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207-146
3-1/2"x3-3/16" RS-95/N-80 4-1/2" 12.6# 13Cr85 / L-80 By Grace Christianson at 4:20 pm, Jul 08, 2024 Abandoned 6/19/2024 JSB RBDMS JSB 071724 xGDSR-7/31/24MGR26DEC2025 Drilling Manager 07/08/24 Monty M Myers Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.07.08 16:13:40 - 08'00' Bo York (1248) ACTIVITYDATE SUMMARY 6/2/2024 *** WELL SI ON ARRIVAL*** MIRU AKEL PT 250 LOW AND 2500PSI HIGH, FUNCTION TEST WLVS DRIFT GR/CCL AND DUMMY WHIPSTOCK WITH 2.75" RINGS. OAL:36' WEIGHT: 250# MAX OD: 2.75" PICK UP OFF BOTTOM AT 10410' ELM PERFORM GYRO DATA SURVEY TAKING SHOTS EVERY 100FT FROM SURFACE TO 10380' LAY DOWN FOR THE EVENING ***JOB CONTINUED ON 3-JUNE-24*** 6/3/2024 *** JOB CONTINUED FROM 3-JUNE-2024*** PT TO 250 LOW AND 2500 PSI HIGH. LOG CORRELATED TO HALLIBURTON COIL FLAG LOG DATED 18-APR-2024 WHIPSTOCK SET AT 10385' TOP OF WHIPSTOCK. ORIENTATION: 218.5 DEG ROHS CCL - TOP: 13.8' CCL STOP DEPTH: 10371.2' RDMO AKEL *** JOB COMPLETED*** 6/6/2024 T/I/O= 280/190/60 (CTD) Assist SL - MIT-T to 2,575 psi ****PASSED**** Target pressure= 2,500 psi - Max Pressure= 2,750 psi - Topped off TBG with 5.1 bbls of Crude while SL set plug. Pumped 10.9 bbls of Crude down TBG to reach 2742 psi. 1st 15-minute loss of 118 psi, 2nd 15-minute loss of 49 psi, for a total loss of 167 psi in 30 minutes. Bled back ~3.2 bbls SL in control of well upon departure. FWHPs= 405/105/48 6/6/2024 ***WELL S/I ON ARRIVAL*** (ctd) SET 3.81" XX PLUG IN X NIP AT 9824' MD LRS PERFORMED MIT-T TO 2500 PSI **PASS** (see LRS AWGRS) PULLED 3.81" XX PLUG AT 9,824' MD ***WELL LEFT S/I ON DEPARTURE*** 6/10/2024 T/I/O = 800/100150. Set 4" CIW "H" Plug #152. Removed Tree above MV. Pitting in top flange on MV. Placed Tree cap on MV. FWP=BPV/100/50 6/11/2024 ***WELL S/I ON ARRIVAL*** SET 3.81" XX PLUG ( 25" oal) IN X NIPPLE @ 9,824' MD PREFORM DRAW DOWN TEST ***CONTINUE ON 6/12/24*** 6/11/2024 T/I/O= BPV/100/50. Installed 4" CIW Tree. PT low 350psi (Passed) PT High 5000psi (Passed). Pulled 4" CIW "H" Plug #152. FWP=800/100/50 6/12/2024 T/I/O = 350/150/75. Pre CDR2. Set 4" CIW TWC #436 @ 125" with CIW lubricator. Removed 4" CIW upper tree and installed CDR Tree w/Target 90 and kill line. PT'd CDR Tree against TWC to 350 / 5000 psi. Passed. Pulled 4" CIW TWC #436 @125" FWP = 350/150/75. 6/12/2024 ***CONTINUED FROM 6/11/24*** CONTINUE WITH DRAW DOWN TEST ***PASS*** *** WELL S/I ON DEPATURE*** 6/13/2024 T/I/O= 593/189/59 Assist Slickline. LRS Unit 76. (CTD) Pumped 20 BBLS Crude and 6 BBLS 50/50 down TBG as directed. SL in control of well and DSO notified upon LRS departure. 6/13/2024 T/I/O=200/150/50. Pre CDR2. Removed 4" tree cap and instaled 4" x 7" X-over and 7" tapped blind. Torqued flanges to API spec. PT x-over aginst SV to 350/5000 psi. Passed. Cycled SV. ***Job Compete*** Final WHP's 350/150/50. Daily Report of Well Operations PBU 05-13B Daily Report of Well Operations PBU 05-13B 6/13/2024 ***WELL S/I ON ARRIVAL*** PULLED 3.81 XX PLUG FROM 9,824' MD ***WELL S/I ON DEPATURE*** David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 06/07/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 05-13 + 05-13A + 05-13B -PTD 177-026 (05-13) -PTD 194-042 (05-13A) -PTD 207-146 (05-13B) -API 50-029-20250-00-00 (05-13) -API 50-029-20250-01-00 (05-13A) -API 50-029-20250-02-00 (05-13B) Definitive Directional Surveys (Composited) -Gyrodata Re-Survey 06/02/2023 Main Folder