - 20:30 2.00 RIGU P PRE Change pack off, MU coil connector, pull test, fill coil 20:30 - 21:00 0.50 RIGU P PRE Test inner reel valve 21:00 - 21:30 0.50 STWHIP P WEXIT MU XO and 1 jt of 2-1/16" CSH, pump slack out coil 21:30 - 23:30 2.00 STWHIP P WEXIT Pop off, cut 266' of eline, MU ball drop test BHA #1 23:30 - 00:00 0.50 STWHIP P WEXIT RIH to 6965' for ball drop test 2/1/2009 00:00 - 00:30 0.50 STWHIP P WEXIT Continue RIH w/ ball drop test BHA Swap wellbore over to milling fluid 00:30 - 01:15 0.75 STWHIP P WEXIT Launch 1/2" stl ball in high vis sweep w/ 1000 psi, good launch could hear ball moving Circ p - 2850 psi ~ 2.15 bpm, 1.7 bpm out Ball away at 21.5 bbl With 26 bbl away, drop rate to 0.5 bpm ~ 850 psi Ball on seat at 31.5 bbl, shear ~ 2750 psi 01:15 - 01:45 0.50 STWHIP P WEXIT Launch 5/8" stl ball in high vis sweep w/ 1000 psi, good launch could hear ball moving Circ p - 2550 psi C~ 2.13 bpm, 1.6 bpm out Ball away at 19.7 bbl With 26 bbl away, drop rate to 0.5 bpm ~ 850 psi Ball on seat at 31 bbl, shear C~3 2940 psi 01:45 - 02:15 0.50 STWHIP P WEXIT Launch 3/4" stl ball in high vis sweep w/ 1000 psi, good launch could hear ball moving Circ p - 2690 psi @ 2.18 bpm, 1.5 bpm out Ball away at 19.4 bbl With 26 bbl away, drop rate to 0.5 bpm ~ 930 psi Ball on seat at 30.9 bbl, shear C~3 3400 psi Good test all three balls went on seat Well is still taking fluids -75% returns 02:15 - 03:15 1.00 STWHIP P WEXIT POOH 03:15 - 03:30 0.25 STWHIP P WEXIT PJSM for LD BHA, discus procedure hazards and mitigations Printed: 3/6/2009 1:43:27 PM ~ ~ BP EXPLORATION Page 2 of 12 ~ Operations Summary Report Legal Well Common W Event Name Contractor Rig Name: Date Name: E eli Name: E : R Name: N N From - To -34 -34 EENTE ORDIC ORDIC Hours R+COM CALIST 1 Task . PLET A Code E NPT Start Rig Rig N Phase ~ Spud Date: 1/5/1994 : 1/30/2009 End: 2/12/2009 Release: 2/12/2009 umber: Description of Operations 2/1/2009 03:30 - 04:00 0.50 STWHIP P WEXIT LD ball drop BHA 04:00 - 05:00 1.00 STWHIP P WEXIT Pump slack management, cut 350' of coil 05:00 - 06:30 1.50 STWHIP P WEXIT Test eline, MU CTC, pull test And Pressure test. 06:30 - 08:00 1.50 STWHIP P WEXIT Head up Baker Inteq. 08:00 - 08:40 0.67 STWHIP N WEXIT RIH to thaw coil. RIH to 600' with 1000 pwsi CT pressure trapped. Circulate across top of well. 5 bbl to fill hole. POH. 08:40 - 09:30 0.83 STWHIP P WEXIT Continue to Head up Baker. Periodically stop the circulate CT. 09:30 - 09:45 0.25 WHIP P WEXIT PJSM for PU of WS BHA. 09:45 - 10:15 0.50 WHIP P WEXIT PU WS BHA. 10:15 - 12:15 2.00 WHIP P WEXIT RIH 12:15 - 12:50 0.58 WHIP P WEXIT Log tie-in. Corection +9'. 12:50 - 13:00 0.17 WHIP P WEXIT RIH to set top of whipstock at 9540. 13:00 - 13:05 0.08 WHIP P WEXIT Close ECD and pressure to 2800 psi set WS 13:05 - 14:30 1.42 WHIP P WEXIT POH. 14:30 - 15:30 1.00 WHIP P WEXIT LD whipstock riunning tools and PU window milling assembly. 15:30 - 17:15 1.75 WHIP P WEXIT RIH to 9380' 17:15 - 18:15 1.00 WHIP P WEXIT Log 9380 - 9476. Log tie-in. Correction +8 18:15 - 19:00 0.75 WHIP P WEXIT RIH to top of WS 19:00 - 00:00 5.00 STWHIP P WEXIT Mill window 3,000 FS, Circ. P-3,130 psi @ 1.52/1.37 ~ 9,543.2' Circ. P - 3,106 psi, 1.52/1.37 ~ 9,544' Circ. P - 3,165 psi, 1.5/1.4 C~ 9,545.3' Circ. P - 3,046 psi, 1.5/1.4 ~ 9,546.8' Circ. P - 3,010 psi, 1.5/1.42 C~3 9,547.6' Circ. P - 3,047psi, 1.5/1.43 ~ 9,548.1' Exit window ~ 9,548.6'- 2/2/2009 00:00 - 04:45 4.75 STWHIP P WEXIT FS 3,000psi Circ. Psi 3,010 ~ 1.5/1.42 C~ 9,549.6' Mill 10' of formation to 9558.5' Ream up and down several times, window looks good 04:45 - 06:15 1.50 STWHIP P WEXIT POOH 06:15 - 06:30 0.25 STWHIP P WEXIT PJSM for BHA change out. 06:30 - 08:00 1.50 STWHIP P WEXIT LD window mills. 2.73" NO GO. 2.74" GO. PU Drilling BHA. 08:00 - 10:00 2.00 DRILL P PROD1 RIH. Tag at 9558. 10:00 - 13:45 3.75 DRILL P PROD1 Drill 1.52/1.44 bpm C~ 2990 psi, 2850 psi = FS, WOB 1.13, ECD 9.98, ROP 40. Drill to 9700. 13:45 - 14:05 0.33 DRILL P PROD1 Wiper. 14:05 - 18:30 4.42 DRILL P PROD1 Drill 1.56/1.51 bpm ~ 3280 psi, WOB 4K,ECD 10.13, ROP 29, Drill to 9850'. 18:30 - 18:50 0.33 DRILL P PROD1 Wiper 18:50 - 20:15 1.42 DRILL P PROD1 Drill 1.52/1.46 bpm ~ 3120 psi, WOB 1.96K ,ECD 10.2, ROP 15-25, Drill to 9,875'. 2,950psi = FS Stall C~ 9,851', 9,852' 20:15 - 23:00 2.75 DRILL P PROD1 Drill 1.54/1.50, 3180 psi, 2970 psi FS, WOB 2.36K, ECD 10.2, ROP 15-60 fph, Drill to 10,000' Stall ~ 9,973' 23:00 - 23:45 0.75 DRILL P PROD1 Wiper & Log trip + 1.5' Correction 23:45 - 00:00 0.25 DRILL P PROD1 Drill 1.53/1.46 bpm C~ 3245 psi, 2,975 psi FS, WOB 2K,ECD 10.29, ROP 20-50, Drill to 10,023'. Stall ~ 10,023' 2/3/2009 00:00 - 03:15 3.25 DRILL P PROD1 Drill 1.53/1.46 bpm ~ 3,200 psi, 2,975 psi FS, WOB Printed: 3/6/2009 1:43:27 PM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: E-34 Common Well Name: E-34 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To 'Hours .Task Code' NPT 2/3/2009 00:00 - 03:15 3.25 DRILL P 03:15 - 04:45 I 1.501 DRILL I P 04:45 - 05:00 I 0.251 DRILL I P 05:00 - 05:45 I 0.751 DRILL I P 05:45 - 06:20 0.58 DRILL P 06:20 - 06:30 0.17 DRILL N 06:30 - 08:15 1.75 DRILL N 08:15 - 09:45 1.50 DRILL C 09:45 - 11:30 1.75 DRILL C 11:30 - 12:45 1.25 DRILL P 12:45 - 17:00 4.25 DRILL P 17:00 - 17:40 0.67 DRILL P 17:40 - 18:15 0.58 DRILL P 18:15 - 21:00 I 2.751 DRILL I P 21:00 - 22:45 I 1.751 DRILL I P Start: 1 /30/2009 Rig Release: 2/12/2009 Rig Number: Page 3 of 12 Spud Date: 1/5/1994 End: 2/12/2009 Phase ', Description of Operations PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 22:45 - 23:45 1.00 DRILL P PROD1 1 23:45 - 00:00 0.25 DRILL P PROD1 2/4/2009 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 02:00 1.25 DRILL P PROD1 02:00 - 02:15 0.25 DRILL P PRODi 02:15 - 02:30 0.25 DRILL P PRODi 02:30 - 05:30 3.00 DRILL P PRODi 05:30 - 07:15 1.75 DRILL P PROD1 07:15 - 07:30 0.25 DRILL P PROD1 07:30 - 11:00 I 3.501 DRILL I P I I PROD1 1.23K,ECD 10.27, ROP 20-65, Drill to 10,100'. Bled down OA & IA to zero psi ~ 01:30 Lost MTR work C~ 10,070' Stall ~ 10,076',10,095',10,096'10,100 POOH to check bit due to low penetration rates. Geo felt that we should have been able to drill faster than we are PJSM for BHA handling, discuss procedure, hazards and mitigations Swap bit Pulled the USED Hycalog TREX, the cutters were chipped on the wing and the pilot. The bit was becoming rung out. The bit was graded 2-3-ct-n-x-x-ro-pr The motor was checked for tightness, all checked out good, ran in hole w/ the same motor and BHA PU new Hycalog T REX RIH POH to service injector (chain misallignment ) Wait on SLB mechanic. Adjust chains and change out counter. LD BHA and add restivity tool to BHA per geo request. (Res will help locate the illusive HOT) RIH to window. Log tie-in. Correction +15'. MAD pass to 10100'. Drill build section. 1.5 bpm, 3100-4100 psi, 70R TF, 40 fph, 2-4K WOB, 10.2 ECD, Found HOT at 9015' TVDSS. Landed well at 9024' TVDSS. Build incl up to 93 deg. Drilled to 10240'. Stacking wt. Wiper trip to window. RIH clean to bottom. Drill build section. 1.5 bpm, 3100-3400 psi, 70R TF, Stacking wt, very slow drilling. Last cuttings sample had 50% chert. POOH to check on bit due to low penetration rates and frequent stacking LD Drilling BHA The pilot is missing 1/2"-1" Discuss w/ baker and town the possibilities of it breaking, discuss junk mill vs running in hole w/new bit while waiting on Baker mills, in the end decide to run in w/ new bit MU Driling BHA P/U drilling BHA with new bit #4. P/U drilling BHA with new bit #4. RIH with drilling BHA & new bit to 9,583' Log tie in +10' correction RIH with drilling BHA & new bit to 10,240' Drill 1.53/1.49 bpm ~ 3,450 psi, 3,300 psi FS, WOB 1.29K,ECD 10.48, ROP 40-90, Drill to 10,420'. POH for RSM SAFETY MEETING. Review procedure, hazards and mitigation for changing to Rib steer Lateral BHA. Lay out Build BHA #7. HYC BC Bit #4 graded at (2,3,1 ). M/U CoilTrak, RES, RSM lateral BHA with HCC RS Bit #5. Test tools at surface. BHA OAL = 64.51' Printed: 3/6/2009 1:43:27 PM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: E -34 Common W ell Name: E -34 Spud Date: 1/5/1994 Event Nam e: REENTE R+COM PLET E Start : 1/30/2009 End: 2/12/2009 Contractor Name: N ORDIC CALIST A Rig Release: 2/12/2009 Rig Name: N ORDIC 1 Rig N umber: Date ', From - To ' Hours Task Code NPT I~, Phase Description of Operations 2/4/2009 11:00 - 13:20 2.33 DRILL P PROD1 RIH with CoilTrak / RES / RS lateral BHA #8. Circ at 0.3 bpm, 1150 psi. Set down in window at 9545', four times. Lowside window. Work bit thru window and sat down at 9554' on rib steer, work thru OK with 0.2 bpm. 13:20 - 13:40 0.33 DRILL P PROD1 Log GR tie-in at RA tag. Added 6'. 13:40 - 14:10 0.50 DRILL P PROD1 RIH. Sat down wt at 10160'. Work thru. RIH and sat down at 10320'. Work thru. RIH to bottom. 14:10 - 15:00 0.83 DRILL P PROD1 Drill Z2 lateral with RSM. 1.4 bpm, 2950-3500 psi, 90 deg incl, 100R TF, 70 fph, 1-2K wob, 10.5 ecd, Start fluid swap to new FloPro at 10,450'. Drilled to 10480' 15:00 - 16:30 1.50 DRILL P PRODi Drill Z2 lateral with RSM. 1.4 bpm, 2900-3300 psi, 90 deg incl, 70R TF, 40 fph, 2-3K wob, 10.1 ecd, Stacking wt. ROP is declining. Drilled to 10,550'. 16:30 - 17:45 1.25 DRILL P PROD1 Wiper trip to window. RIH clean to bottom. 17:45 - 19:15 1.50 DRILL P PROD1 Drill Z2 lateral with RSM. 1.4 bpm, 2900-3300 psi, 90 deg incl, 90R TF, 2-3K wob, 10.1 ecd, ROP variable 25-70 fph Drill to 10,600' 19:15 - 22:00 2.75 DRILL P PROD1 Drill Z2 lateral w. RSM, 1.4bpm/1.35 bpm, 3000-3200 psi, 89 deg incl, 2-3K wob, 10.1 ecd ROP 10-20 fph, stacking weight, test RSM to see max DL, Max DL was 6 Drill to 10,640' 22:00 - 00:00 2.00 DRILL P PROD1 POOH to inspect bit due to low penetration rate Pulled thru window with no problems Open the EDC and POH 2/5/2009 00:00 - 00:45 0.75 DRILL P PROD1 UD Rib Steer Assy. & check tool Bit Rung Out on pilot, Wing has chipped & worn teeth 6-4-RO-S-6-2-BT-PR 00:45 - 01:15 0.50 DRILL P PRODi Inspect rib steer Assembly 01:15 - 03:30 2.25 DRILL P PROD1 P/U Rib Steer Assembly & new bit RIH, drop pumps through window, sit down once at 9,547', PU and go right through window second time 03:30 - 03:45 0.25 DRILL P PROD1 Log GR tie-in, +5' correction 03:45 - 04:15 0.50 DRILL P PROD1 Continue RIH 04:15 - 05:00 0.75 DRILL P PROD1 Drill Z2 lateral with RSM. 1.4 bpm/1.3 bpm, 2950-3200 psi, 90 deg incl, 70-100 fph, 1.5-2K wob, 10.3 ecd, FS 2,850psi Drilled to 10,715'. 05:00 - 06:00 1.00 DRILL P PROD1 Drill Z2 lateral with RSM. 1.4 bpm/1.3 bpm, 2950-3200 psi, 90 deg incl, 40-80 fph, 1.5-2K wob, 10.3 ecd, FS 2,850psi Drilled to 10,740' 06:00 - 08:15 2.25 DRILL P PROD1 Drill Z2 lateral with RSM. 1.4 bpm/1.3 bpm, 2950-3600 psi, 90 deg incl, 20 fph, 1.5-2K wob, 10.3 ecd, Drilled to 10772' 08:15 - 08:55 0.67 DRILL P PRODi Drilled Z26 lateral with RSM, 1.4 bpm, 2900-3600 psi, 90 deg incl, 5 fph, 1-3K wob, 10.3 ecd. Stacking wt. No ROP last 15 min. 65% chert and pyrite in last cuttings sample. Printed: 3/6/2009 1:43:27 PM • • BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: E-34 Common Well Name: E-34 Spud Date: 1/5/1994 Event Name: REENTER+COMPLETE Start: 1/30/2009 End: 2/12/2009 Contractor Name: NORDIC CALISTA Rig Release: 2/12/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ', Code NPT ' Phase Description of Operations 2/5/2009 08:15 - 08:55 0.67 DRILL P PROD1 Drilled to 10775'. 08:55 - 09:45 0.83 DRILL P PROD1 POH for bit. Clean trip to window. Pulled clean thru window. Opened EDC. pulled thru 7-5/8" casing while circ 1.9 bpm. RIH and POH while circ 1.9 bpm to clean casing. 09:45 - 11:15 1.50 DRILL P PROD1 POH while circ 1.9 bpm, 11:15 - 11:30 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing bits and checking rib steer BHA. 11:30 - 12:50 1.33 DRILL P PROD1 Lay out rib steer BHA #9. Bit #6 graded at (6,3,1) pilot rung out same as bit #5. Test rib steer at surface. All tools checked OK. M/U new HCC BC RS Bit #7, RSM, RES and CoilTrak. Test tools at surface. BHA OAL = 64.51'. 12:50 - 14:30 1.67 DRILL P PROD1 RIH with RSM /RES / coilTrak Lateral BHA #10. Circ at 0.1 bpm, 800 psi. RIH thru window, lost 3K down wt. 14:30 - 14:45 0.25 DRILL P PROD1 Log GR tie-in with RA tag. Add 6' CTD. 14:45 - 15:15 0.50 DRILL P PROD1 RIH clean to bottom. 