Contents: Please include current contact information if different from above. T38881 T38882 T38883 177-026 194-042 207-146 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.10 08:19:20 -08'00' 207-146 () PTD 207-146 (05-13B)T38883 10410, 10430, 10432, 12770 Drilling Manager 04/29/24 Monty M Myers By Grace Christianson at 11:40 am, Apr 29, 2024 SFD 4/30/2024MGR10MAY2024 10-407 DSR-4/29/24 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) Approved for alternate plug placement on parent abandonment with fully cemented liner JLC 5/13/2024 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: April 29, 2024 Re:PBU 05-13B Sundry Request Sundry approval is requested to set a whipstock and mill the window in 05-13B, as part of the pre-rig and drilling/completing of the proposed 05-13C CTD lateral. Proposed plan for PBU 05-13C Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT (caliper if needed). E-line will set a 3-1/4" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. See 05-13C PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 3-1/4" packer whipstock and mill a single string 2.74" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 4 and land in Zone 1. The lateral will continue in Zone 1 to TD. The proposed sidetrack will be completed with a 2-3/8 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Sag perfs. This Sundry covers plugging the existing Sag perforations via the packer whipstock, liner cement job and liner top packer set post rig (if needed) (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start May 2024): 1. Slickline: Dummy WS drift and Caliper (if needed) a. Drift and Caliper past whipstock setting location 2. Fullbore: MIT-IA or T to 2,500 psi (minimum) 3. E-line: Set 3-1/4 packer whipstock* a. Top of whipstock at 10,385 MD (top of window at 10,385 MD = pinch point) b. Oriented 220° ROHS (high side) 4. Service Coil: Mill Window (mill with rig if needed) a. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,460 psi IV. Mill 2.74 window plus 10 of rat hole V. Single string window exit out of 3-1/4 liner 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: Reference PBU 05-13C PTD submitted in concert with this request for full details. General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,460 psi a. Give AOGCC 24hr notice prior to BOPE test 2. Mill Window (only if not done pre-rig) 3. Drill Production Lateral 4. Run and Cement Liner* 5. Freeze Protect and RDMO 6. Set LTP* and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Sundry 324-254 PTD 224-040 , p y p p g ( This completion will completely isolate and abandon the parent Sag perfs. The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coils departure. Additionally, all BHAs will be lubricated and there is no plan to open hole a BHA. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Hole Size: The window and 10 of formation will be milled/drilled with a 2.74 OD mill. Well Control: BOP diagram is attached. AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. 20 AAC 25.036 (c)(4)(C) requires that a BOPE assembly must include a firewall to shield accumulators and primary controls. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: DS05 is an H2S pad. Last H2S reading on 05-13: 10 ppm in 2022. Max H2S recorded on DS/Pad: 580 ppm in 1998. Reservoir Pressure: The estimated reservoir pressure is expected to be 3,340 psi at 8,800 TVD. (7.3 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,460 psi (from estimated reservoir pressure). Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 DS05 is an H2S pad. Coiled Tubing BOPs Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B3 B4 B1 B2 Choke Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 10,385' 13,027' MD Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the Abandon box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer SFD 4/30/2024 SFD 4/30/2024 207-146 PRUDHOE BAY UNIT 05-13B 324-254 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:207-146 6.50-029-20250-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13107 10410 8356 9789 , 9925 10888 7902 , 7994 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 27 - 107 27 - 107 1530 520 Surface 2685 13-3/8" 27 - 2712 27 - 2712 4930 2670 Intermediate 10004 9-5/8" 26 - 10030 26 - 8064 8150 / 6870 5080 / 4760 Liner 6170 7" 4182 - 10352 4058 - 8309 7240 / 8160 5410 / 7020 Perforation Depth: Measured depth: 10326 - 13048 feet True vertical depth:8288 - 8814 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 24 - 10300 24 - 8266 9789 / 9925 7902 / 7994Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT, 4-1/2" Baker SABL-3 Liner 3118 9977 - 13095 8028 - 8813 10160 / 10570 10530 / 11160 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 93001276170 10629485 0 35534 313 973 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: David Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8813 Sundry Number or N/A if C.O. Exempt: n/a No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Dump bail cmt on CIBP Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028326 PBU 05-13B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" x 3-3/16" x 2-7/8" 10430, 10432,10990 By Samantha Carlisle at 3:59 pm, Apr 22, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.22 15:35:26 -08'00' Bo York , ADL028325 SFD 4/23/2021RBDMS HEW 4/23/2021MGR30JUL2021DSR-4/22/21 SFD 4/23/2021 ACTIVITYDATE SUMMARY 3/17/2021 ***WELL S/I ON ARRIVAL*** (Profile modification) DRIFT TO 10,387' SLM W/ 2.60" BELL GUIDE (CIBP od = 2.513"). ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 3/28/2021 ***WELL S/I ON ARRIVAL*** (HES E-Line and Cement Dump Bail) SET 3-3/16" NORTHERN SOLUTIONS EXTRA RANGE CIBP AT 10,430'. DUMP BAIL 20' OF 17 PPG NEO SUPERSLURRY CEMENT (est. toc ~ 10,410'). ***JOB COMPLETE ON 28-MAR-20201*** Daily Report of Well Operations PBU 05-13B • STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations EI Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing ❑ Change Approved Program 1❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: C /6P C6 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-146 3. Address: P.O.Box 196612 Anchorage, Development I Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20250-02-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PRUDHOE BAY UNIT 05-13B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 13107 P feet Plugs measured 10990/12770 feet true vertical 8813 feet Junk measured feet APR 0 4 2017 Effective Depth: measured 10990 feet Packer measured See Attachment feet A r A,� true vertical 8777 feet Packer true vertical See Attachment feet (1.x.1: Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"94#H-40 28-107 28-107 1530 520 Surface 2687 13-3/8"72#N-80 27-2714 27-2714 4930 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10326-10346 feet 10346-10376 feet 11210-11400 feet 