15:15 - 17:45 2.50 DRILL P PROD1 Drilled Z2B lateral with RSM, 1.4 bpm, 2900-3500 psi, 90 deg incl, 30-40 fph, 1-2K wob, 10.3 ecd. Drilled to 10850' 17:45 - 21:30 3.75 DRILL P PROD1 Drilled Z2B lateral with RSM, 1.4 bpm, 2900-3500 psi, 90 deg incl, 30 fph, 1-2K wob, 10.3 ecd. Short wiper ~ 10,903' & continue drilling to 10,950' 21:30 - 23:15 1.75 DRILL P PROD1 Wiper trip to window 23:15 - 00:00 0.75 DRILL P PROD1 Drill Z2B lateral w/ RSM, 1.5, 3000-35000 psi, 90 deg incl, 25-35 fph, 1-2K WOB, 10.5 ecd Drill to 10980' 2/6/2009 00:00 - 02:00 2.00 DRILL P PROD1 Drill Z2B lateral w/ RSM, 1.5, 3000-35000 psi, 90 deg incl, 25-35 fph, 1-2K WOB, 10.5 ecd Drill to 11,014' ROP dropped to less than 10fph & stacking wt. 02:00 - 05:00 3.00 DRILL P PRODi POOH to inspect bit & rib steer tool Run through window clean Open EDC, pump at 1.9 and POOH Closed EDC @ 533' 05:00 - 05:15 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing bits and checking rib steer BHA. 05:15 - 06:45 1.50 DRILL P PROD1 Lay out rib steer BHA #10 Bit graded 5-4-RO-N-X-I-BT-PR Change out RSM. M/U re-build HCC BC rib steer Bit #8, RSM, RES and CoilTrak. BHA OAL = 64.51'. 06:45 - 08:30 1.75 DRILL P PROD1 RIH with RSM /RES / CoilTrak Lateral BHA #11. Circ at 0.1 bpm, 900 psi RIH clean to window. Slight wt loss going thru window. 08:30 - 08:45 0.25 DRILL P PROD1 Log GR tie-in at RA tag. Add 3' CTD. 08:45 - 09:15 0.50 DRILL P PROD1 RIH clean to bottom. 1.4 bpm, 3050 psi, full returns. 09:15 - 10:45 1.50 DRILL P PROD1 Drill Z26 lat w/ RSM, 1.4 bpm, 3000-3400 psi, 60L TF, 90 deg incl, 1.5K wob, 10.6 ecd, 40 fph, Drilled to 11065'. ~' 10:45 - 12:30 1.75 DRILL P PROD1 Drill Z2B lat w/ RSM, 1.4 bpm, 3000-3400 psi, 60L TF, 90 deg incl, 1.5K wob, 10.6 ecd, 40 fph, with used FloPro. Printed: 3/6/2009 1:43:27 PM BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: E-34 Common Well Name: E-34 Spud Date: 1/5/1994 Event Name: REENTER+COMPLETE Start: 1/30/2009 End: 2/12/2009 Contractor Name: NORDIC CALISTA Rig Release: 2/12/2009 ~i Rig Name: NORDIC 1 Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 2/6/2009 10:45 - 12:30 1.75 DRILL P PROD1 Swap to GeoVis at 11065'. Free spin press fell from 3000 psi to 2400 psi at 1.40 bpm, with GeoVis at the bit. Circ press will continue to drop as annulus is swapped over to GeoVis. Drilled to 11,120'. 12:30 - 13:45 1.25 DRILL P PROD1 Drill Z26 lat w/ RSM, 1.4 bpm Free spin = 2050 psi with GeoVis to surface. Ecd = 9.7 1.4 bpm, 2050-2500 psi, 70L TF, 90 deg incl, 2-3K wob, 9.7 ecd, 20-30 fph, Stacking wt, Slower ROP. Drilled to 11,150'. 13:45 - 15:00 1.25 DRILL P PRODi Wiper trip to window. Clean hole. RIH clean to bottom. 15:00 - 15:45 0.75 DRILL P PRODi Drill Z2B lat w/ RSM, 1.4 bpm, 2050 free spin, 2200-2900 psi, 90L TF, 90 deg incl, 3.3K wob, 10 fph, 9.7 ecd Stacking wt, bit is wornout. Drilled to 11155'. 15:45 - 17:00 1.25 DRILL P PROD1 POH to window. clean hole. Pull clean thru window. Open EDC. Circ. at 1.8 bpm and cleanout 7-5/8" casing. 17:00 - 18:15 1.25 DRILL P PROD1 POH for bit. 18:15 - 18:30 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing bits and checking rib steer BHA. 18:30 - 20:00 1.50 DRILL P PROD1 Lay out rib steer BHA #11 Bit graded 5-4-RO-N-X-I-BT-PR Test RSM M/U re-build HCC BC rib steer Bit #9, RSM, RES and CoilTrak. BHA OAL = 64.51'. 20:00 - 22:00 2.00 DRILL P PROD1 RIH with RSM /RES / CoilTrak Lateral BHA #12. Circ at 0.2 bpm, 700 psi RIH clean to window. 22:00 - 22:15 0.25 DRILL P PROD1 Log GR tie-in at RA tag. + 4' correction. 22:15 - 23:00 0.75 DRILL P PROD1 RIH clean to bottom. 1.5 bpm, 2,402 psi 23:00 - 00:00 1.00 DRILL P PROD1 Drill Z2B lat w/ RSM, 1.5 bpm, 2,500-2,800 psi, 60L TF, 90 deg incl, 2K wob, 10.04 ecd, 30-60 fph, FS 2,500psi Drilled to 11,192' 2/7/2009 00:00 - 03:00 3.00 DRILL P PROD1 Drill Z26 lat w/ RSM, 1.5 bpm, 2,500-2,800 psi, 60L TF, 90 deg incl, 2K wob, 10.04 ecd, 30-60 fph, FS 2,500psi Drilled to 11,300' 03:00 - 05:00 2.00 DRILL P PROD1 Wiper trip to window 05:00 - 06:00 1.00 DRILL P PROD1 Drill Z26 lat w/ RSM, 1.5 bpm, 2,500-2,800 psi, 60L TF, 90 deg incl, 2K wob, 9.99 ecd, 40 fph, FS 2,500psi Drilled to 11,320' 06:00 - 08:30 2.50 DRILL P PROD1 Drill Z2B lat w/ RSM, 1.6 bpm, 2,700-3100 psi, 10L TF, 90 deg incl, 2-3K wob, 10.0 ecd, 40 fph, Drilling break at 11330'. ROP went to 80 fph for 30 ft. ROP slowed and started stacking wt. Drilled to 11415'. 08:30 - 10:00 1.50 DRILL P PROD1 POH for bit. Pull clean to window. Pull clean thru window. Open EDC and cleanout 7-5/8" casing. Printed: 3/6/2009 1:43:27 PM BP EXPLORATION Page 7 of 12 I, Operations Summary Report 'Legal Well Name: E-34 Common Well Name: E-34 Spud Date: 1/5/1994 Event Name: REENTER+COMPLETE Start: 1/30/2009 End: 2/12/2009 Contractor Name: NORDIC CALISTA Rig Release: 2/12/2009 Rig Name: NORDIC 1 Rig Number: Date ~'~~ From - To 'Hours Task '~~, Code' NPT Phase ~I Description of Operations 2/7/2009 10:00 - 11:15 1.25 DRILL P PROD1 POH for bit. 11:15 - 11:30 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing and checking BHA. 11:30 - 12:00 0.50 DRILL P PROD1 Lay out REM /RES lateral BHA #12. HCC RSM BC Bit #9 graded at (5,4,1 ). 12:00 - 12:30 0.50 BOPSU P PROD1 Function test BOPE. Good test. 12:30 - 13:30 1.00 DRILL P PROD1 M/U RSM /RES / CoilTrak Lateral BHA #13. Test tools at surface. BHA OAL = 64.51'. 13:30 - 15:00 1.50 DRILL P PROD1 RIH with BHA #13. Circ at 0.1 bpm, 750 PSI. RIH thru window with 3K wt loss. 15:00 - 15:15 0.25 DRILL P PROD1 Log GR tie-in at RA tag. Add 2' CTD. 15:15 - 15:45 0.50 DRILL P PROD1 RIH clean to bottom. 15:45 - 17:00 1.25 DRILL P PROD1 Drill Z26 lat w/ RSM, 1.6 bpm, 2,700-3600 psi, 90L TF, 90 deg incl, 2-3K wob, 10.2 ecd, 40 fph, Drilled to 11,450'. 17:00 - 19:45 2.75 DRILL P PROD1 Drill Z2B lat w/ RSM, 1.6 bpm, 2,700-3600 psi, 90L TF, 90 deg incl, 2-3K wob, 10.2 ecd, 40 fph, Drilled to 11,550' 19:45 - 21:45 2.00 DRILL P PROD1 Wiper trip to window 21:45 - 00:00 2.25 DRILL P PRODi Drill Z26 lat w/ RSM, 1.6 bpm, 2,700-3600 psi, 90L TF, 90 deg incl, 2-3K wob, 10.2 ecd, 40 fph, Drilled to 11,625' 2/8/2009 00:00 - 01:45 1.75 DRILL P PROD1 Drill Z2B lat w/ RSM, 1.6 bpm, 2,700-3600 psi, 90L TF, 90 deg incl, 2-3K wob, 10.2 ecd, 40 fph, Drill to TD ~ 11,741' 01:45 - 02:45 1.00 DRILL P PROD1 POH to window 02:45 - 03:00 0.25 DRILL P PROD1 Log GR tie-in (+14) 03:00 - 04:10 1.17 DRILL P PROD1 RIH tag TD ~ 11749' 04:10 - 07:15 3.08 DRILL P PROD1 POOH to LD drilling BHA, go through window no issue, get above window and open the EDC, pump at 1.9 POOH 07:15 - 07:30 0.25 DRILL P PROD1 SAFETY. MEETING. Review procedure, hazards and mitigation for laying out BHA and M/U new CTC. 07:30 - 08:30 1.00 DRILL P PROD1 Lay out RSM lateral BHA #13. Bit #10 graded at (3,3,1 ). 08:30 - 13:30 5.00 EVAL P PROD1 Cut off 10' coil. M/U Kendal CTC and pull test with 35K. M/U SWS XO and Wet connect for E-Line logging. Test E-Line. Bad test. Cut coil. M/U Kendal CTC, pull test. M/U SWS XO and wet connect. Test E-Line, OK. 13:30 - 13:45 0.25 EVAL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS logging tools with 2 sources. 13:45 - 14:15 0.50 EVAL P PROD1 M/U SWS 2" open hole logging BHA. Test tools. 14:15 - 16:30 2.25 EVAL P PROD1 RIH to 9,000' 16:30 - 20:15 3.75 EVAL P PROD1 Log down to 11,740', 30-60fpm, PR ~ 1 bpm Tool working intermittently due to overheating of the tool 20:15 - 23:15 3.00 EVAL P PROD1 Log up to 9,000', 60fpm, PR C~3 .82 bpm Tool not working, POOH Tight spot ~ 11,442', work through 23:15 - 23:45 0.50 EVAL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for UD SWS logging tools with 2 sources. 23:45 - 00:00 0.25 EVAL P PROD1 UD SWS logging tools with 2 sources. 2/9/2009 00:00 - 01:30 1.50 EVAL P PROD1 UD SWS logging tools with 2 sources. 01:30 - 02:00 0.50 EVAL P PROD1 Prep rig floor for liner run Printed: 3/6/2009 1:43:27 PM BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: E-34 Common Well Name: E-34 Spud Date: 1/5/1994 Event Name: REENTER+COMPLETE Start: 1/30/2009 End: 2/12/2009 Contractor Name: NORDIC CALISTA Rig Release: 2/12/2009 Rig Name: NORDIC 1 Rig Number: Date From - To 'Hours Task I~, Code II NPT Phase I! Description of Operations 2/9/2009 02:00 - 02:15 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U CTC and pumping slack. 02:15 - 08:00 5.75 CASE P RUNPRD Install CTC, Pump slack, cut 30' E-line. Pulled hard on E-line and found bird nest above CTC. Cut 30" coil. M/U CTC and 1 jt. Attempt to pump slack. Coil frozen. RIH thaw coil. Pump slack at max rate at 3.8 bpm, 3 times. Cut off 275' E-Line. Total cut = 305'. 08:00 - 08:15 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for P/U & running 2-3/8" liner 08:15 - 12:45 4.50 CASE P RUNPRD M/U 2-3/8" indexing guide shoe, Flt Cllr, 1 jt 2-3/8" liner, Flt Cllr, 3' pup, Landing Cllr and 44 jts, 2-3/8", 4.43#, STL, L-80 liner with Turbos. Fill liner with water. M/U total of 85 jts, 2-3/8" Liner with BTT Deployment. Liner total length = 2,770.36'. M/U BTT SELBRT, XO, Hyd Disc, XO, 3 jts-2-1/16" CSH, XO, Quick Conn and CTC. BHA OAL = 2868.08'. 12:45 - 14:00 1.25 CASE P RUNPRD RIH with 2-3/8" liner on SELBRT. Circ at 0.2 bpm, 1400 psi. RIH to 9500'. Up wt = 28K RIH thru window clean. 14:00 - 15:10 1.17 CASE P RUNPRD RIH thru open hole at 60 fpm, circ 0.2 bpm, 1400 psi. RIH clean thru build section. RIH at 11000', 10K down wt. RIH at 11300', 8K dwn wt. Sat down at 11359'. Up wt = 38K. Set down several times at 11360'. This is depth where we had a drilling break from 40-90 fph. Work down to 11370'. Work thru and RIH clean thru shales at 1160'. RIH to 11,754'. Pick up and land liner at TD again at 11,754' CTD. Liner is landed at TD. 15:10 - 17:30 2.33 CASE P RUNPRD Launch 5/8" steel ball and displace with GeoVis at 1.5 bpm, 3900 psi. Did not hear ball moving, surge press, no luck. Cic 45 bbls. Ball not on seat. Lauch second ball. hear ball rolling in reel. Displace with GeoVis at 1.6 bpm, 4200 psi. Heard second ball, 10 wraps (300') behind first ball. Slow pump to 0.5 bpm, 2000 psi at 25 bbl. Pump total of 60 bbls behind ball at variuse rates. Did not see ball land. Pick up free from liner at 24K up wt. 17:30 - 20:00 2.50 CEMT P RUNPRD Circ. well to 2% KCL water, double slick. Haul GeoVis to MI plant for reconditioning. Circ. 1.1 bpm at 2900 psi. With KCL to surface, circ at 1.6 bpm with 1.45 bpm returns. 10% fluid loss. Plan on pumping 10 bbl + 2 bbl ex = 12 bbl CMT. 20:00 - 22:00 2.00 CEMT P RUNPRD RU cementers. Cold weather. -41 F, -45WC. 22:00 - 22:15 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for Pumping liner cement job. 22:15 - 23:00 0.75 CEMT P RUNPRD Circ. at 1.6 bpm, 2600 psi, while batch mixing cement to wt. Cement at weight at 2240 hrs. Printed: 3/6/2009 1:43:27 PM • 'BP EXPLORATION Page 9 of 12 Operations. Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 2/9/2009 22:15 - 23:00 23:00 - 00:00 E-34 E-34 Spud Date: 1/5/1994 REENTER+COMPLETE Start: 1/30/2009 End: 2/12/2009 NORDIC CALISTA Rig Release: 2/12/2009 NORDIC 1 Rig Number: I Hours Task I Code I NPT -- 0.75 CEMT P 1.00 CEMT P 2/10/2009 00:00 - 02:00 2.00 CEMT P 02:00 - 02:15 0.25 CEMT P 02:15 - 03:15 1.00 CEMT P 03:15 - 09:00 5.75 CEMT P 09:00 - 10:30 1.501 CEMT ~ P 10:30 - 11:30 I 1.001 CEMT I P 11:30 - 11:45 0.25 CEMT P 11:45 - 13:30 1.75 CEMT P 13:30 - 14:20 I 0.831 CEMT I P 14:20 - 15:15 I 0.921 CEMT I P Phase Description of Operations RUNPRD Press test cement line to 6000 psi with KCL water. RUNPRD Stage 12.0 bbl, 15.8 ppg, G CMT. 1.2 bpm, 2000-2700 psi, 1.0 bpm returns. Isolate cement line. Pump biozan to cement line. Blow down line Zero in/out volume. Stage 35 bbl Biozan displacement. 10 bbl displ, 1.4 bpm, 1.3 bpm returns, 3300 psi. 20 bbl displ, 1.6 bpm, 1.5 bpm returns, 3720 psi 30 bbl displ, 1.6 bpm, 1.4 bpm returns, 3600 psi, Swap to KCL water. 35 bbl displ, 1.5 bpm, 1.3 bpm returns, 3440 psi 38.4 bbl displ, stop pump. pick up 13' from free point, circ 5 bbl to backside of coil. stop pump. open baker choke. RIH to same depth and wt.Close Baker choke. Press up and shear LWP at 2400 psi. pinned for 1800 psi Zero in micro at LWP shear. Liner capacity = 10.47 bbl. Zero out micro with cement at shoe. 2 bbl displ, 1.2 bpm, 1.0 bpm returns, 3550 psi. 5 bbl displ, 1.1 bpm, 1.0 bpm returns, 3450 psi 7 bbl displ, 1.1 bpm, 1.0 bpm returns, 3500 psi 9 bbl displ, 0.9 bpm, 0.85 bpm returns, 3600 psi slow pump to 0.5 bpm 10 bbl displ, 0.5 bpm , 0.4 bpm returns, 2360 psi. Bump LWP at 10.5 bbl displ, hold 3400 psi. good press test. bleed off press and check floats. No flow. Press up to 500 psi and sting out. RUNPRD Pump 2 bbl of bio, POOH while contaminating RUNPRD PJSM for laying down SELBRT and PU cleanout assembly, discuss procedure, hazards and mitigations RUNPRD LD SELBRT BHA, both balls recovered RUNPRD Prep rig floor, RU to run 1"CSH, M/U 1.875" mill, 1-11/16" motor, circ sub, hyd disc, XO, 92 jts of 1"CSH M/U Hyd Disc, check valves, 3jts CSH, XO, Quick Conn and CTC. BHA OAL = 2951.60' RUNPRD RIH with 1.875" mill/motor cleanout BHA #16. Circ at 0.2 bpm, 400 psi. Tag SEBLRT steel profile at 8990' CTD. RUNPRD Mill steel profile at bottom of deployment sleeve. 