11440-11610 feet 11800-11930 feet 11990-12170 feet 12330-12620 feet 12820-12870 feet 12940-13048 feet True vertical depth: 8288-8304 feet feet 8304-8329 feet 8821-8824 feet 8825-8827 feet 8829-8829 feet 8826-8822 feet 8824-8821 feet 8821-8817 feet 8815-8814 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): �n!, ) Treatment descriptions including volumes used and final pressure: SCANNED MAY 16 401., 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 180 4340 12056 440 414 Subsequent to operation: 1112 26274 10155 450 1006 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Ed Exploratory ❑ Development H Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil EI Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer SignatureAi Phone +1 907 564 4424 Date 4/4/17 Form 10-404 Revised 5/2015 /772—L 57/b ``7--- RBDMS IA,APR — 5 2017 Submit Original Only • • Packers and SSV's Attachment PRUDHOE BAY UNIT 05-13B SW Name Type MD TVD Depscription 05-13B PACKER 4186.4 4061.09 7" Baker ZXP Top Packer 05-13B TBG PACKER 9787.25 7901.53 4-1/2" HES TNT Perm Packer 05-13B PACKER 9876.2 7961.05 7" Baker ZXP Packer 05-13B PACKER 9885.35 7967.17 7" Liner Top Packer 05-13B TBG PACKER 9929.16 7996.49 4-1/2" Baker SABL-3 Packer • • a� Q o 0 0 0 0 0 0 00 0) 0 0 co r(1-:-) 0 0 CO - N O O V O I� O OCCf)N LO 'Cr Ln Ln I� CO00 I,- (-) y 0 0 0 0 0 0 00 0 O O CO 3 Ln O co N O m v000o0oI- aOCD M0) CO V V 1-0 O CO N- M CO O O N- CO N- CO CO O N N CO I� Ln 6) O CA CO N CO CO 01 N N N CO CO N- CO CO CO CO N- a) 0i i I . 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N m N 7Rl3= CAN ® SA ETY NOTES:WELL ANGLE>70*@ 10981'.USE WELLHEAD= FMC 05-13B CAUTION IN WELLBORE,MAY BE DEWS FROM ACTUATOR= BAKER C MULTIPLE RSHING OPS."'ORIGINAL&05-13A OKB.LEV= 69' WELLBORES NOT SHOWN BELOW WHIPSTOCK"' BF.LEV= I I 4-1/2"CHROME TBG"' KOP= 10300' Max Angle= 96°@ 12828' 9-5/8"CSG,47#, 2539' 1-......„,x � �-- 2191' -�4-1/2"HES X NP,D=3.813" Datum MD= NA RS-95 XO TO GAS LET MANDRELS Datum TVD= 8800'SS N-80 BTC I\ ST MD -ND DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG, H 2718' 3 3873 3809 32 MMG DOME RK 16 08/18/14 72#,N-80 BUTT 1 2 7335 6177 49 KBG2 DOME BK 16 08/18/14 ID=12.347" 1 9642 7804 48 KBG2 DMY BK 0 02/06/11 TOP OF 7"LNR-SCAB —I 4182' ., 4182' H 9-5/8"X 7"ZXP LTP w/HMC LN2 HGR, • D=6.188" 9-5/8"CSG,47#,N-80 X0 TO RS-95 BTC —I1 84W • ♦ I ' ♦ 9759' —I4-1/2"HES X NP,D=3.813" Minimum ID =2.370" a@ 11484' .ir :t►♦ 9789' —17"X 4-1/2"FESS TNT FKR,D=3.956" 3-3/16" X 2-7/8" XO • 1 r ♦ 9824' H4-1/2"FE5 X NP,D=3.813" 7"SCAB LNR 26#,L-80 BTC-k& H{ 9878' 1e.e. 9878' H9-5/8"X 7"TACK SLV,ID=7.5" .0383 bpf,ID=6.276" 9885' —19-5/8"X 7"BKR LTP&LNR HGR,13=6.184" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, —1 9895' 1 .0152 bpf,D=3.958' f✓��( 9910' 7"X 4-112"11NiQUE OVERSHOT 9925' -{7"X 4-1/2"BKR SAB-L-3 HYD PKR D=??? 4-1/2"TBG STUB(02/02/11) H 9900• r 8 9-5/8"MLLOUT VVI DOW(05-13A)-10030'-10080' .4- 9977' H3.70"DEFLOYMBYTSLV,D=3.00" 9-5/8"CSG,47#,RS-95 BTC,ID=8.681" H —10080 4 9996' H3-1/2"FES X Nom,D=2.813' 41 ! /' 41 3-1/2'LNR,9.2#,L-80 STL,.0087 bpf,D=2.995" —1 10250' J-' 10250' —3-1/2" X 3-3116"XO,0=2.786" 1 1` 4-1/2'TBG, 12.6#,L-80 BTC-M, - I 10300' ', 10278' —4-1/2"FES X NE,D=3.813" .0152 bpf,D=3.958" j It • I 10300' —I4-1/2"WLEG,D=3.958" 7"VM-PSTOCK(01/25/08) —I 10347' V/.. 44 �--..♦�4 V/ V• MLLOUT VVIVDOW(05-13B) 10352'-10359' 7"LN?,29#,L-80 NSCC,.0371 bpf,D=6.184" —I 10347' I 44 `.`t. RA TAG(01/25/08) H 10357' ■ ♦��♦4., S 10990' 1-13-3116"WFD CEP(03/14/17) F �/,PERFORATION `� � 11484' H3-3/16"X 2-7/8"XO,C4=2.370" REF LOG:MF3IADRY CNJGR/CCL on 02/01/08 ANGLE AT TOP PERF:35°@ 10326' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL C n/Sqz SHOT SOZ 12770' —2-7/8'VVRP 2-112" 6 10326-10376 0 03/15/17 , (09/17/15) 3-3/16"LNR,6.2#,L-80 TCI, — 11484' 2" 6 11210-11400 C 02/03/08 0076 bpf,D=280" 2" 6 11440-11610 C 02/03/08 , , 2" 6 11800-11930 C 02/03/08 2' 6 12330- 12620 C 02/03/08 /,♦�4•0 PBTD(02I01/08) — 13059' *i 2" 6 12820-12870 C 02/03/08 2" 6 12940-13048 C 2/3/2008 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,D=2.441" H 13095' DATE REV BY COMMENTS DATE REV BY OOMMB'TS PRUDHOE BAY UNIT 07/03/77 ROW 35 ORIGINAL COMPLETION 08/26/14 STF/JMD GLV CIO(08/18/14) WELL: 05-13B 07/13/94 N2ES SIDETRACK(05-13A) 09/23/15 JOMYJMt7 SET WFD WRP(09/17/15) PERMT No: 2071460 06/20/98 D-16 LAST WORKOVER 03/17/17 N-W/J1,13 SET CBP&ADPBRFS(03/14-15/17) AR No: 50-029-20250-02 02/02/08NORDIC 1 CTD SIDETRACK(05-13B) SEC 32,T11N,R15E,2265'FN-&112'FWL 02/06/11 N7ES IVO 07/01/14 D-14 MO(FISH WRP) BP Exploration(Alaska) STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI • REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ / Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ;t--Yt l 1")C P £ 1171-- 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-146 3. Address: P.O.Box 196612 Anchorage, Development Il Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number 50-029-20250-02-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 05-13B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13107 feet Plugs measured 12770 feet RECEIVED true vertical 8813 feet Junkmeasured feet Effective Depth: measured 12770 feet Packer measured See Attachment feet OCT 0 6 2015 true vertical 8824 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"94#H-40 29-108 29-108 1530 520 Surface 2687 13-3/8"72#N-80 29-2716 29-2716 4930 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11210-11400 feet 11440-11610 feet 11800-11930 feet 11990-12170 feet 12330-12620 feet 12820-12870 12940-13048 feet True vertical depth: 8821 -8824 feet 8825-8827 feet 8829-8829 feet 8826-8822 feet 8824-8821 feet 8821 -8817 8815-8814 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) _. 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JAN 2 0 2016 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 well operation: 194 3650 12327 1900 479 Subsequent to operation: Shut-In 460 14.Attachments:(required per 20 AAC 25 070 25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development p Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 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 Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer a Signature e,i Phone +1 907 564 4424 Date 10/5/15 Form 10-404 Revised 5/2015 1 RBDMS (11,I - 7 2015 Submit Original Only (o4'/ • • Packers and SSV's Attachment PBU 05-13B SW Name Type MD TVD Depscription 05-13B PACKER 4188.3 4062.52 7" Baker ZXP Top Packer 05-13B TBG PACKER 9789.15 7902.8 4-1/2" HES TNT Perm Packer 05-13B PACKER 9878.1 7962.32 7" Baker ZXP Packer 05-13B PACKER 9887.25 7968.45 7" Liner Top Packer 05-13B TBG PACKER 9931.06 7997.76 4-1/2" Baker SABL-3 Packer • • a) Q o O O O O O O 0, cp O O N � CO CO 00 r N up M V O O N O CC) CCD 41 ON- OD 00 I2 U y O O O O C) O O CD O L M M CC) I- CC) Nt CO ,, N M CC) 0) CO c- N r- c0 V O NY 00 CO co r• 00 O) 00 CO CO CA Nt CO CA CO N- co V v- MO r- co CO CO CO O N N v- CO N- I- 41 v- O CA co N 00 00 CA N r N N t` CO I.