1.0 bpm, 2200 psi. 3 stalls to get started milling. Total of 6 stalls after 1 hour of very easy milling. milled from 8988.5 -8988.7' and milled thru profile. RUNPRD Ream profile up and down three times. Profile is clean. RUNPRD RIH to cleanout any cement from liner. 1.0 bpm, 1800-2800 psi. Circ new 18 bbl FloPro pert pill to bit while RIH. Tag PBTD on depth at 11,709'. RUNPRD POH while laying in pert pill inside 2-3/8" Liner at 0.5 bpm, 60 fph. RUNPRD POH with 1.875" milling BHA. Printetl: 3/6/2009 1:43:'L/ PM ~ ~ BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: E-34 Common Well Name: E-34 Spud Date: 1/5/1994 Event Name: REENTER+COMPLETE Start: 1/30/2009 End: 2/12/2009 Contractor Name: NORDIC CALISTA Rig Release: 2/12/2009 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/10/2009 14:20 - 15:15 0.92 CEMT P 15:15 - 15:30 0.25 CEMT P 15:30 - 18:00 2.50 CEMT P 18:00 - 18:30 0.50 CEMT P 18:30 - 19:30 1.00 CEMT P 19:30 - 21:10 1.67 CEMT P 21:10 - 21:30 0.33 CEMT P 21:30 - 21:45 0.25 PERFO P 21:45 - 22:45 1.00 CEMT P 22:45 - 23:00 I 0.251 PERFOBI P 23:00 - 00:00 I 1.001 PERFOBI P RUNPRD Circ at 0.9 bpm, 1600 psi. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH and milling BHA. RUNPRD Lay out 40 jts of CSH. Standback 13 stds of CSH. Lay out mill and motor. RUNPRD SAFETY MEETING. Crew change and PJSM for standing back remaining CSH. RUNPRD Stand back 12 stds of 1"CSH. RUNPRD M/U swizzle stick to jet out stack. Jet stack 3.5 bbls/min 2 passes. RUNPRD Break off well and remove swizzle stick. LOWERi SAFETY MEETING. PJSM for loading TCP running equipment to rig floor. RUNPRD Load TCP equipment to floor. Conduct liner lap test. (Cement has reached 1,890 psi compressive) Steady injection pressure of 1,740 psi C~3 0.42 bpm, liner lap has failed. Bleed off pressure and prep rig floor to M/U perf guns. LOWERI SAFETY MEETING. PJSM for running perf guns. Well control and pinch points were discussed. LOWERI M/U perf guns: SWS 1." PJ PERF GUNS & FIRING HEAD, 1/2" BTT HYD DISC, 5/8" BALL SEAT XO, 1-1/4" CSH X 1-1/2" MT 25 stands 1 "CSH, ave 30.88' XO BOT HYD DISC, 3/4" BALL DBPV XO, 2 JTS OF 2-1/16" CSH Tubing BOT X-O, BTT Quick Connect Kendal CTC 2/11/2009 00:00 - 04:30 4.50 PERFOB~ P 04:30 - 07:00 2.50 PERFO P 07:00 - 08:10 I 1.171 PERFOBI P 08:10 - 10:15 I 2.081 PERFOBI P BHA OAL = 2,982.5 ft. LOWERI Continue M/U perf guns as per program. LOWERI Pick up injector, make up CT riser. RIH with SWS 1.56" perf guns. LOWERI Tag PBTD at 11,701' up depth. Correct up depth to 11,709', added 8' CTD. Circ. 8 bbl new FloPro perf pill. Launch 1/2" AL ball and chase with FloPro and KCL water. Heard ball in reel. Locate bottom shot at 11703', just below perf depth. Circ 25 bbl at 1.5 bpm at 3600 psi. Slow pump to 0.5 bpm and circ ball on seat at 34.9 bbl. Guns fired at 3500 psi - Fired guns on depth, on the fly. Good shot detection. No overpull on guns. LOWERI POH while circ. 0.8 bpm, 700 psi. Flow check at 8900'. No Flow. POH. Printed: 3/6/2009 1:43:27 PM BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: E-34 Common Well Name: E-34 Spud Date: 1/5/1994 Event Name: REENTER+COMPLETE Start: 1/30/2009 End: 2/12/2009 Contractor Name: NORDIC CALISTA Rig Release: 2/12/2009 Rig Name: NORDIC 1 Rig Number: I Date ! From - To Hours Task Code NPT ! Phase Description of Operations 2/11/2009 08:10 - 10:15 2.08 PERFO P LOWERI Flow check at surface. No flow. 10:15 - 10:30 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for laying out 1"CSH. 10:30 - 12:30 2.00 PERFO P LOWERI Lay out 52 jts of 1"CSH. 12:30 - 12:45 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for laying out SWS fired pert guns. 12:45 - 18:30 5.75 PERFO P LOWERI Lay out SWS 1.56" fired pert guns and blanks. All shots fired. SWS, 1.56", 6 SPF, 1606PJ CHARGES PERFORATED INTERVALS: 10,350 - 10,850' 11,100 - 11,200' 11,260 - 11,400' 11,600 - 11,700' TOTAL PERFORATIONS = 840'. 18:30 - 18:45 0.25 CASE P RUNPRD SAFETY MEETING: Review procedure, hazards and mitigation for M/U BTT 3-1/2" LT Packer BHA. 18:45 - 20:00 1.25 CASE P RUNPRD M/U BTT 3-1/2" Hyd KB Liner Top Packer with 2-1/4" seal assembly, Hyd release, Hyd Disc, 2 jts 2-1/16" CSH and CTC. BHA OAL = 77.54 20:00 - 22:20 2.33 CASE P RUNPRD RIH with LT Packer BHA. RIH slow at SSSV at 2104', no wt loss across SSSV. RIH at 70 fph. Slow down across 3 GLM's. Circ at 0.2 bpm, 130 psi. 22:20 - 00:00 1.67 CASE P RUNPRD Wt check at 8,920 ft is 24K. RIH with 0.2 bpm, start to sting into deployment sleeve at 8979 ft. Drop pump and continue to sting in another 5 ft to 8984 ft. Pick up and repeat, same results +- 1 ft. Pull up to ball drop position. Drop 5/8" steel ball, launch with 700 psi. Ball is not heard rolling. Move reel up and down. Ball finally heard rolling after 22 bbls away. Ball on seat at 42.4 bbls. Bleed off pressure and sting in to deployment sleeve, set 6K down. Pick up to CT wt then 1 more ft. Pressure up CT to 1800 psi to set slips, then slack down to 6K down on packer. Slips are holding. Bleed off CT pressure slowly, then pick up to neutral wt for PT of packer. PT CT x tbg annulus to 2,000 psi, bleeds to 1,967 psi in 15 min, good test. Bleed off annulus, pressure up CT to 2,700 psi to shear out ball seat and release from packer. POOH. 2/12/2009 00:00 - 01:30 1.50 CASE P RUNPRD POOH. 01:30 - 01:45 0.25 CASE P RUNPRD SAFETY MEETING. PJSM for L/D BHA. 01:45 - 02:20 0.58 CASE P RUNPRD Tag stripper and lay down LTP running BHA. Tool looks normal. Load out BTT equipment. 02:20 - 03:00 0.67 WHSUR P POST Cut off 15 ft of cable and re-boot. M/U freeze protect nozzle + check valves. M/U CT riser. 03:00 - 04:15 1.25 WHSUR P POST RIH to 2,100 ft lay in McOH 60/40 back to 200 ft. Stop at 200 ft and pump McOH to surface. Printed: 3/6/2009 1:43:27 PM ~ ~ BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: E-34 Common Well Name: E-34 Spud Date: 1/5/1994 Event Name: REENTER+COMPLETE Start: 1/30/2009 End: 2/12/2009 Contractor Name: NORDIC CALISTA Rig Release: 2/12/2009 Rig Name: NORDIC 1 Rig Number: Date From - To ~, Hours Task Code NPT Phase Description of Operations 2/12/2009 03:00 - 04:15 1.25 WHSUR P POST Shut down pump and tag up. Shut in swab and pump last McOH in CT to cuttings box. 04:15 - 04:30 0.25 WHSUR P POST SAFETY MEETING. PJSM for setting BPV. 04:30 - 04:50 0.33 WHSUR P POST Set BPV, close swab and master. Start cooling N2 unit down. 04:50 - 05:10 0.33 WHSUR P POST M/U CT injector to wellhead. PJSM for N2 purge of reel. 05:10 - 06:00 0.83 WHSUR P POST Initial PT of N2 line fails, change out chicksan. Use air to purge rig pumps. 06:00 - 07:30 1.50 WHSUR P POST Open up cement line to N2. 07:30 - 07:45 0.25 RIGD P POST 07:45 - 09:45 2.00 RIGD P POST 09:45 - 10:00 0.25 RIGD P POST 10:00 - 13:15 3.25 RIGD P POST 13:15 - 13:30 0.25 RIGD P POST 13:30 - 18:00 4.50 RIGD P POST 18:00 - 18:45 0.75 RIGD P POST 18:45 - 19:00 0.25 RIGD P POST 19:00 - 21:30 I 2.501 RIGD I P I I POST 21:30 - 21:45 0.25 RIGD P POST 21:45 - 23:00 1.25 RIGD P POST 23:00 - 00:00 1.00 RIGD N WAIT POST Start N2 purge at 1800 scfm. Displace coil to N2. Bleed down press to zero. Clean rig pits. SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil stub to reel and securing coil. Install internal grapple, pull test, pull coil to reel. Secure coil on reel. SAFETY MEETING. Review procedure, hazards and mitigation forremoving guide arch and lowering injecter head into pipe bay. Pick and remove guide arch, remove pipe straightener. Pick and lower injecter head into driller side pipe bay. Super suck cuttings tank. Vac KCL from Tiger tank. SAFETY MEETING. Review procedure, hazards and mitigation for N/D BOP stack and N/U tree cap and press test. N/D BOP stack. N/U Tree cap and press test. RELEASED RIG AT 1630 HRS, 02/12/2009. TOTAL OF 12.63 days on the well. Crew change and prep to cut and slip drilling line. Clear rig floor of hoses and cables. SAFETY MEETING. PJSM for cut and slip of drill line. Removing bails, hanging off blocks, and manual handling of cable drum were discussed. Remove bails from block. Hang off block from derrick. Pull new line from cable drum and install cable nut. Wind new cable onto drawworks and secure deadman. SAFETY MEETING. PJSM for pinning ram cylinders. Hand traps and crew positions were discussed. Attach tugger lines to ram cylinders. Extend cylinders and pin bottom of rams. Hook up bridal line to blocks. Prep to lower windwalls. Wait on Doyon 14 rig move on spine road td move Nordic 1. Wait on weather to lower windwalls, wind gust > 20 mph. Change out fluid end on #2 pump while waiting. Last report for this well, all further entries on 05-27 Printed: 3/6/2009 1:43:27 PM ~~~r BAKER N~Il~HE 1NTEt~ North America -ALASKA - BP Prudhoe Bay PB E Pad E-34 -Slot 34 E-34L1 Survey: MWD Baker Hughes INTEQ Survey Report 09 February, 2009 • by pp~~~~~~ B NY~iilS LNTEQ Baker Hughes INTEQ Survey Report bP Company: North America -ALASKA - BP Project: Prudhoe Bay Ske: PB E Pad Well: E-34 Welibore: E-34L1 Design: E-34L1 Local Co-ordinate Reference: Well E-34 -Slot 34 TVD Reference: Mean Sea Level MD Reference: 55:34 1/5/1994 00:00 ~ 64.90ft (generic drilling rig) North Reference: True Survey Calculation Method: .Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES _ _ Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor • Bite PB E Pad, TR-11-14 - - ~~ _ ii Ske Position: Northing: 5,973,160.88 ft Latkude: 70° 19' 59.134 N 'I '~ From: Map Easting: 662,538.97 ft Longitude: 148° 40' 53.054 W Position Uncertainty: 0.00 ft Slot Radius: 0 " Grid Convergence: 1.24 j - ---- -- Weil E-34 -Slot 34, E-34 Well Poskion +N/-S 0.00 ft g. Northin 5,976,895.55 ft Latkude: 70° 20' 35.449 N ~~~ +EI-W 0.00 ft Easting: 664,445.00 ft Longkude: 148° 39' 55.015 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft ---------- Welibore E-34L1 Magnetics Model Name Sample Date Declination Dip Angie Field Strength 1°) lo) (hn bggm2007 2/10/2009 22.85 80.96 57,693 Design E-34L1 - T • Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,532.09 i I VertieaFSection: Depth From (TVD) +NI-S +EI-W Direction fft) Ift) Ift) (°) i -30.00 0.00 0.00 74.73 ' 2/9/2009 3:05:32PM Page 2 COMPASS 2003.16 Build 70 N~~ NYR' F~ffi Baker Hughes INTEQ Survey Report by Company: ° North America -ALASKA - BP Project: Prudhoe Bay Ske: PB E Pad Well: E-34 Wellbore: E-34L1 Design: E-34L1 Survey Program ' Date 2/9/2009 From To (ft) (ft) Survey (Wellbore) Taol Name 200.52 9,532.09 1 : MWD -Standard (E-34) MWD 9,540.00 11,749.00 MWD (E-34L1) MWD ~urvey - - MD lnc Azi ND TVDSS NIS ENy Map N Map E VS DLS ', If~1' 1°I (°I Ifq (ft) (ft) Ift) (ft) (ft) (ft) (°HOOft) 9,532.09 88.41 81.64 8,688.54 8,688.54 770.27 2,190.11 5,977,713.62 666,617.53 2,315.65 0.00 i TIP 1 ~ 9,540.00 88.65 81.76 8,688.74 8,688.74 771.41 2,197.93 5,977,714.93 666,625.33 2,323.50 1 3.39 KOP 9,571.51 81.28 81.88 8,681.51 8,691.51 775.88 2,228.98 5,977,720.07 666,656.27 2,354.63 23.39 9,603.37 73.14 82.00 8,698.55 8,698.55 780.23 2,259.71 5,977,725.10 666,686.90 2,385.42 25.55 8,634.31 64.12 82.32 8,709.82 8,709.82 784.16 2,288.23 5,977,729.65 666,715.32 2,413.97 29.17 ~ 9,663.05 55.08 82.20 8,724.35 8,724.35 787.49 2,312.77 5,977,733.52 666,739.77 2,438.51 31.46 9,693.29 45.58 84.47 8,743.63 8,743.63 790.22 2,335.85 5,977,736.76 666,762.79 2,461.51 31.94 9,725.30 35.14 81.60 8,767.99 8,767.99 792.68 2,356.40 5,977,739.66 666,783.28 2,481.98 33.12 ', 9,756.83 27.80 73.58 8,794.87 8,794.87 796.09 2,372.46 5,977,743.43 666,799.26 2,498.37 26.76 j 9,784.36 22.18 62.90 8,819.83 8,819.83 800.27 2,383.26 5,977,747.85 666,809.96 2,508.89 26.11 9,813.24 20.74 58.43 8,846.71 8,846.71 805.43 2,392.47 5,977,753.21 666,819.06 2,520.13 7.54 9,843.22 I 27.78 70.11 8,874.04 8,874.04 810.60 2,403.58 5,977,758.62 666,830.05 2,532.21 28.32 9,874.18 35.62 76.61 8,900.37 8,900.37 815.15 2,419.17 5,977,763.51 666,845.53 2,548.44 27.59 9,905.62 44.33 81.87 8,924.45 8,924.45 818.83 2,438.99 5,977,767.62 666,865.27 2,568.54 29.70 9,836.38 52.58 81.17 8,944.83 8,844.83 822.23 2,461.74 5,977,771.52 666,887.94 2,591.38 26.871 9,966.64 56.48 68.41 8,962.43 8,962.43 828.74 2,485.42 5,977,778.55 666,911.47 2,615.93 36.64 9,994.38 60.30 57.66 8,977.00 8,977.00 839.47 2,506.40 5,977,789.73 666,932.21 2,639.00 35.74 ~, 10,024.88 64.20 51.17 8,991.21 8,991.21 855.18 2,528.32 5,977,805.92 666,953.77 2,664.28 22.76 10,044.42 67.68 54.97 8,989.18 8,999.18 865.89 2,542.58 5,977,816.94 666,967.79 2,680.86 25.15 '.. 