- CO 00 00 00 00 H CO CO M V 00 CO N- N- CD CA N- co N- CO M N N N Co N- N N N co CA O CD O N CO N CA N CO V N- 00 co 00 N- a) OOMO � NO � LC) OCO co r M M M l(7 In OO O)CD O 04 CNI CO CD 03 CD CD 01 op CD C- 0 I I I I I �+ m Q r O CD N CO M CO 00 f� O M CC) O N N N 41 CO CA N N CA L() N 00 Nt CA CA C) CA 0 M CD F'' 0- to OD 0CDCrn CCD D CD 5c00 O i 00 Z Z i 00 CO N N J J N• 'N03 (n g co CD 0) CO Cfl C�j U � N _ CO -— O ao oo Cq Nd, j 1.1) N... M f— (V CA CA CD M N i 4 +' I— CA N- r` COCID r- O C7 O) 00 O C)) C)) 0) N M M c- 00 co C N- O d N N CO '— O N v V J Z Z Z CID 000 C E- W E- E- E- V) 0 0 000 asDDDD 0Cu_ Co0 W' CCCC � ZZ Z a 0 0 0 W W W W W m m 0 D Z Z Z Z Z J D U U) d J J J J J I- E- 0 • / \ cri - F-o > § § $ 4_ o & (/) 7/ / ° p a)/ � / % .g _ & _ 0 2 .)o v-� £ = ou= o >cantƒ o R . oo c a -0a. ¥ z ftG \ al � \ / E \/ 9 7 9 f \ § y / �2k2 � 0 f 7-1 cts < - / / / R E o L. 7 \ / / 2iI \ (j) >-, Or / a / ® /27 \ CD 1- / / / k • / � / 4 � d / � kkUJ l � / o M A o ct 2 a 0 0 0- k» CI s- $ 1 S / 0 2 k -±- 73 a) mI m § / owed Ce o 0 f 0 - j & c o >6 -, in _, � ® \tom 2 ° 0 Q ~ / C3 $ ,- 2 / e . ® ¥ R , 7 O r o c C / , / _ E \ r G 2 2 c ¥ Al $ a + / b n / & _c y \ % - a % 0 ' - ' 3 / 2 � > 0 k / C.0 g a CO / _ . O ° / ± / / 2 ) o # m / - / - co o .6 0 / ® U 2 # O % 2 + f E f / ƒ L / r m ¥ / \ mom _e ¥ d % a- 5 0 k / < TREE= CMJ SAF NOTES:WCL ANGLE>70"@ 10981'.USE 4IIaLFEAD= FMC • 05-13B 5-13B CA IN WELLBORE,MAY BE DEBRIS FROM ACTUATOR= _ BAKB2 C OKB ��= MUL LE FISHING OPS."""'ORIGINAL&05-13A ��= WELLBORES NOT SHOWN BELOW WHIPSTOCK*" BF. 4-1!2"CHROME TBG""' KOP= 10300'1 Max Angle= 96'@ 12828' 9-5/8'CSG,47#, --{ 2539' I V 2191' {--4-1/2"FES X N8?D=3.813" Datum MD= NA RS-95 XO TOxc GAS LFT MADS D3tum1VD= 8800 SS N-80 BTC ' ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG, 2718' ....J 3 3873 3809 32 MAG DOME RK 16 08/18/14 72#,NF-80 BUTT 21 7335 67177 49 KBG2 DOME BK 16 08108/14 13=12.34r 1 9642 7804 48 KBG2 OMY BK 0 02/06/11 TOP OF r LN2-SCAB H 4182' 4182' —9-5/8"X r ZXP LTP w/MAC LN2 HGR, D=6.188' • 9-5/8"CSG,47#,N-80 X0 TO RS-95 BTC —I 8436' }-- 4• 4 9759' --14-1/2"FES X NP,D=3.813' Minimum ID =2.370" @ 11484' :0. 9789' -17"X 4-1/2"HES TNT PKR,D=3.956" 3-3/16" X 2-7/8"XO + 9824' {—4-1/2'I-ES X t*,D=3.813" r , 7"SCAB LN.26#,L-80 BTC-M, — 9878' 0383 bpf,D=6.276" 9878' —19-5/8"X r T�ApC SLV,D=7.5" 9885' —9-5/8"X r BKR LTP&LNR HGR,D=6.184" 4-1/2"TBG,12.6#,13CR-86 VAM TOP, —{ 9895' .0152 bpf,D=3.958' 9910' —7'X 4-1/2"UNIO E OVERSHOT 9925' H 7"X 4-1/2'BKR SAB-L-3 HY D PKR,D=??? 4-1/2"TBG STUB(02!02/11) H 9900• 9-5/8"MLLOUT WIDOW(05-13A)-10030'-10080' 9977' ---13.70'DEPLOYMENT SLV,D=3.00' 9-5/8'CSG,47#,RS-95 BTC,D=8.681" —I —10080 I--..., 9996' --I 3-1/2"FES X NP,D=2.813' 3 112"LNR 92#,L-80 SIL,.0087 bpf,D=2.995' —f 10250' + 10250' 3-1/2- X 3-3/16"XO,D=2.786" 4-1/2"TBG,12.6#,L-80 BTC-M, —{ 10300' + ii 10278' H4-1/2"HES X Ni?D=3.813' .0152 bpf,13=3.958" 4 )1 10300' —14-1/2"W.EG,0=3.958" r wt-FSTOO((01/25/08) H 1034T ,444 t'tr 4444 •s r LNR,29#,L-80 NSCC,.0371 bpf,D=6.134' -I 1034T 4'1, �'� "�I " W(06 138) 10352 -10359' RA TAG(0125/08) H 10367' a4,No , 44 PERFORATION SUMMARY11484' 3-3116"X 2-718"XO,D=2.370" REF LOG:M ENORY CNJGR/C L on 02/01/08 ANGLE AT TOP PEFF:87"1r 11210' Note:Refer to Production DB for historical perf data 12770 —2-7/8"VW ' SIZE SPF INTERVAL Opn/Sqz