10,073.68 73.51 - 59.89 8,008.90 9,008.90 880.72 2,565.83 5,877,832.27 666,990.71 ___ 2,707.19 25.46 ~I i LocaLCo-ordinate Reference: Well E-34 -Slot 34 ND Reference: Mean Sea Level MD Reference: 55:34 1/5/1994 00:00 @ 64.90ft (generic drilling rig) North deference: True Survey Calculation Methods Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Description MWD -Standard ~I MWD -Standard • 2/9/2009 3:05:32PM Page 3 COMPASS 2003.16 Build 70 ~i.r ~~$ Baker Hughes INTEQ Survey Report by Company: North America -ALASKA - BP total Co-ordinate References Well E-34 -Slot 34 Project: Prudhoe Bay ND Reference: Mean Sea Level Site: PB E Pad MD Reference: 55:34 1/5/1994 00:00 @ 64.90ft (generic drilling rig) Weli: E-34 Morth Reference: True Wellbore: E-34L1 Survey Calculation Method: Minimum Curvature Design: E-34L1 Database: EDM .16 - Anc Prod - WH24P Survey --- -- -- MD Inc Azi TVD TVDSS NIS ENV Map N Map E VS DLS IR) 1°) f°I , Ift) IfU l~1 (ft1 (ft) (ft- (fU < 1°NOOft-;, 9 ~ 10,134.15 85.48 74.46 9,019.48 9,01 .48 904.88 2,619.94 5,977,857.62 667,044.27 2,76576 36.58 ~ • 10,162.01 i 85.75 83.21 9,021.61 9,021.61 910.26 2,647.16 5,977,863.58 667,071.37 2,793.44 31.33 '; 10,194.61 86.74 94.62 9,023.76 9,023.76 910.87 2,679.63 5,977,864.91 667,103.82 2,824.92 35.06 ', '~ 10,224.15 92.55 104.95 9,023.94 9,023.94 905.86 2,708.69 5,977,860.54 667,132.98 2,851.63 40.11 ~ 10,260.83 94.73 103.19 9,021.61 9,021.61 896.96 2,744.19 5,977,852.42 667,168.67 2,883.54 7.63 ', 10,289.23 97.56 99.23 9,018.57 9,018.57 891.47 2,771.88 5,977,847.54 667,196.47 2,908.81 17.07 II 10,319.77 97.05 90.85 9,014.68 9,014.68 888.81 2,802.03 5,977,845.54 667,226.66 2,937.19 I 27.27 10,350.32 92.49 85.92 9,012.14 9,012.14 889.67 2,832.44 5,977,847.07 667,257.05 2,966.76 21.94 10,380.40 92.43 84.88 9,010.85 9,010.85 892.08 2,862.40 5,977,850.14 667,286.94 2,996.29 3.46 10,415.84 88.60 91.68 9,010.22 9,010.22 893.14 2,897.79 5,977,851.98 667,322.30 3,030.71 20.781 10,443.06 88.68 92.03 9,010.63 9,010.63 892.26 2,925.00 5,977,851.69 667,349.51 3,056.72 3.62 ' 10,477.78 89.45 91.82 9,011.19 9,011.19 891.10 2,959.69 5,977,851.29 667,384.22 3,089.89 2.30 ~'i 10,506.76 89.69 90.83 9,011.41 9,011.41 890.43 2,988.66 5,977,851.25 667,413.20 3,117.66 3.52 ', 10,538.64 90.12 90.90 9,011.47 9,011.47 889.95 3,020.54 5,977,851.47 667,445.08 3,148.28 1.37 j i 10,567.11 91.10 89.67 9,011.16 9,011.16 889.80 3,049.01 5,977,851.95 667,473.54 3,175.71 5.52 I'i 10,598.03 90.49 88.27 9,010.73 9,010.73 890.36 3,079.92 5,977,853.19 667,504.43 3,205.67 4.941 10,637.73 88.62 84.96 9,011.04 9,011.04 892.70 3,119.54 5,977,856.40 667,543.99 3,244.51 9.5811 10,667.67 90.15 84.23 9,011.36 9,011.36 895.52 3,149.34 5,977,859.87 667,573.72 3,274.01 5.66 I, 10,696.61 90.40 83.63 9,011.22 9,011.22 898.58 3,178.12 5,977,863.56 667,602.42 3,302.58 2.25 10,730.65 89.17 83.20 9,011.35 9,011.35 902.49 3,211.94 5,977,868.21 667,636.14 3,336.23 3.83 10,758.67 90.95 82.20 8,011.32 9,011.32 906.05 3,239.73 5,977,872.38 667,663.84 3,363.97 7.29 10,786.47 90.31 81.97 9,011.02 9,011.02 909.87 3,267.26 5,977,876.81 667,691.29 3,391.54 2.451 10,816.77 90.46 81.87 9,010.81 9,010.81 914.13 3,297.26 5,977,881.72 667,721.18 3,421.60 0.59 10,847.97 90.28 79.91 9,010.61 9,010.61 919.07 3,328.06 5,977,887.33 667,751.87 3,452.62 6.31 i 10,881.15 90.37 79.40 9,010.42 9,010.42 925.03 3,360.70 5,977,894.01 667,784.37 3,485.68 1.561'1 10,913.59 91.14 79.52 9,010.00 9,010.00 930.96 3,392.59 5,977,900.64 667,816.12 3,518.00 2.40 2/9/2009 3:05.~32PM Page 4 COMPASS 2003.16 Build 70 N.mr ~iieRi+es INTEQ Company: " North America -ALASKA - BP Project: Prudhoe Bay Site: PB E Pad well: E-3a WeHbore: E-34L1 Design: E-34L1 ~ Survey MD Inc Azi ND If~l l°) l°) lfU 10,942.32 90.49 77.50 9,009.59 10,973.05 90.98 78.16 9,009.19 11,005.29 90.86 77.26 9,008.68 11,035.07 90.68 75.92 9,008.28 11,064.31 88.40 75.71 9,008.51 11,094.23 88.43 72.15 9,009.34 11,125.47 88.86 72.40 9,010.08 11,154.61 89.97 72.79 9,010.37 11,185.63 89.91 74.00 9,010.41 11,215.13 90.18 74.92 9,010.38 11,244.66 89.23 75.81 9,010.54 11,273.16 90.18 76.19 9,010.68 11,301.79 90.31 75.69 9,010.56 11,330.92 90.31 75.77 9,010.40 11,363.64 90.06 75.08 8,010.30 11,390.92 90.49 75.01 9,010.17 11,429.44 90.77 76.10 9,009.74 11,462.38 89.45 74.69 9,009.68 11,492.58 89.39 74.68 9,009.98 11,522.20 88.99 74.10 9,010.40 11,552.82 88.86 74.39 9,010.98 11,584.06 88.15 74.16 9,011.79 11,617.78 88.68 75.60 9,012.73 11,649.48 89.17 74.83 9,013.32 11,678.46 88.86 73.28 9,013.82 11,708.36 89.88 73.77 9,014.15 Baker Hughes INTEQ Survey Report by local Co-ordinate Reference: Well E-34 -Slot 34 TVD Reference: Mean Sea Level MD Reference: 55:34 1/5/1994 00:00 @ 64.90ft (generic drilling rig) North Reference: True Survey Calculation Method: ..Minimum Curvature Database: EDM .16 - Anc Prod - WH24P NDSS N13 ENV Map N Map E' VS DLS 1ft) lft) lft) (ft) (ft) (ft) (°/100ft)' 9,009.59 936.69 3,420.74 5,977,906.88 667,844.13 3,546.67 7.39 9,009.19 943.16 3,450.78 5,977,914.11 667,874.02 3,577.35 2.67 • 9,008.68 950.03 3,482.28 5,977,921.66 667,905.35 3,609.54 2.821 9,008.28 956.93 3,511.24 5,977,929.20 667,934.16 3,639.30 4.541 9,008.51 964.10 3,539.59 5,977,936.98 667,962.34 3,668.53 7.83 9,009.34 972.37 3,568.32 5,977,845.89 667,990.88 3,698.44 11.891 9,010.08 981.88 3,598.07 5,977,956.05 668,020.41 3,729.64 1.591 9,010.37 990.60 3,625.87 5,977,965.37 668,048.02 3,758.76 4.041 9,010.41 999.46 3,655.60 5,977,974.88 668,077.54 3,789.77 3.91 9,010.38 1,007.37 3,684.02 5,977,983.41 668,105.78 3,819.27 3.25 ~' 9,010.54 1,014.83 3,712.59 5,977,991.49 668,134.18 3,848.79 4.41 ~, 9,010.68 1,021.72 3,740.24 5,977,998.99 668,161.67 3,877.29 3.59 '', 9,010.56 1,028.68 3,768.02 5,978,006.56 668,189.28 3,905.91 1.80 9,010.40 1,035.86 3,796.25 5,978,014.35 668,217.35 3,935.03 0.271 9,010.30 1,044.09 3,827.91 5,978,023.28 668,248.82 3,967.75 2.24 9,010.17 1,051.13 3,854.27 5,978,030.89 668,275.01 3,995.03 1.60 9,009.74 1,060.74 3,891.57 5,978,041.32 668,312.09 4,033.54 2.92 • 9,009.68 1,069.04 3,923.44 5,978,050.32 668,343.77 4,066.48 5.86 !, 9,009.98 1,077.02 3,952.57 5,978,058.93 668,372.72 4,096.68 0.201 9,010.40 1,084.99 3,981.09 5,978,067.52 668,401.06 4,126.29 2.38 9,010.98 1,093.30 4,010.56 5,978,076.48 668,430.33 4,156.91 1.04 9,011.79 1,101.77 4,040.62 5,978,085.60 668,460.20 4,188.14 2.39 ~ 9,012.73 1,110.56 4,073.16 5,978,095.10 668,492.53 4,221.84 4.55 1 9,013.32 1,118.65 4,103.80 5,978,103.86 668,522.99 4,253.53 2.88 9,013.82 1,126.61 4,131.66 5,978,112.43 668,550.67 4,282.51 5.45 ' 9,014.15 1,135.08 4,160.33 5,978,121.54 668,579.14 4,312.40 3.78 2/9/2009 3:05:32PM Page 5 COMPASS 2003.16 Build 70 Nay ~~~ Baker Hughes INTEQ Survey Report by INTEQ Company: North America -ALASKA - BP Project: :Prudhoe Bay Site: PB E Pad Well: E-34 Wellbore: E-34L1 Design: E-34L1 Survey Local Co-ordinate Reference: Well E-34 -Slot 34 TVD Reference: Mean Sea Level MD Reference: 55:34 1/5/1994 00:00 @ 64.90ft (generic drilling rig) North Reference:. True .Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P MD Inc Azi TVD TVDSS N/S EIW Map N Map E VS DLS Ift) 1°1 (°- tft Iftl l~tl (~1 (~1 lftl Ift1 (°nooft- 11,749.00 89.88 73.77 9,014.23 9,014.23 1,146.44 4,199.35 5,978,133.75 668,617.90 4,353.03 0.00 TD - 2.375" _.. _ __ - --- - -- -- -- _ -_ _ _ _ _ _ - - _J 2/9/2009 3:05:32PM Page 6 COMPASS 2003.16 Build 70 _~~~ ~~~ Baker Hughes INTEQ Survey Report INTEQ by Company: North America -ALASKA - BP Local Co-ordinate Reference: Well E-34 -Slot 34 ?Project: Prudhoe Bay `TVD Reference: Mean Sea Level Site: PB E Pad MD Reference: 55:34 1/5/1994 00:00 @ 84.90ft (generic drilling rig) Weli: E-34 North Reference: True Wellbore: E-34L1 Survey Ca{culation MBN~od: Minimum Curvature Design: E-34L1 Database: EDM .16 - Anc Prod - WH24P Targets -- - --- Target Name - hWmiss target Dip Angle Dip Dir. ND +N/-S +EI-W Northing Fasting -Shape 1°I 1°) Ift1 Ift- IfU (~) Ift) Latitude Longitude ~ E-34A Target 2 0.00 0.00 9,004.00 1,133.82 4,148.16 5,978,120.00 668,567.00 70° 20' 46.589 N ,, 148° 37' 53.811 W - survey misses target center by 10.32ft at 11696.22ft MD (9014.08 TVD, 1131.67 N, 4148.68 E) - Point E-34A Fault 2 0.00 0.00 0.00 1,299.08 3,454.57 5,978,270.00 667,870.00 70° 20' 48.218 N 148° 38' 14.074 W - survey misses target center by 8793.07ft at 9571.51ft MD (8691.51 TVD, 775.88 N, 2228.98 E) - PolY9on Point 1 0.00 1,299.08 3,454.57 5,978,270.00 667,870.00 ~I Point2 0.00 1,250.42 3,848.62 5,978,230.00 668,265.00 ', E-34A Polygon 0.00 0.00 0.00 969.39 2,752.12 5,977,925.00 667,175.00 70° 20' 44.978 N 148° 38' 34.603 W - survey misses target center by 8708.65ft at 9540.OOft MD (8688.74 TVD, 771.41 N, 2197.93 E) - Polygon Point 1 0.00 969.39 2,752.12 5,977,925.00 667,175.00 Point2 0.00 1,134.24 3,901.09 5,978,115.00 668,320.00 Point 3 0.00 1,244.78 4,333.65 5,978,235.00 668,750.00 Point4 0.00 1,069.04 4,364.81 5,978,060.00 668,785.00 Point 5 0.00 810.53 3,153.76 5,977,775.00 667,580.00 Point6 0.00 828.97 2,769.05 5,977,785.00 667,195.00 ~ E-34A Target 1 0.00 0.00 9,004.00 893.85 - survey misses target center by 14.32ft at 10294.43ft MD (9017.89 TVD, 890.70 N, 2776.98 E) - Point E-34A Fault 3 0.00 0.00 0.00 907.43 - survey misses target center by 8967.64ft at 9603.37ft MD (8698.55 TVD, 780.23 N, 2259.71 E) - Polygon Point 1 0.00 907.43 Point 2 0.00 1,037.03 2,775.47 5,977,850.00 667,200.00 70° 20' 44.235 N 148° 38' 33.922 W 4,436.28 5,977,900.00 668,860.00 70° 20' 44.361 N 148° 37' 45.396 W 4,436.28 5,977,900.00 668,860.00 4,684.20 5,978,035.00 669,105.00 2,244.24 5,977,790.00 666,670.00 70° 20' 43.761 N 148° 38' 49.443 W \J E-34A Fault 1 0.00 0.00 0.00 845.49 - survey misses target center by 8689.04ft at 9532.09ft MD (8688.54 TVD, 770.27 N, 2190.11 E) - Polygon Point 1 0.00 845.49 Point 2 0.00 824.24 Point 3 0.00 782.02 Point 4 0.00 824.24 2,244.24 5,977,790.00 666,670.00 2,528.87 5,977,775.00 666,955.00 3,313.18 5,977,750.00 667,740.00 2,528.87 5,977,775.00 666,955.00 2/9/2009 3:05:32PM Page 7 COMPASS 2003.16 Build 70 N.t/ g~ R FN18~s b Baker Hughes INTEQ Survey Report y INTEQ Company: North America -ALASKA - BP Local C©-ordinate Reference:: Well E-34 -Slot 34 Project: Prudhoe Bay TVD Reference: Mean Sea Level Ske: PB E Pad MD Reference: 55:34 1/5/1994 00:00 @ 64.90ft (generic drilling rig) Well: E-34 Morth Reference: True Weilbore: E-34L1 Survey Calculation Method: ' Minimum Curvature Design: E-34L1 patataase: EDM .16 - Anc Prod - WH24P Casing Points _ ! I Measured:.. . Vertical Casing Hole '' ~~ Depth: .. Depth Diameter biameter 1111 Ift1 Name 1"1 l"1 ' 11,749.00 9,014.23 2.375^ 3 2-3/8 Survey Annotations Measured ' vertlcai Local Coordinates Depth Depth +N/-S +EI•W ' (ft1 lft) (ft) ' (ft) ' ` Comment 9,532.09 8,688.54 770.27 2,190.11 TIP 9,540.00 8,688.74 771.41 2,197.93 KOP 11,749.00 9,014.23 1,146.44 4,199.35 TD ' Checked By: Approved By: Date: 2/9/2009 3:05:32PM Page 8 COMPASS 2003.16 Build 70 ~`~ ~ E.~ ALA5SA OIL A1~TD GrAS CO1~T5ER~"ATIOI~T COMl-II55IOI~T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-34L1 BP Exploration Alaska Inc. Permit No: 208-178 Surface Location: 168' FNL, 500' FEL, SEC. 06, T11N, R14E, UM Bottomhole Location: 958' FSL, 3647' FWL, SEC. 32, T12N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well PBU E-34, Permit No 193- 202, API 50-029-22439-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining. additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, Cathy . Foerster Commissioner S~ DATED this day of November, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~o STATE OF ALASKA "'°-`"° ALAS~OIL AND GAS CONSERVATION COMMON ~j~ !~°` -~1 - PERMIT TO DRILL ~,~~ 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193. 11. Well Name and Number: PBU E-34L1 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Proposed Depth: MD 11690' TVD 9003' ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 168' FN ' FE E E 7. Property Designation: ADL028304, ADL028299 Pool L, 500 L, S C. 06, T11N, R14 , UM Top of Productive Horizon: 576' FSL, 1507' FWL, SEC. 32, T12N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 15, 2008 Total Depth: 958' FSL, 3647' FWL, SEC 32, T12N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 5100' 4b. Location of Well (State Base Plane Coordinates): Surface: x-664445 y-5976895 Zone-ASP4 10. KB Elevation (Height above GL): 64.95' feet 15. Distance to Nearest Well Within Pool: 1100' 16. Deviated Wells: Kickoff Depth: 9565 feet Maximum Hole An le: 94.87 d reel 17. Maximum Anticipated Pressures in prig (see 20 AAC 25.035) Downhole: 3186 Surface: 2306 1 P r cifi ions T in D th - Bo om n' f m n .f. r sa s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data - / " 4.4# L- T 1 0' 9003' ss 7 x I ' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (tt): 10742 Total Depth TVD (ft): Plugs (measured): 27 None Effective Depth MD (ft): 10742 Effective Depth TVD (tt): 8727 Junk (measured): None Casing Len th Size Cement Volume MD TVD Conductor /Structural Ar i A r 1 1' ' Surface 1- 4" 1 x PF ' 7 x l 6' Intermediate Pr i T - / " I ' Liner 1 1 n in r 4'- 1 7' 77' - 727' Perforation Depth MD (ft): Slotted Liner 9214' - 10718' Perforation Depth TVD (tt): Slotted Liner 8698' - 8736' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoin is true and correct. Printed Name John ull Si nature < • Contact Ron Phillips, 564-5913 Title En ineerin Team Leader Prepared ey Name/Number. Phone ~Y ~ ~ Date ( 7e~ Sondra Stewman, 564-4750 Commission Use Onl Permit To Drill Nu r• 0708/~~ API Number: 50-029-22437-60-00 Permit Approval ~ - See cover letter for h n Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me_th/ane, gas hydrates, or gas contained shales: ~/ Samples Req'd: ^ Yes L~0 No Mud Log Req'd: ^~ es L~ No ` HZS Measures: [Yes ^ No Directional Survey Req'd: Q Yes ^ No Other: ~j~ ~ [~ S ~ `J~ ~ "~ ~-5~ \1c, ~ ~ ,,, / APPROVED BY THE COMMISSION -21- Date ~~~i7~+'"" ~`c.v-~. COMMISSIONER Form 10-401 Revised 12!2005 ~ -~` F _ _ _ w~ . _ _., . Submit m uupucate To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ron Phillips, CTD Engineer Date: November 12, 2008 RE: E-34L1 Permit to Drill Request The E-34L1 is scheduled to be drilled by Nordic 1 around January 15, 2009. The plan calls for a slimhole lateral with a solid cemented liner in Zone 2B. BP's intent is not to produce from the Sag River again. The cement in the Ivishak lateral and the liner top packer at 8990' will isolate the Ivishak from the Sag River formation. Cement will not be brought back up to the whip stock to preserve the option to cut and pull the tubing and sidetrack at a later date. Pre-Rig Work: 1. Dummy GLV's 2. PDS Caliper Tubing. 3. MIT-IA 4. MIT-OA. 5. Mill XN at 9077' to 2.74" with left handed motor, mill. 6. Dummy whipstock drift for 3-1/2" x 4-1/2" thru tubing WS to 9600' (89 deg inch 7. AC-LDS; AC-PPPOT- T. 8. Test MV, SV, WV. 9. Install BPV. 10. Bleed gas lift and production flowlines down to zero and blind flange. 11. Remove wellhouse, level pad. The pre CTD work is slated to begin on December 1, 2008. Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high, Pull BPV 2. Set 3-1/2" x 4-1/2" through tubing whipstock @ 9565'. 3. Mill 2.74" window at 9565' and 10' of openhole. Swap the well to Flo-Pro. 4. Drill build/turn section with 3" bicenter bit, and land well. 30 deg/100 (plan #5) 5. Drill lateral section with 3" bicenter bit to TD at 11690'. 12 deg/100 (plan #5) 6. Run a triple combo open hole log. 7. Run 2-3/8" solid cemented liner leaving TOL at 9000'. 8. Pump primary cement job up to 9765', 7.7 bbl of 15.8 ppg cmt planned. 9. Run CO assembly. 10. Perforate 800' at 6spf. 11. Run a turned down liner top packer. 12. Freeze protect well, Set BPV, RDMO. Post-Rig Work: 1. Pull BPV 2. Re-install wellhouse and FL's. 3. Generic GLV design. 4. Flow well to portable test separator. Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2 3/8", 4.4#, L-80, STL liner: 11690'-9000' MD. • 7.7 bbls 15.8 ppg cement will be used to cement the liner. • TOC planned at 9765', left 200' outside of window for future sidetrack option. Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan #5. Max. planned hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 5,100' to the North. • Distance to nearest well within pool - 1100' ft to E-OIA. Anticollision Summary • With Global Scan applied, anti-collision analysis revealed no close approach issues. Logging • MWD directional, Gamma Ray and Resistivity will be run over the open hole section while drilling. Triple combo E-line logs (Gamma Ray, Neutron, Density and Resistivity) will be run in the open hole. Hazards The maximum recorded H2S level on E-Pad is 120 ppm on E-102. One small fault will be crossed in zone 2 at approximately 10,040' near the landing point. This area of the field has low risk of losses. Reservoir Pressure • Res. press. is estimated to be 3,186 psi at 8,800'ss (6.96 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2306 psi. Ron Phillips CTD Drilling Engineer 564-5913 CC: Well File Sondra Stewman/Terrie Hubble TREE = CNV E-34 S NOTES: HORIZONTAL WELL WELLHEAD = ACTUATOR= FMC BAKER KB. ELEV = 65.0' BF. ELEV = 30.20' KOP _ 4287 Max Angle = 113 @ 10742' Datum MD = WA Datum TVD = 8800' SS 10-3/4" CSG, 45.5#, J-55, ID = 9.953" I I 3664' 1 Minimum ID = 2.635" @ 9077' 3-1 /2" SWN NO GO NIPPLE 2104' ~~ 3-1/2" OTIS SSSV LANDING NIP, ID = 2.75" SAS I IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4247 4174 10 MMG DMY RK 0 09/25/04 2 7021 8793 19 MMG DMY RK 0 09/25/04 1 8280 7984 18 MMG DMY RK 0 9004' - -j 3-1/2" PARKER SWS NIP, ID = 2.75" 9030' 7-5/8" X 3-1/2" BAKER SABL-3 PERM PKR, ID = 3.874" 9054' ~ 3-1/2" PARKER SWS NIP, ID = 2.75" 9077' 3-1/2" SWN NO GO NIP, ID = 2.835" 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" ~-I 9090' TOP OF 4-1/2" LNR I-I 9146' 9090' -j3-1/2" WLEG 90$$' ELMD TT LOGGED 02/04/94 9146' 7-5/8" X 4-1/2" TNV PKR W/ SCOOP HEAD 9174' ~-I PORTED PIPE 7-5/8" CSG, 29.7#, ID = 8.875" ~ 9360' I I ~ I I I I I I I I I I I I I I I ~ I ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4-1/2" SLTD LNR, 12.8#, NT-80, .0152 bpf, ID = 3.953" I-I 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 01!26/94 ML ORIG HORIZ COMPLETION 09/06/01 RN/TP CORRECTIONS 07/12/03 CMO/TLP KB ELEVATION, MAX ANGLE 09/17/03 CMO/TLP DATUM MD & LOCATION 10/20/04 CAO/TLH GLV GO PRUDHOE BAY UNff WELL: E-34 PERMfT No: 1932020 API No: 50-029-22437-00 SEC 6, T11 N, R14E, 188' FNL & 500' FEL BP Exploration (Alaska) TREE _~ CNV WELLHEAD= FMC ACTUATOR= BAKER KB. ELEV = 65.0' BF. ELEV = 30.20' KOP = 4287' Max Angk: = 113 ~ 10742' Datum MD = WA Datum TV D = 880Q' SS SAFEIY NOTES: HORIZONTAL WELL '~ ~~~~~ Proposed CTD Lateral O 10-3/4" CSG, 45.5#, J-55, ID = 9.953" 3664' 2104' ~--3-1/2" OT1S SSSV LANDING NIP, ID= 2.75" CHAS I IFf MANDRELS Minimum ID = 2.635" ~ 9077' 3-1/2" SWN NO GO NIPPLE Liner Top Packer 8990' TOP OF 2-3/8" LNR 9000' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4247 4174 10 MMG DMY RK 0 09/25/04 2 7021 6793 19 MMG DMY RK 0 09/25/04 1 8280 7984 18 MMG DMY RK 0 9004' ~3-i/Z" PARKER SWS NIP, 10 = 2.75" 90$0' 7-5/8" X 3-1/2" BAKER SA BL-3 PERM PKR, ID = 3.874" 9054' 3-1/2" PARKER SWS NIP, ID = 2.75" 9077' 3-1/2" SWN NO GO NIP, ID mlled to = 2.74" 3-112" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" ~-{ 9090' I TOP OF 4-1/2" LNR ~--~ 9146' ~ I I I 7-5/8" CSG, 29.7, ID = 6.875" 9360' I '. I I I I I I I I I I I 9565' ~-~ Mill Window off Mechanical Whipstock 4-1/2" SLTD LNR, 12.6#, NT-80, .0152 bpf, ~= 3.953" I I I I I I I I I I I I I I I I I I I 1 I I I I I I I I -~ 10742' 9090' 3-i/2" WLEG 9Q$$' 1 ELMD TT LOGGED 02/04/94 9146' ~-~7-5/8" X 4-1/2" TAN PKR W! SCOOP HEAD 9174' I~ PORTED PIPE 9765' I~TOC 2-3/8" Liner, Cemented & Perfd ~--~ 11690' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/26/94 ML ORIG HORIZ COMPLETION 09/06/01 RNRP CORRECTIONS 07/12/03 CMO/TLP KB ELEVATION, MAX ANGLE 09/17/03 CMO/TLP DATUM MD 8 LOCATION 10/20/04 CAO(TLH GLV GO 10/22/08 MSE PROPOSED CTD Lateral PRUDHOE BAY UNfr WELL: E 34A PERMII" No: API No: 50-029-22437-61 SEC 6, T11 N, R14E, 168' FNL &500' FEL BP Exploration (Alaska) • • are rrom i N ~_ of bag . - . - BAG Dowell of blind/shears Blind/Shears fiddle of pipes 2" combi pipe/slips TOTs Mud Cross I I Mud Cross cross rams 2 3/8" x 3 1/2" VBR's middle of pipe/slips 2" combi pipe/slips alv TOTs Flow Tee bP ~ BP Alaska Baker Hughes INTEQ Planning Report ~r.~r a'-s 1NTGQ ': Company:. 'BP Amoco ~-- Date: :10/31/2008 Time: ib39:07 Page: 1 .'.Field: Prudhoe Bay. Co-ordinate(NE) Reference: Well: E-34, True North .Site: PB E Pad Vertical (TVD) Reference:. 55 :34 1/5/1994 00:00 64:9 We1L E-34 Section (VS) Reference: Welt (O.OON,O.OOE,85.OOAzi) Welipath: Plan 5, E-34A Survey Calculation Method: Minimum Curvature Db: Sybase i Field: Prudhoe Bay I~ North Slope i, UNITED STATES i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 - -- -- ' Site: PB E Pad -- - ~ TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973160. 88 ft Latitude: 70 19 59.134 N From: Map Easting: 662538. 97 ft Longitude: 148 40 53.054 W Position Uncertainty: 0.00 ft North Reference: True ', Ground Level: 0.00 ft Grid Convergence: 1.24 deg I~ Well: E-34 Slot Name: 34 ~~ E-34 Well Position: +N/-S 3692.74 ft Northing: 5976895. 55 ft Latitude: 70 20 35.449 N +E!-W 1986.65 ft Easting : 664445. 00 ft Longitude: 148 39 55.015 W Position Uncertainty: 0.00 ft -- --- ~, -- _ _- - Wellpath: Plan 5, E-34A - - - E-34 Drilled From: '~ 500292243701 Tie-on Depth: 9564.56 ft ~ Current Datum: 55:34 1 /5/1994 00:00 Hei ght 64. 90 ft Above System Datum: Mean Sea Level Magnetic Data: 10/23/2008 Declination: 23.00 deg '~ Field Strength: 57685 nT Mag Dip Angle: 80.95 deg ', j Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ' ~ ft ft ft deg -- 34.90 0.00 0.00 85.00 ~' Plan: Plan #5 Date Composed: 10/23/2008 ~I copy Sean's plan 5, kop change Version: 8 Principal: Yes Tied-to: From: Definitive Path Targets __ __ -- Map Map <---- Latitude ----> <--- Longitude ..> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Din. ft ft' ft ft ft _--,I' ~ E-34A Polygon 64.90 969.39 2752.12 5977925.00 667175.00 70 20 44.978 N 148 38 34.603 W ' -Polygons 64.90 969.39 2752.12 5977925.00 667175.00 70 20 44.978 N 148 38 34.603 W -Polygon 2 64.90 1134.24 3901.09 5978115.00 668320.00 70 20 46.594 N 148 38 1.030 W -Polygon 3 64.90 1244.78 4333.65 5978235.00 668750.00 70 20 47.679 N 148 37 48.389 W -Polygon 4 64.90 1069.04 4364.81 5978060.00 668785.00 70 20 45.950 N 148 37 47.482 W -Polygon 5 64.90 810.53 3153.76 5977775.00 667580.00 70 20 43.414 N 148 38 22.870 W -Polygon 6 l 64.90 828.97 2769.05 5977785.00 667195.00 70 20 43.597 N 148 38 34.110 W ~ E-34A Fault 1 i 64.90 845.49 2244.25 5977790.00 666670.00 70 20 43.761 N 148 38 49.443 W lip l ~ -Polygon 1 64.90 845.49 2244.25 5977790.00 666670.00 70 20 43.761 N 148 38 49.443 W -Polygon 2 64.90 824.24 2528.87 5977775.00 666955.00 70 20 43.551 N 148 38 41.128 W -Polygon 3 64.90 782.02 3313.19 5977750.00 667740.00 70 20 43.133 N 148 38 18.212 W '. -Polygon 4 64.90 824.24 2528.87 5977775.00 666955.00 70 20 43.551 N 148 38 41.128 W ' I E-34A Fault2 64.90 1299.08 3454.57 5978270.00 667870.00 70 20 48.218 N ' 148 38 14.074 W -Polygon 1 64.90 1299.08 3454.57 5978270.00 667870.00 70 20 48.218 N 148 38 14.074 W -Polygon 2 64.90 1250.42 3848.63 5978230.00 668265.00 70 20 47.737 N 148 38 2.561 W E-34A Fault 3 64.90 907.43 4436.29 5977900.00 668860.00 70 20 44.361 N 148 37 45.396 W -Polygon 1 64.90 907.43 4436.29 5977900.00 668860.00 70 20 44.361 N 148 37 45.396 W ~ -Polygon 2 64.90 1037.03 4684.21 5978035.00 669105.00 70 20 45.634 N 148 37 38.150 W E-34A Target 1 9068.90 893.85 2775.47 5977850.00 667200.00 70 20 44.235 N 148 38 33.922 W E-34A Target 2 9068.90 1133.82 4148.16 5978120.00 668567.00- 70 20 46.589 N 148 37 53.811 W S BP Alaska ~! by Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Date: 10!31/2008 Time: t5:39:07 Page:. 2 ~i Field: Prudhoe Bay. Co-ordinate(NE) Reference: Weil: E-34, True North Site: PB E Pad Vertical (TVD) Reference: 55:34 1/5!1994 00:00 64.9 Well: E-34 Section(VS)Reference: Well (O.OON,O.OOE,85.OOAzi) Wellpath; Plan 5, E-34A Survey Calculation Method: Minimum Curvature Db: Sybase ~ Annotation MD TVD ft ft 9564.56 8754.06 _ TIP 9565.00 8754.07 KOP 9585.00 8754.59 End of 9 Deg/100' DLS 9843.00 8911.56 4 10108.00 9068.95 End of 30 Deg/100' DLS 1 10178.00 9068.98 6 : 10283.00 9068.55 7 '...10483.00 9068.32 8 ', 10733.00 9068.29 9 10983.00 9068.26 10 11233.00 9068.24 11 11490.00 9068.22 12 11690.00 9068.20 TD Plan Section Information - _. MD Intl- Azim _ TVD ___ +N!-S +E/-W DLS Build 'turn TFO ft deg deg ft ft ft deg/1OOft deg/iOOft deg/1OOft deg 9564.56 89.39 82.13 8754.06 774.85 2222.24 0.00 0.00 0.00 0.00 9565.00 89.41 82.13 8754.07 774.91 2222.68 4.55 4.55 0.00 360.00 ~ 9585.00 87.61 82.13 8754.59 777.65 2242.48 9.00 -9.00 0.00 180.00 9843.00 10.21 82.13 8911.56 802.30 2420.79 30.00 -30.00 0.00 180.00 110108.00 89.61 74.26 9068.95 849.23 2601.56 30.00 29.96 -2.97 352.00 10178.00 90.35 82.63 9068.98 863.23 2670.08 12.00 1.05 11.95 85.00 10283.00 90.12 70.03 9068.55 887.99 2771.90 12.00 -0.22 -12.00 269.00 110483.00 90.01 94.03 9068.32 915.51 2968.53 12.00 -0.06 12.00 90.25 i 10733.00 90.01 64.03 9068.29 962.52 3211.17 12.00 0.00 -12.00 270.00 10983.00 90.01 94.03 9068.26 1009.53 3453.81 12.00 0.00 12.00 90.00 111233.00 90.01 64.03 9068.24 1056.55 3696.45 12.00 0.00 -12.00 270.00 11490.00 90.00 94.87 9068.22 1103.02 3946.07 12.00 0.00 12.00 90.00 ''~, 11690.00 90.00 70.87 9068.20 1127.65 4143.08 12.00 0.00 -12.00 270.00 Target - - Survey MD Inc!' Azim `SSTVD N/S F/W MapN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft deg/100ft ft deg 9564 .56 89.39 82.13 8689.16 774. 85 2222.24 5977718.90 666649.56 0.00 2281 .32 0.00 MWD 9575 .00 88.51 82.13 8689.35 776. 28 2232.58 5977720.56 666659.86 8.43 2291 .75 180.00 MWD 9585 .00 87.61 82.13 8689.69 777. 65 2242.48 5977722.15 666669.73 9.00 2301 .73 180.00 MWD 9600 .00 83.11 82.13 8690.90 779. 70 2257.29 5977724.52 666684.49 30.00 2316 .66 180.00 MWD 9625 .00 75.61 82.13 8695.52 783. 06 2281.61 5977728.41 666708.73 30.00 2341 .18 180.00 MWD 9650 00 68 11 82.13 8703. 29 786.31 2305.13 5977732.18 666732.16 30 .00 2364.89 180.00 MW D I . 9675.00 . 60. 61 82. 13 8714. 10 789.40 2327.44 5977735.75 666754.40 30 .00 2387.38 180.00 I MWD, 9700.00 53. 11 82. 13 8727. 76 792.26 2348.16 5977739.07 666775.05 30 .00 2408.28 180.00 MWD 9725.00 45. 61 82. 13 8744. 03 794.86 2366.94 5977742.07 666793.77 30 .00 2427.21 180.00 MWD; 9750.00 38. 11 82. 13 8762. 64 797.14 2383.45 5977744.72 666810.23 30 .00 2443.86 180.00 MWD 1 9775.00 30. 61 82. 13 8783. 26 799.07 2397.42 5977746.95 666824.15 30 .00 2457.94 180.00 MWD j 9800.00 23. 11 82. 13 8805. 55 800.61 2408.60 5977748.74 666835.29 30 .00 2469.21 180.00 MWD 9825.00 15. 61 82. 13 8829. 12 801.75 2416.80 5977750.06 666843.47 30 .00 2477.48 180.00 MWD 9843.00 10. 21 82. 13 8846. 66 802.30 2420.79 5977750.70 666847.43 30 .00 2481.50 180.00 MWD 9850.00 12. 29 80. 76 8853. 52 802.50 2422.14 5977750.93 666848.78 30 .00 2482.86 352.00 MWD 9875.00 19. 76 78. 19 8877. 53 803.80 2428.91 5977752.37 666855.52 30 .00 2489.72 353.35 MW D Iii 9900.00 27. 25 77. 00 8900. 44 805.95 2438.64 5977754.74 666865.20 30 .00 2499.60 355.82 MWD' 9925.00 34. 74 76. 29 8921. 86 808.93 2451.15 5977757.99 666877.64 30 .00 2512.33 356.91 MWD, 9950.00 42. 23 75. 81 8941. 41 812.68 2466.24 5977762.07 666892.64 30 .00 2527.68 357.52 MWD; 9975.00 49 .73 75. 45 8958. 77 817.14 2483.64 5977766.92 666909.94 30 .00 2545.41 357.90 MWD; 10000.00 57 .22 75. 17 8973. 64 822.24 2503.06 5977772.43 666929.24 30 .00 2565.20 358.15 MWD 10025.00 64 .72 74. 92 8985. 76 827.88 2524.16 5977778.53 666950.22 30 .00 2586.71 358.32 MWD 10050.00 72 .22 74. 71 8994. 93 833.96 2546.59 5977785.11 666972.50 30 .00 2609.58 358.44 MWD 10075.00 79 .72 74. 51 9000. 99 840.40 2569.96 5977792.05 666995.72 30 .00 2633.42 358.52 MWD 1 BP Alaska by Baker Hughes INTEQ Planning Report ~T~Q i Company; BP Amoco ---------- -- --- Date: 10/31!2008 Time: 15:39:07 Page: 3 j Field: Prudhoe Bay Co-ordinate(NE)Reference:- Well: E-34, True North I Site: PB E Pad Vertical{TVDJReference: 55 : 34.1/5!1994 00:00 64.9 ~ Well E-34 (VS)`Reference: Secti i ' Well {O.OON,O.OOE,85.OOAzi) p Well ath: Plan 5, E-34A Surve Calculation Method• Y Minimum Curvature Db• S base ~ y Survey ', MD Inch Azim SS TVD ft deg deg ft 10100. 00 87. 21 74.32 9003. 83 10108. 00 89. 61 74.26 9004. 05 10125. 00 89. 79 76.30 9004. 14 'i 10150. 00 90. 05 79.29 9004. 18 ~' 10175. 00 90. 32 82.27 9004. 10 I i 10178. 00 90. 35 82.63 9004. 08 10200. 00 90. 30 79.99 9003. 96 10225. 00 90. 25 76.99 9003. 84 10250. 00 90. 19 73.99 9003. 74 10275. 00 90. 14 70.99 9003. 67 10283. 00 90. 12 70.03 9003. 65 10300. 00 90. 11 72.07 9003. 62 10325. 00 90. 10 75.07 9003. 57 i 10350. 00 90. 08 78.07 9003. 53 i 10375 .00 90. 07 81.07 9003. 50 10400. 00 90. 06 84.07 9003. 47 10425. 00 90. 04 87.07 9003. 45 10450. 00 90. 03 90.07 9003. 43 i 10475. 00 90. 01 93.07 9003. 43 t 10483. 00 90. 01 94.03 9003. 42 10500 .00 90. 01 91.99 9003. 42 I~ 10525 .00 90. 01 88.99 9003. 42 10550 .00 90. 01 85.99 9003. 42 ~i, 10575 .00 90. 01 82.99 9003. 41 10600 .00 90. 01 79.99 9003. 41 10625 .00 90. 01 76.99 9003. 40 10650 .00 90. 01 73.99 9003. 40 10675 .00 90. 01 70.99 9003. 40 10700 .00 90. 01 67.99 9003. 40 10725 .00 90. 01 64.99 9003. 39 ' 10733 .00 90. 01 64.03 9003. 39 ', 10750 .00 90. 01 66.07 9003. 39 I, 10775. 00 90. 01 69.07 9003. 39 'I 10800 .00 90. 01 72.07 9003. 38 ' 10825 .00 90. 01 75.07 9003. 38 10850 .00 90. 01 78.07 9003. 38 ' 10875 .00 90. 01 81.07 9003. 37 10900 .00 90. 01 84.07 9003. 37 10925 .00 90. 01 87.07 9003. 37 10950 .00 90. 01 90.07 9003. 37 10975 .00 90. 01 93.07 9003. 36 10983 .00 90. 01 94.03 9003. 36 ' 11000 .00 90. 01 91.99 9003. 36 11025 .00 90. 01 88.99 9003. 36 11050 .00 90. 01 85.99 9003. 36 ' 11075 .00 90. 01 82.99 9003. 35 847.06 849.23 853.55 858.83 862.84 863.23 866.56 871.54 877.80 885.32 887.99 893.51 900.58 906.38 910.91 914.14 916.07 916.69 916.00 915.51 914.61 2593.86 2601.56 2618.00 2642.43 2667.11 2670.08 2691.83 2716.32 2740.52 2764.36 2771.90 2787.98 2811.96 2836.27 2860.86 2885.64 2910.57 2935.56 2960.54 2968.53 2985.50 914.40 915.49 917.89 921.58 926.57 932.83 940.35 949.11 959.08 962.52 969.69 979.23 987.54 994.61 1000.41 1004.94 1008.17 1010.09 1010.72 1010.03 1009.53 1008.64 1008.42 1009.52 1011.92 3010.50 3035.47 3060.36 3085.08 3109.57 3133.77 3157.61 3181.03 3203.95 3211.17 3226.58 3249.69 3273.26 3297.24 3321.56 3346.14 3370.93 3395.85 3420.84 3445.83 3453.81 3470.79 3495.78 3520.76 3545.64 11100.00 90.01 79.99 9003.35 1015.61 3570.36 11125.00 90.01 76.99 9003.35 1020.60 3594.86 11150.00 90.01 73.99 9003.35 1026.86 3619.06 11175.00 90.01 70.99 9003.34 1034.38 3642.90 11200.00 90.01 67.99 9003.34 1043.14 3666.31 11225.00 90.01 64.99 9003.34 1053.11 3689.23 MapN MapE DLS VS TFO Took ft ft deg/100ft ft deg 5977799.24 - 667019.48 --= - 30.00 -- 2657.82 358.56 MWD 5977801.58 667027.12 30.00 2665.68 358.58 MWD 5977806.26 667043.47 12.00 2682.43 85.00 MWD! 5977812.08 667067.77 12.00 2707.23 84.99 MWD':: 5977816.62 667092.35 12.00 2732.16 84.99 MWD'; 5977817.08 667095.32 12.00 2735.16 84.99 MWD: 5977820.88 667116.98 12.00 2757.11 269.00 MW D'i 5977826.40 667141.36 12.00 2781.95 268.99 MWD, 5977833.19 667165.42 12.00 2806.60 268.97 MWD' 5977841.23 667189.08 12.00 2831.00 268.96 MWD' 5977844.06 667196.56 12.00 2838.75 268.95 MWD' 5977849.93 667212.52 12.00 2855.25 90.25 MWD' 5977857.53 667236.33 12.00 2879.75 90.25 MWD!. 5977863.86 667260.51 12.00 2904.48 90.26 MWD~i 5977868.92 667284.99 12.00 2929.36 90.26 MWD'', 5977872.70 667309.70 12.00 2954.34 90.27 MWD 5977875.17 667334.57 12.00 2979.33 90.27 MWD 5977876.34 667359.54 12.00 3004.28 90.27 MWD 5977876.20 667384.53 12.00 3029.11 90.28 MWD ~ 5977875.88 667392.52 12.00 3037.02 90.28 MWD 5977875.36 667409.51 12.00 3053.86 270.00 MWD 5977875.69 667434.51 12.00 3078.74 270.00 MW D III 5977877.33 667459.45 12.00 3103.71 270.00 MWD 5977880.28 667484.27 12.00 3128.71 270.00 MWD 5977884.52 667508.90 12.00 3153.66 270.00 MWD 5977890.04 667533.28 12.00 3178.50 270.00 MWD' 5977896.83 667557.34 12.00 3203.15 270.00 MW D ~~, 5977904.87 667581.00 12.00 3227.55 270.00 MWD !~ 5977914.14 667604.22 12.00 3251.64 270.00 MWD'i 5977924.60 667626.91 12.00 3275.35 270.00 MWD 5977928.20 667634.06 12.00 3282.84 270.00 M W D I, 5977935.71 667649.31 12.00 3298.82 90.00 MWD; 5977945.75 667672.20 12.00 3322.67 90.00 MWD 5977954.58 667695.58 12.00 3346.88 90.00 MWD; 5977962.17 667719.40 12.00 3371.38 90.00 MWD 5977968.51 667743.58 12.00 3396.11 90.00 MWD; i 5977973.57 667768.06 12.00 3420.99 90.00 MWD, 5977977.34 667792.76 12.00 3445.97 90.00 MWD i 5977979.82 667817.64 12.00 3470.96 90.00 MWD; 5977980.99 667842.61 12.00 3495.91 90.00 MWD; 5977980.85 667867.60 12.00 3520.74 90.00 MWD' 5977980.53 667875.59 12.00 3528.66 90.00 MWD 5977980.01 667892.58 12.00 3545.49 270.00 MWD'! 5977980.34 667917.58 12.00 3570.37 270.00 MWD'i; 5977981.98 667942.52 12.00 3595.34 270.00 MWD i 5977984.92 667967.34 12.00 3620.34 270.00 MWD j 5977989.16 667991.97 12.00 3645.29 270.00 MW D ii 5977994.68 668016.35 12.00 3670.13 270.00 MWD':. 5978001.47 668040.41 12.00 3694.78 270.00 MWD; 5978009.51 668064.07 12.00 3719.18 270.00 MWD; 5978018.78 668087.29 12.00 3743.27 270.00 MWD', 5978029.25 668109.98 12.00 3766.98 270.00 M W D ~, N/S E/W ft ft by ~ BP Alaska Baker Hughes INTEQ Planning Report iNTEQ Company: . BP Amoco Date: 10/31/2008 Time: 15x39:07 Pagec 4 ~ Field: Prudhoe Bay Co-ordinate(NE) Reference: Welh E-34, True North ' Site: PB E Pad Vertical (TVD) Reference: 55:34 1/5/1994 00:00 64:9 5.OOAzi ~ Wellpath: I Plan 5,.E-34A --- ----- Survey C Icu etion Method: ------ M nimum Curvaaure Db: Sybase 'i Survey MD Incl Azim SS TVD N/S ' E!W MapN ft deg tleg ft ft ft ft 11233.00 90.01 64.03 9003.34 1056.55 3696.45 5978032.85 11250.00 90.01 66.07 9003.34 1063.72 3711.87 5978040.35 ~, 11275.00 90.01 69.07 9003.33 1073.25 3734.97 5978050.39 11300.00 90.01 72.07 9003.33 1081.57 3758.55 5978059.22 I I 11325.00 90.01 75.07 9003.33 1088.64 3782.52 5978066.81 I ~ 11350.00 90.00 78.07 9003.33 1094.44 3806.84 5978073.15 i 11375.00 90.00 81.07 9003.33 1098.96 3831.42 5978078.21 11400.00 90.00 84.07 9003.32 1102.19 3856.21 5978081.98 11425.00 90.00 87.07 9003.32 1104.12 3881.13 5978084.46 11450.00 90.00 90.07 9003.32 1104.74 3906.12 5978085.63 11475.00 90.00 93.07 9003.32 1104.06 3931.11 5978085.49 11490.00 90.00 94.87 9003.32 1103.02 3946.07 5978084.78 11500.00 90.00 93.67 9003.32 1102.27 3956.04 5978084.25 11525.00 90.00 90.67 9003.31 1101.32 3981.02 5978083.85 11550.00 90.00 87.67 9003.31 1101.68 4006.02 5978084.76 11575.00 90.00 84.67 9003.31 1103.35 4030.96 5978086.98 ' 11600.00 90.00 81.67 9003.31 1106.32 4055.78 5978090.49 11625.00 90.00 78.67 9003.31 1110.59 4080.41 5978095.30 ', 11650.00 90.00 75.67 9003.30 1116.14 4104.78 5978101.38 11675.00 90.00 72.67 9003.30 1122.96 4128.83 5978108.72 11690.00 90.00 70.87 9003.30 1127.65 4143.08 5978113.72 MapE I)LS VS TFO Tool ft deg/100ft ft deg ~ 668117.13 12.00 3774.47 270.00 MWD 668132.38 12.00 3790.45 90.00 MW D 668155.27 12.00 3814.30 90.00 MWD 668178.65 12.00 3838.51 90.00 MWD', 668202.47 12.00 3863.01 90.00 MWD 668226.65 12.00 3887.74 90.00 MW D ~' 668251.13 12.00 3912.62 90.00 MWD 668275.83 12.00 3937.60 90.00 MWD 668300.71 12.00 3962.59 90.00 MWD 668325.68 12.00 3987.54 90.00 MWD 668350.67 12.00 4012.38 90.00 MWD 668365.65 12.00 4027.19 90.00 MWD 668375.64 12.00 4037.06 270.00 MWD' 668400.63 12.00 4061.86 270.00 MWD'; 668425.61 12.00 4086.79 270.00 MWD 668450.51 12.00 4111.78 270.00 MWD ~ 668475.25 12.00 4136.77 270.00 MW D I, 668499.78 12.00 4161.68 270.00 MWD! 668524.03 12.00 4186.44 270.00 MW D ~I 668547.92 12.00 4210.99 270.00 MWD 668562.06 12.00 4225.60 270.00 2 3/8"' P Alaska .,,1 .iN ~ T LEGEND E.341E.36) M -.. Plan 5. E-30A um,vm. w I,~ xorv, Pl p5 • w, v~.~nle>,m.T evn c,.,mar m w. ~m„mm °~.° P.. wewwra oeru~a BNUGNE an xmnxie Nmn-zaoo I {•~ p =~~s~ ~ ~n~~l ne ; ~ ~~ --.-- ,e, n a,ea M~ae~.on ,oa,w,~,~>o r..., w.nov.x. 1NTEQ ~ E ~";a~~l~,~s,o w~.y.nl~„ a.n~ a~.a..am° ae:a.,,v,caaaom s..9en w`~ol: o.~ls o.~w F. m~rfra : .,.~ o.~ o.~ a,.,a EE E FOR TON J ~ I F I f ~ 1 1 { I II-~ r l.( ~~ 1I 1 T~TTTr T• .~~I {t (}{l_ I }yr *fr t Ii~ r _ t l r -r - `, 1 L ti '-1t i l ' 1 ~ ~~ ~ ' J~ ~ {{ ~}L i {11 ? 1 {~ 4_._ rt1I 1 ~ CoarV nal f E) C E30 Leval OnM1 Venice 1 v~l R I - 5 Sec,o ( 7RM 1ea'.5 3C1 Maa o s a sw oouo cn9o n c m ~n,an~e t I _ -' 1 _. ~ ~ t + ] : I 1 ] + _ i~_ tt V- Y L ly- F - ~ i_ I.. l '- r ~ 1 F Ti ~.IL~T l'{i JL . E tj~ i- - 1 -G- - i ~ _ t f -H 1 j ' I ~` t I + T~ ~ ~ { l I { _~ - _ ~ ; ~ ~ `~ , ~.,. o ~ F ~ 7 r I TT I { 1 . 1 ' ~ (~ I ~ li ~ ' _i.i I i r t. ~ t '1 I I I I T . _ r ~• ~ i I i . L }'.~1 Tj i' {{ i _1 I ' ~ T i * j. 7 { ~ i r1 ~ r r wa . vw,u ..a at..vv va:.w° y ..n ...... ~y i - _ __ _ r i-~ r~~ ~ ~ i ~ _ I I ~ i } _ { ', E-34A Fault 2 _ ~. l .. ...»aw .m.o v.o.v . ... »aw I 4 r - l {- 11 'L 1r`` ~: {i r a Y t ~ - ~ i ~ - f - ~ ~ ~ i I ~ I . ~ J . t Y T : . :. l ... ~ v,vwaw ~ vrva. nn.r n.v.v va~v ~ v` vv ` ~.lan 5, E-34A n ~ • . [ - f/~ ~ 0 r x DFr n. xo r rlox ~vwa., ~ - rvo ao m o-1 ~ I , __ 12 ~ cnd of 30 Deg/700' DL , ~ tt -34A T et 2 y , .a.x,a „asa ~ _ T-~o 1 O 10 - , T ~,.~..a.a. vov. vs ,v,wm v.. , s I evv..vv .v+r. oo e T sao E w v,a,x mo..w „asex .+.e.,a ca i vvvr es ,avn ov r vvvr .r ,vuv w • ~ vav>>v ,ana av v ' ~., E-34A Fault 7 - __ _ 1 © _ _ _ ----.. E-34 E-34 ~y~_ ~= \ ~` -34A Fault 3 . vov>>v ,aver vv vo e / vvnniii ii:'vo.va ii vouavn „evv.vv ro a eov ~ _ _ - _ '~ ~ . ~ ~ ' - ' E-34A Tar at 1 ~ j ~ ~~ ~ ' L - , _ .. ~ :. ~ TIP KOP End of 9 D H00' DLS d ~ ~~ i t I } { , {_ ~I { j i 7 ~ : I 1 r I .. .. ~ y ' I ~ F rra {~~ i i-r ~ I - t _ f: T ~ 1 o- 4 . } ' y _ _ I - - es ~ r I I r I~ r tT -~ '1 r r+ ~ 1. ~ ~ t H~ T 1 J I- rl 1-F 1 I t~ ~-F ~ i ~ I r r F - J - I- ~ 1T } -- _. .. . , , _ I r r . evm I - f I 1 { .. ' I Fr ~f 1 " ~ `' 7 ~~ - ~ ~ 1 I - , 1 T ~~l r~ ij - ,- -- i D I ~+i ' {' 1 i i ` _r ~I ~ ~ ' I { }~ r I - .+~ r i 1 ~ ~ i ~? I .a ~ 1 _ r o- ~ - _. I. :, ,.- TI r rl. } f l ' F I - 1 TIP KOP End of S D 1700' DLS : ~. .. 1. I ',..._ - I I {{ _-_ _ I h~ ~ _i ~ f {.., .~ ~.. _ I l t _ r { r {{ C .... L j 1 ....r.1 . ~ ' ~ - ---- ~ - ~ i~~ i rT I~ _ _... . _ . - ...... .. ' I I ;, I, ~ I i .~,~~ >s G . i . ~ ~ '/ ~i 1~{ I++ i I. .. t` 4~ J i -~ r f ~ r,~ zz~ ~ ,,, , , , >~ r,~ a ~~ .ooo ,.~o ~ r~ z,oa z~a zaoo ~o r,~ we t-pEaat[.] [toawm] .,~ .zap .~~ o «o « + r- a $+ ] ,~ ~ l +' ' ~ r { ~ r ~:I--F~iTI~~..,_114 ~ , 1~: ~I ~4,~,. i i I 1. ~~ ~ `' i `h I I y n~ ; 1 ~ ~ f~~ i 1 t i I 1 '- ~ ~ g _ : _ ___ - - -- 1 ar Y u ~ . ~ - _ ~-, ~ .. ~ .. a- f- ~ I ~ ~ c-34A Target 1 {_~ 1 T 1 ~ 1 : 7..4 r 1 . I rj I i :. ~ E.34A Tar et 2 N ~ ~ T 1~ I i ~ ~ ~ 12 / ~ ~~ ,. - 1 . 'T r IfTr Ti t_ _ i 1~ ~ ~ ~ . End of 30 De HOO' DL i - I ~. ` ' _ .. :. - .: t ' ~ I !-, 1 M - .. t~ { j 1 ` I _ Pian 5, E-34A _ _ _ 1 i ~ ~ _ ~ _ I I I ~_ I 1 I 1 r E i tr ~ { `_ , t 1 ' .~. l i + r.. i { ~ ~ - I ,,. , a, - .. {-~ + i '__ ,- TiT T ' i. ' _T` ~; ~- +- i { 1- i' 1 ~~ , -{. /~ ~~ 4 t + i 1-1 t ~l. _ ~F `,y~ ti r s, f ~ ; t i i ~ # fii + } ~' ~ ,, L ~ ~ I 1 {{ ~ -` k .~ y,. rF ~ ~ ~ =t ~ T ~#- ~- G I _ ~I ~ ` i.~ F Ty.! ~ ~ rrl~. ~ [ r + 1- l- , + i -~ n ~ I ~: ~ t 1 'Ytt .. ~ , . ' i rT ~ ~ .. I~ , ' t ~ , I ,, T r ~ ~ ~~ .. ~ . . ., ,~ r~ I I J J I~ ,r ~ ~ ~: I I ~ _ sr~ r^ r>~T~-rT^-7 -r i-r ~~T ~ zzso ~ z~ z,~ r.~ r~ r~ ~ z~ r,~ z,s~ r~ ,~.; ,~.T„~T ~ ~, ~~~~T~ ~ ~ ~ >~ ~,oo „~ 3d~ ~ 3~' as i : ~b ,ooa .os~ .:~a Vertical Section at 85.00' [50tt/in] `J • ~~~+~~. '~ BP Alaska "''t'"r ~~ Anticollision Report ~, rr..~ BAKER Nlu~l~s 1NTEQ Company: BP Amoco Date. 10/31/2008 Time:. 16:03:46: Page: 1 Field: Prudhoe Bay Reference Site: PB E Pad Co-ordinate(NE) Reference: Well: E-34, True North Reference Well: E-34 Vertical (TVD) Reference: 55:34 1/5/1994 00:00 :64.9 ~ Reference Wellpath:: Plan 5, E-34A Db: Oracle GLOBAL SCAN APPLIED: All welipaths within 200'+ 100/1000 of reference -There are'RIGBd~laeells in thisg9etrC'ipal Plan & PLANNED PROGRAM ~, Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse ,Depth Range: 9564.56 to 11690.00 ft Scan Method: i Trav Cylinder North i Maximum Radius: 1365.51 ft Error Surface: Ellipse + Casing i Survey Program for Definitive Wellpath Date: 10/31/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft ~~ 200.52 9564.56 1 : MWD -Standard (200.52-107 MWD MWD -Standard ~, 9564.56 11690.00 Planned: Plan #5 V8 MWD MWD -Standard Casing Points --- MD TVD Diameter Hole Size Name ' ft ft in in ~' 11690.00 9068.20 2.375 3.000 2 3/8" ~I --- Summary -- - - ---- ~___aw~__ Offset Wellpath --- - ---=' Reference Offset - Ctr-Ctr No-Go Allowable -~ ~~ Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ~ ft ~ PB E Pad E-01 - E-01 V1 9906.63 - 9800.00 578.05 - - 121.73 456.32 Pass: Major Risk ~ ', PB E Pad E-01 E-01 A V4 Out of range PB E Pad E-01 E-01APB1 V1 Out of range PB E Pad E-11 E-11 V12 11477.21 9850.00 867.75 507.60 360.15 Pass: Major Risk PB E Pad E-11 E-11A V1 11463.81 9650.00 1305.43 413.44 891.99 Pass: Major Risk PB E Pad E-11 E-11AP61 V2 11467.49 9600.00 1308.54 385.86 922.68 Pass: Major Risk ' PB E Pad E-34 E-34 V1 9575.00 9575.00 0.11 67.87 -67.76 FAIL: Major Risk PB K Pad K-08 K-086 V2 Out of range PB K Pad K-10 K-10 V1 11025.00 9925.00 988.07 545.76 442.31 Pass: Major Risk ~~ PB K Pad K-10 K-10A V7 11615.12 10535.60 847.66 526.16 321.50 ~ Pass: Major Risk ~ PB K Pad ~ K-10 K-10AP61 V1 11066.61 9825.00 1025.08 514.86 510.23 Pass: Major Risk i ! PB K Pad K-10 K-10APB2 V1 11066.63 9825.00 1026.09 514.85 511.25 Pass: Major Risk PB K Pad K-10 K-10AP63 V2 11081.19 9903.60 1007.03 510.52 496.51 Pass: Major Risk ~B K Pad K-10 K-106 V3 9599.13 11050.00 609.30 457.49 151.81 Pass: Major Risk Site: PB E Pa d Well: E-01 Rule Assigned: Major Risk Wellpath: E-01 V1 ----- Inter-Site Error: - 0.00 - ft Reference - Offset Semi-Mnjor Axis Ctr-Ctr No-Go Allowable ~ ' MD TVD MD TVD Ref Offset TFO+AZI TF0-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9906.63 8971.18 9800.00 9233.48 34.34 108.99 235.08 158.30 7.000 578.05 121.73 456.32 Pass 9912.97 8976.66 9825.00 9256.91 34.37 109.18 235.08 158.48 7.000 582.66 123.30 459.36 Pass 9920.00 8982.61 9850.00 9280.37 34.41 109.35 235.10 158.69 7.000 588.07 125.06 463.00 Pass ' 9925.38 8987.07 9875.00 9303.83 34.44 109.57 235.16 158.87 7.000 594.24 126.54 467.70 Pass II I~ 9931.43 8991.98 9900.00 9327.31 34.47 109.77 235.24 159.08 7.000 601.17 128.17 473.00 Pass I I'I 9937.37 8996.68 9925.00 9350.80 34.51 109.97 235.34 159.31 7.000 608.83 129.76 479.07 Pass li 9940.00 8998.74 9939_90 9364.81 34.53 110_12 159.43 235.42 7.000 613.74 130.50 483.24 Pass _ ~ _ Site: PB E Pad _ _ Well: E-11 Rule Assigned: Major Risk Wellpath: E-11 V12 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis ' Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZT TFO-HS Casing/ flsflistance Area Deviation Warning ft ft ft' ft ft ft deg -deg in ft ft ft -- 11284.12 9068.23 -- , 9100.00 7816.12 -- 50.48 178.28 -- 46.72 336.55 7.000 1364.81 ---- 312.64 - - 1052.17 - - Pass 11290.45 9068.23 9125.00 7837.14 50.61 178.73 47.12 336.19 7.000 1345.58 317.24 1028.34 Pass 11296.81 9068.23 9150.00 7858.12 50.74 179.14 47.51 335.82 7.000 1326.50 321.97 1004.52 Pass 11303.19 9068.23 9175.00 7879.06 50.86 179.52 47.89 335.43 7.000 1307.56 326.82 980.74 Pass ~ 11309.60 9068.23 9200.00 7899.96 50.96 179.87 48.25 335.03 7.000 1288.78 331.79 956.99 Pass 10~ 10 10 ~UDHOE BAY, PRI~HOE O~ Productan Data 10 10 10 10 ._ ____ ~ L a SKI I_H E-34 i 10 s~ i aa4 as ao a i ao ~~ cwv v ~ v~ ~., ~~ .... .... ... .. DATE Alaska Department of Natural Resources Land Administration System Page 1 of~ -.;i; , ~,.~ - . _-~, _• 9a~s ~~~c~r~~r's S~arci; Stag Cabins ~~t~ ~ u ~ Alaska DNR base Sur~nnary File Type. Ata~ '` File Number: 2$299 ~ Printable Case_File Summary. See Township, Range, Section and Acreage? I ~' YeS ~` NO New Search 1_AS then:~ I Case Abstract I Case Detaii I Land Abstract . _, l~rle: AUi. 28299 ''~~ ~ Se:~rch for Stai~s.Plat Updates ~s cif 11:'1 Si~00S Custorner.~ 000107377 BP EXPLOR.~7~IUN (~~L.~SKA) INC PO BOX ] 96612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ~3f~ OIL & GAS LEASE COMP DNR Urrit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Corse Stags: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2459.000 Date Initiated: 05/28/1965 Office of Pri~rary Responsibility: DOG DIV OIL AND GAS Last Trarascrctiorr Date: 12/04/2006 Case Subtype : ~ NORTH SLOPE bust T~°ansactiorz: AA-NRB ASSIGNMENT APP ROVED 11%Ier'idiu~~.'U Toirns{~r~~.~ U12N R<ni,~~~.~ (11<ll~ ,S~°crir~~t: ~~) S'c~c~[r~»t Jc~'es: 640 Sea:ch pl,~~ .llc'i7dItN1: U TON'i1.1(1L~)' 01~~ Riaf1.~L: O~4E SE'Ct7~~!].~ ?~) ,S~c'C(lUl7.~~L'PC'~'.~ ~~~ 1~~F'/'IcilcUl: ~ TOWrlshlp: 012N 1~C7N~rC: (~ ~ ~~~, .~~c'CllllJl.~ ~ 1 SCE"I1(~Pl _tC7'~',~: ~~) A1er•idre,n ~ U Totivnship: O l2N h~n~~r: Cl l -~l : ,1'~~~ riurz~ 32 Secri~u~ 1 crrs.~ (~~O Leal Description 0~-28-196 * * ~S~LE NOTICE LEGAL DESCRIPTION* CI-1-120 01?N-OI~E-U~1=129,30,31,32 2;r~9.00 0-1-01-I1%' ***U,ITTTI7_F.D I.F.G:1I, DF.SC'RIPTION"~`* T12N. R1=lF_, U11~I, SEC,'S: 2y, 31, 32 C'O,VT.4L-'~'I.VG 1871 ACRES MORE OR ~FSS. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28299... 11 / 18/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~ ., :.:>~ ~ ,-_;r .., : i r~, r. I ~i ; - .~ nrC:cr'~ :~~:arci~~ State Cabins ~'~LII'~~ 411'5 Alaska DAR Case Summary File Type. A~~ File Number: 28304 ~ Printable Case File Summary See Township, Range, Section and Acreage? ~` Yes ~ No New Search ' I.A.rti Mensa ~ Case Abstract ~ Case Cetaii ~ hand Abstract ~*~"~,. File: :'vDL 2830~t ~~ Search for Status Plat Updates 1 c,f 11/1 S''<1105 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 9951966]2 Case Type: ~~~~ O[L & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File LC)CatlOn: DOG DIV OIL AND GAS Case Statz~s: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2469.000 Date Initiated': OS/28/1965 Office of~Primafy Responsihilitl°: DOG DIV OIL AND GAS Last "transaction Date: 12/04/2006 Case Subt}pe: ;°~i~ NORTH SLOPE Lust Transaction: AA-NRB ASSIGNMENT APPROVED Mc~rr~~rrrri.~ L! Tn~r~~s{ul~.~ O I N Range: 014E Section: OS p' Y-IK: s 11~~ri~lr<n~.~ 1 Township: O1 I N l~art~re~: (I I ~L ~S'c~c/r~,~r.~ UG 1~1i~ricli~~~t.~ 1_` Tn1l~nehi~~: O L I N l~uj~~,<<~: U 1 ~I ~, 1'c°clinn: U ~;'('!7(~lcl~l: ~ - i~lit71 ~{]1~1: ~) I ~ N Ratlge: O ~ -~1 _ ,~~'~7eOn: Oc~ Leal Description 0~-?8-196 ***SALENOTICELEGAL DESCRIPTION*"~` Section .=lcrE~s~: 6~0 1~~~cliun . l~~f~c~~.~ ~9_; ti~r~~liut~ _~l~rc~.~ ~~)~~ Search C1-;t-12~ 11 N 1 ~E UNt ~, 6, 7, 8 2-X69.00 II- 3- 7 l~ CBS C~' imp Last updated on 11/18/2008. http://www.dnr. state.ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28304... 11 /18/2008 E-341ateral or sidetrack questi~ • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 12, 2008 1:02 PM To: 'Phillips, Ron' Subject: RE: E-34 lateral or sidetrack question Ron, I have checked with my naming colleagues and it is our consensus that the name should be E-34L1 as you are not intending to permanently abandon the original E-34 Sag borehole. On that basis, a sundry is not needed just the PTD. In the "introduction statement" in the permit package, it makes sense to state what BP's intent is. Call or message with any questions. Tom Maunder, PE AOGCC From: Phillips, Ron [mailto:Ron.Phillips@bp.com] Sent: Wednesday, November 12, 2008 10:50 AM To: Maunder, Thomas E (DOA) Subject: RE: E-34 lateral or sidetrack question Tom, The existing penetration will have a retrievable liner top packer and a retrievable whipstock. There will be cement in the proposed lateral separating the Ivishak formation from the Sag River Formation. Thanks, Ron Phillips Coil Tubing Drilling Engineer Alaska Drilling & Wells Office (907) 564-5913 Cell (907) 748-7868 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, November 12, 2008 10:41 AM To: Phillips, Ron Subject: RE: E-34 lateral or sidetrack question Ron, According to the drawing, the TOC will be "out" in the new segment. Any isolation of the existing penetration will be just mechanical, correct? I will have to defer to my colleagues over here. We will get back to you. Tom Maunder, PE AOGCC From: Phillips, Ron [mailto:Ron.Phillips@bp.corrt] Sent: Wednesday, November 12, 2008 9:46 AM To: Maunder, Thomas E (DOA) 11/20/2008 E-34 lateral or sidetrack question • Page 2 of 2 Subject: E-34 lateral or sidetrack question Tom, This is a bit of an oddball and I am not sure if you want a sundry notice or not for this well. First of all E-34 is a Sag River horizontal slotted liner completion that cycles on and off with an on time of only 15%. We do not plan to produce from the Sag River again. The new Ivishak lateral/ sidetrack will be a solid liner, cemented and perforated. The cement in the Ivishak lateral and the liner top packer at 8990' will isolate the Ivishak from the Sag River formation. We do not want to bring cement back up to the whip stock to preserve the option to cut and pull the tubing and sidetrack again later. Since the liner top packer and whip stock are retrievable, will this Sag River well E-34 have an E-34L1 lateral in the Ivishak or does this well become sidetrack E-34A. «0638_001. pdf» Thanks, Ron Phillips Coil Tubing Drilling Engineer Alaska Drilling & Wells Office (907) 564-5913 Cell (907) 74$-7868 11 /20/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~,C~'!1 ~.~~L/ PTD# ~a ~i~~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: P,e6/D~OE' ~Ay POOL: /~.~C~.Df~l.L~',Q,gyO/L Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL Thep it is for a new wellbore segme t of existing ~s~oo~p~l/~-3~ , well~oo~9aa i _ n (If last two digits p ?~3~~C~G? API No SO Q ~ ~ it N ?O /93 ?D API number are between 60-69) . ,e a erm o.~ 0 , r Production should continue to be reported as a function of the original API number stated above. PILOT 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 well name ( PH) and API number (50- - -~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Comnany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/11/2008 WELL PER(~1T CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL •640150 Well Name: PRUDHOE BAY UNIT E-34L1 Program DEV Well bore seg ^ PTD#:2081780 Canpany BP EXPLORATION (ALASKA) INC Initial Classltype DEV / PEND GeoArea $90 Unit 11650 OnlOff Shore ~ Annular Disposal ^ Administration 1 Petmitfeeattached__._._.__-__--._--___-_.-__----- --------_ NA___-_ _-__---.-------- -- --- 2 Lease number approRriate- - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - 3 Unique well-name and number-- -- -- - -- - -- -- --Yes -- -- -- - ----- --- ---- --- - - -- -- - - - 4 Well located in a-definedp_ool---------------------------- ----------Yes---- --- -- -- 5 WelllocaiedRroperdistancefromdrillingunfl_boundary------------- ---------Yes---- ----------------------------- -- -- -- - -- --- - - 6 Well located RroRer distatrce from ocher wells- - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - 7 Suffigientaoreage_ayailableindriilingunit____--------------- ----- ----Yes_ _- ---2560 acres,------------------------------ - -- --- - - -- --- 8 Ifdeviated~is-wellboreplat_included---- ----- --- - --- Yes -- --- -- - -- - -- ----- -- -- -- -- - -- 9 QperatoronlyaffeciedRa~Y-- --- - - -- - -- -- -- ---Yes -- --- -- -- - -- -- -- -- -- -- - -- -- - -- --- 10 Operatorhas-appCOpriatebondinforce___-_-----__--__---_ ___------Yes---- ---BlanketSond#6194193.-_____-__--_-___-__-_----------------- -- -- 11 Permitcanbeissuedwithoutconservationorder__-__----__---- ---------Y~-- -- -- -- - -- - --- --- -- -- - ----- - - - - -- Appr Date 12 Permiteanbeissuedwithoutadministrativ_e_apRroyal--------------- ----------Yes---- -------------------------- - - -- - - --- -- 1111812008 13 CanpemlitbeaRRrovedbef9re15•daYwait------------------- ----------Yes--- ------------------------------ -- -- -- -- -- - - -- -- - ACS 14 Well located within area and strata authorized bylnjectionOrder#(putiO#in_ comments)_(FOr_ NA_____ _________--___--___-__-_-__-__-_____-__---___---_---__--__-____-- 15 Ail wells_within 114,mile area_of review identified (For seryice_weli onl NA- - - - - - - - - - - - - - - - - - - - - - - - - - ------------------------------------- 16 Pre•produced injector duration of pre production less than 3 months-(For service well only) _ - -NA_ _ - _ _ - - - _ _ _ . _ - - _ - - _ - - _ _ _ - _ _ - . _ - - - _ - _ - - - - - - - - - - - - - - - - - - - - 17 Nonconyen, gas eonforms to AS31,05.034Q.1.A),([.Z.A•D) _ - - _ _ _ - - _ - _ _ _ - _ _ _ _ _ - _ NA- - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductor string-Rrovided---___-______--__--___-___- ___-____-NA_____ __Cgnductorset_inE-34(195.202}__________________________________------------ 19 Surface casingprotectsaH-knownU$DWS---------------_---- -_-_ _--- NA__-- _-Ali aquifersexempefedAEO1._-_-____-___-__-___-_-_-------------------------- 20 CMTvoladequate_iecirc~lake_onccnducto[&surf_csg-------------- ---------- NA____- -__Surf_acecasing set in E•34.______--___-__--___---_-_------------------------ 21 CMT_yoladequatetotie•iniongstringtosurfcs9___-_-__--_-.__ -____-_--- NA_---. _--Production_casingsetin_E-34------------------------------------------------- 22 CMTwilicover_allknown_productivehorizons-___-_--_--._--_ ___- --_--Yes---- ----------------------------- - - -- -- --- - -__-- 23 Casing desgns adequate for C~ T, B &_Rermafr_ost - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage_ or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ - - _ Rig equipped with steel pits, No reserve pit planned.- All waste,to apRrov_ed disposal well(s), - - _ - - - _ _ _ _ - 25 Ifare~drill,has_a10.40$forabandQnmentbeegapRroved___-____-_ __--__--_-NA__-_ __-Existingintervatwiil not be plugged-----------------------------------------_--__- 26 Adequate wellbore separationproposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - - _ Proximity analysis performed, Nearest segment is ivishak penetration of Er34, Paths diverge. _ - - - _ _ _ _ 27 If divertertequiled,dQesitmeetregulatiens------------------- --------- N?----- ---BpPStackwillalreadY-beinRiace,-----------.------------------------------ - Appr Date 28 Drilling fluid_prpgram schematic & equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ -Maximum expected formation pressure 7,0_EMW_ MW planned 13.6 ppg. - _ _ - - - _ _ - - - _ _ - - _ _ - - _ _ - - TEM 11I20l2008 29 BOPEs~ do they meet rQgulation - - - - - - - - - - - - - - Yes . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE_Rress rating appropriate; test to.(put prig in-cgmments)- - - - - - - - - - - - - - - -Yes _ - - _ - - MASP calculated at 2306 psi, 3500_psi-BOP testplanned, - _ - - . _ - - _ _ _ - - - - _ _ - - . _ - - - _ _ - _ . _ - - /,.-~ 31 Cheke_ manifpld complies wlAPl_ RP-53 (May 64). - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - !!! "`"' 32 Work wih 9ccur without operation shutdown- - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ _ _ _ H2S is known at E pad. -Mud shguld precludetl2S on rig._ Rig has sensors and alarms. _ - - - _ _ - - _ _ - _ _ _ 34 _Mechanical condition of yells within A0R verified (For service well onN) _ - _ - _ - - - - _ - _ NA_ _ _ _ - _ _ - _ _ - _ _ _ _ - _ - _ - - - - - - - - - - - - - - - - - - - - - - Geology 35 Permit can be issued wlo hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - - - - - No_ - _ _ - _ _ Max level H2S on_ E pad_i& 120ppm on well E-102, - _ _ _ _ _ - - _ _ - - - _ - - - _ _ _ _ - - _ _ - - - - _ _ - _ 36 Data_plesentedonpotentialove~pressurezones--____--_---_--_ ____------KA----- ------ -- - -- - - -- --- --- - --- - - -- --- --- Appr Date 37 Seismicanslysisofshallowgas_zonas----------------------- ----------- KA---- ------------ -- ACS 11!1812008 38 Seabed conditionsuryey_(ifof(•shore)----------------------- ----- ----NA_____ ___--____---_----- 39 Cor~ctnamelphoneforweekly_Rrogtesstepods[exploratory9nly)------ -----------Yes---- ---Bon_Phillips-564.4750.------------------------------ - --- --- -- - Geologic Commissioner: Engineering Public Date: Commissioner: Date Com is ' Date ~~ ~~-2 i -off ~j.~~,.08 • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special ef~orl has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 09/04/09 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/02/08 2444741 01 2.375" CTK *** LIS COMMENT RECORD *** !!!~!~!!!~~!!!!!!!! Remark File Version 1.000 !!!!!~!!!!~!~!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 9314.0000: Starting Depth STOP.FT 11749.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: E-34L1 FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 20' 35.449"N 148 deg 39' 55.015"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 08 Feb 2009 API API NUMBER: 500292243760 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 24 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 64.9 DMF DF EKB .F 0 EDF .F 64.9 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage (OHMM) (OHMM) (OHMM) (OHMM) surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and depth shifting has been waived by Doug Stoner with BP Exploration (Alaska), Inc. The MWD data is the PDC (Primary Depth Control) log for E-34L1. (8) The sidetrack was drilled from E-34 through a milled window in a 4 1/2 inch liner. Top of window 9543 ft.MD (8688.8 ft.TVDSS) Bottom of window 9548 ft.MD (8689.1 ft.TVDSS) (9) Tied to E-34 at 9532 feet MD (8688.5 feet TVDSS). (10) The interval from 11721 feet to 11749 feet MD (9014.1 feet to 9014.2 feet TVDSS) was not logged due to sensor to bit offset. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 75 records... 10 bytes 132 bytes *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and depth shifting has been waived by Doug Stoner with BP Exploration (Alaska), Inc. The MWD data is the PDC (Prinary Depth Control) log for E-34L1. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-t ype is: 1 FRAME SPACE = 0. 500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Sample s Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 136 Tape File Start Depth = 9314.000000 Tape File End Depth = 11749.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 149 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 • *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 271 Tape File Start Depth = 9314.000000 Tape File End Depth = 11749.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 284 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/02/08 2444741 O1 **** REEL TRAILER **** MWD 09/04/09 BHI Ol Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes ~ ~ Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR RPD RPS 9314.0000 -999.2500 -999.2500 -999.2500 9314.5000 64.5000 -999.2500 -999.2500 9400.0000 57.8000 -999.2500 -999.2500 9500.0000 -999.2500 -999.2500 -999.2500 9600.0000 77.8000 29.6920 34.3880 9700.0000 216.1000 197.9420 225.8730 9800.0000 25.5000 97.7760 96.0070 9900.0000 35.2000 59.2690 55.6680 10000.0000 18.7000 49.3230 49.5140 10100.0000 20.0000 23.9100 23.9820 10200.0000 21.4000 29.0870 29.3670 10300.0000 24.4000 37.6170 39.1310 10400.0000 21.2000 53.3160 58.6710 10500.0000 23.3000 42.0700 41.0080 10600.0000 18.8000 40.3040 40.9980 10700.0000 21.7000 37.8960 38.6530 10800.0000 23.0000 37.1550 36.5250 10900.0000 26.1000 43.9670 46.4560 11000.0000 20.3000 17.1830 14.2380 11100.0000 21.1000 23.7480 20.9700 11200.0000 26.4000 ROP -999.2500 -999.2500 -999.2500 -999.2500 67.1000 11.9000 42.2000 67.4000 56.1000 29.3000 50.1000 109.0000 89.5000 29.4000 33.3000 103.9000 38.9000 25.7000 29.9000 34.9000 41.6000 RAD -999.2500 -999.2500 -999.2500 -999.2500 15.4090 31.7630 29.6370 26.1710 20.7350 19.2730 21.2360 22.3440 20.7440 25.9130 26.1880 23.5050 21.5770 19.4160 19.4160 22.7850 21.9320 RAS -999.2500 -999.2500 -999.2500 -999.2500 21.4240 264.4460 111.1280 77.3130 56.3730 21.6540 23.6910 33.4320 39.4700 39.9000 36.3890 33.6700 36.9240 2000.0000 26.0240 29.7330 27.5070 30.8630 30.6000 11300.0000 16.7000 37.1000 37.9030 51.9730 11400.0000 24.6000 29.6000 23.5740 25.2810 11500.0000 77.0000 55.5000 11.0960 11.9390 11600.0000 131.9000 33.1000 40.8080 65.0850 11700.0000 19.5000 106.2000 46.0180 51.9730 11749.0000 -999.2500 101.7000 -999.2500 -999.2500 Tape File Start Depth = 9314.000000 Tape File End Depth = 11749.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 15.5920 15.7590 12.5920 15.0280 19.0160 -999.2500 22.6310 19.8250 8.4130 23.2150 37.4760 -999.2500 ~ ~ Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9314.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9314.2500 66.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 57.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 77.8000 67.1000 15.4090 21.4240 29.6920 34.3880 9700.0000 216.1000 11.9000 31.7630 264.4460 197.9420 225.8730 9800.0000 25.5000 42.2000 29.6370 111.1280 97.7760 96.0070 9900.0000 35.2000 67.4000 26.1710 77.3130 59.2690 55.6680 10000.0000 18.7000 56.1000 20.7350 56.3730 49.3230 49.5140 10100.0000 20.0000 29.3000 19.2730 21.6540 23.9100 23.9820 10200.0000 21.4000 50.1000 21.2360 23.6910 29.0870 29.3670 10300.0000 24.4000 109.0000 22.3440 33.4320 37.6170 39.1310 10400.0000 21.2000 89.5000 20.7440 39.4700 53.3160 58.6710 10500.0000 23.3000 29.4000 25.9130 39.9000 42.0700 41.0080 10600.0000 18.8000 33.3000 26.1880 36.3890 40.3040 40.9980 10700.0000 21.7000 103.9000 23.5050 33.6700 37.8960 38.6530 10800.0000 23.0000 38.9000 21.5770 36.9240 37.1550 36.5250 10900.0000 26.1000 25.7000 19.4160 6933.3096 43.9670 46.4560 11000.0000 20.3000 29.9000 19.4160 26.0240 17.1830 14.2380 11100.0000 21.1000 34.9000 22.7850 29.7330 23.7480 20.9700 11200.0000 26.4000 41.6000 21.9320 27.5070 30.8630 30.6000 11300.0000 16.7000 37.1000 37.9030 51.9730 11400.0000 24.6000 29.6000 23.5740 25.2810 11500.0000 77.0000 55.5000 11.0960 11.9390 11600.0000 131.9000 33.1000 40.8080 65.0850 11700.0000 19.5000 106.2000 46.0180 51.9730 11749.0000 -999.2500 101.7000 -999.2500 -999.2500 Tape File Start Depth = 9314.000000 Tape File End Depth = 11749.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • 15.5920 15.7590 12.5920 15.0280 19.0160 -999.2500 22.6310 19.8250 8.4130 23.2150 37.4760 -999.2500 ~ ~ Tape Subfile 4 is type: LIS