SHOT SQZ , 2" 6 11210-11400 0 02/03/08 3-3/16"LNR,6.2#,L-80 TCI, 11484' 017/15) 2' 6 11440-11610 0 02/03/08 .0076 bpf,D=2.80" 2" 6 11800-11930 0 02/03/08 '4 , 2' 6 11990-12170 0 02/03/08 2" 6 12330-12620 0 02/03/08 /4ii, 2' 6 12820-12870 C 02/03/08 PBTD(02/01/08) --I 13069' +Vi 2' 6 12940-13048 C 2/3/2008 2-7/8'LNJR,6.16#,L-80 STL,.0058 bpf,D=2.441" H 13095' DATE REV BY COMMENTS DATE REV BY COMMENTS F UDHOE BAY LAW 07/03177 ROW 35 ORIGINAL COMPLETION 07/07/14 PJC DRLG HO CORRECTIONS Mitt 05-13B 07/13/94 WEB SIDETRACK(05-13A) 07/07/14 !MAID ADCED SAFETY NOTE PERMT No: 2071460 06!20/98 0-16 LAST WORKOI/BR 07/07/14 JPA) PERF/LEGEND CORRECTIONS AR No: 50-029-20250-02 02/02/08IIORDIC 1 CTD SIDETRACK(05-138) 0826/14 STF/JMD GLV CIO(08/18/14) SEC 32,T11N,R15E,2265'FN..&112'PAIL 02/06111' N7133 f6NO 09/23/15 JDMJMD SET WFD WRP(09/17/15) 07/01/14 0.14 RAO(FISH WPP) BP Exploration(Alaska) ~ i Image Project Well I-listor~ 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. p~Q ~ - ~ ~- ~ Well History File Identifier Organizing (done) ^ Two-sided III II~III II III II III ^ Rescan Needed III II'lll II II III III RESCAN DIGI AL DATA OVERSIZED (Scannable) for Items: iskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: o /s/ ProjectProofing III IIIIIIIIIII VIII BY: Maria Date: ~ ~- D /s/ Scanning Preparation cc x 30 = + _ ~- =TOTAL PAGES___~'t ' (Count does not include cover she ) BY: Maria Date; Q ~ /s/ T ~ ~ III IIIIIIIIIII VIII Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scan ing reparation: ~ YES NO BY: Maria Date: I ~. Q /s/ '~ ~/ 1, ~j r Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'I II I II N II III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III II'I III p P 10/6/2005 well History File Cover Page.doc STATE OF ALASKA ALASipIL AND GAS CONSERVATION COMMI N RECEIVED' REPOR OF SUNDRY WELL OPERA ONS MAP, 1, 8 011 Aurka 1. Operations Performed: .. ; ca C omm in ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Weil _ . ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other 0 ' 3i '5 ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory + 207 - 146 3. Address: ❑ Service ❑ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 •50 - 029 - 20250 - 02 - 00 7. Property Designation: 1 8. Well Name and Number: ADL 028325 & 028326 or PBU 05 - 13B 9. Field / Pool(s): e Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 13107 feet Plugs (measured) 9975 / 9996 feet true vertical 8813 feet Junk (measured) None Effective depth: measured 13059 feet Packer. (measured) 9789 / 9925 feet true vertical 8814 feet Packer. (true vertical) 7903 / 7994 feet Casing Length Size MD ND Burst Collapse Structural Conductor 112' 20" 112' 112' 1530 520 Surface 2718' 13 -3/8" 2718' 2718' 4930 2670 Intermediate 10030' 9-5/8" 10030' 8064' 6870 4760 Production Liner 6171' 7" 4182' - 10353' 4058' - 8310' 8160 7020 Liner 3118' 3-1/2" x 3 -3116° x 2 -71 9977' - 13095' 8029' - 8813' 10160 10530 s, ;; Perforation Depth: Measured Depth: 11210' - 13048' (below plugs) mAR 2 4 f O u True Vertical Depth: 8821' - 8814' Tubing (size, grade, measured and true vertical depth): 4 , 12.6# 13Cr - 9910' MD 7984' TVD 4 - 1/2 ", 12.6# L - 80 9900' - 10300' 7977' - 8266' ND Packers and SSSV (type, measured and true vertical depth): 7" x 4 HES TNT Packer 9789" MD 7903' TVD 7' x 4 BKR SAB L - 3 HYD Packer 9925' MD 7994' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Set plug. Cut and pulled 4 tubing from 9900'. Dressed off stub and ran new 4 - 1/2 ", 12.6#, 13Cr - 85 tubing. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory • -' Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ * :4 Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Wilmer Hoffman, 564 -4592 N/A Printed Name Elizabeth Barker / //� J //�) Title Drilling Technologist ;, K i Prepared a rker Signature P /� Phone 564 -5674 Date Elizabeth Barker, 564 -566456 74 Form 10-404 Revised 1 010 RBDMS MAR 21 2011 ireir,v 3.23g Submit Original Only . . 05 -13B Well History (Pre Rig Workover) Date Summary 12/3/2010 PULLED INTACT 4 -1/2" WFD WRP FROM 8595' SLM /8580' MD. DRIFTED & TAGGED TOP OF LINER TOP 9932' SLM/9976' MD, W/ 3.77" WFD DRIFT. 12/5/2010 SET 4 -1/2" WFD WRP © 9927' SLM/9975' MD. 12/6/2010 LRS PERFORMS PASSING CMIT -TxIA TO 3500# ON SECOND ATTEMPT.DUMP BAILED 2 BAGS OF SLUGGITS ON 4 -1/2" WFD WRP © 9927' SLM/9975' MD. SET 4 -1/2" JUNK CATCHER ON TOP OF SLUGGITS, TOP OF SLUGGITS © 9913' SLM. LRS PERFORMS SUCESSFULL MIT -OA TO 2000# 12/6/2010 CMIT -TxIA PASSED to 3500 psi. MIT -OA PASSED to 2000 psi (RWO prep) CMIT -TxIA; Passed on second attempt. Pumped 11 bbls crude down IA to reach test pressure. TBG /IA lost 180/140 psi in the 1st 15 mins and 100/100 psi in the 2nd 15 mins. Repressured TBG /IA to 3500 psi with 2 additional bbls of crude. TBG /IA lost 100/60 psi in the 1st 15 mins and 0/20 psi in the 2nd 15 mins for a total loss of 100/80 psi during the 30 min test. Bled TBG /IA to 500 psi (approx 7.5 bbls) MIT -OA; Passed on second attempt. Pumped 13.8 bbls crude down OA to reach test pressure. OA lost 200 psi in the 1st 15 mins and 30 psi in the 2nd 15 mins. Repressured OA to 2000 psi with 0.2 additional bbls of crude. OA lost 100 psi in the 1st 15 mins and 0 psi in the 2nd 15 mins for a total loss of 100 psi during the 30 min test. Bled OA to 200 psi (approx. 2.3 bbls). 12/9/2010 PPOT -T (PASS), PPPOT -IC (PASS) Stung into test port (20+ psi), bled to 0 psi. Functioned LDS (Standard), all moved freely (1.5 "). Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (300 psi), bled to 0 psi. Functioned LDS (Standard), all moved freely (1.5 "). Pressured void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 12/14/2010 JET CUT TUBING AT 9896', IN MIDDLE OF FIRST FULL JOINT ABOVE PACKER. DEPTH CORRECTED TO TUBING TALLY. USED 3.65" SCP POWER CUTTER. 1/5/2011 Spear into IA w/0 bbls neat meth followed by 600 bbls 1% KCL to circ -out well taking returns down FL on 15 -12. Pump 150 bbls diesel down IA. U -tube diesel from IA to tbg for freeze protect. CMIT T x IA to 1000 psi. PASSED. Tbg /IA lost 70/70 psi in first 15 minutes & 30/30 psi in second 15 minutes. Total loss= 100/100 psi. Bleed tbg & IA pressures down to 0 psi. Freeze protect FL on 15 -12 w/ 5 bbls neat met & 45 bbls crude. Perform second CMIT to 1000 psi as per FB PE. PASSED. Tbg/ IA lost 60 psi in first 15 minutes & 20 psi in second 15 minutes. Bleed pressures down to 0 psi. 1/6/2011 Verified barriers. Rigged up lubricator and pressure tested to 300 psi low and 3500 psi high. (passed) Set 4" FMC ISA BPV w/ 1 -2' ext. © 98" Pre RWO. Tested tree cap connection to 500 psi upon completion. 1/7/2011 Bleed WHPs to 0 psi. (RWO prep). OA FL near surface. Bled OAP from 250 psi to 80 psi in 1 hr 6 min to slop trailer (Multiple bleeds, FTS). Monitored for 30 min. OAP increased 40 psi to 120 psi. Page 1 of 1 TREE = CIW SAFETY : *** WELL ANGLE> 70 @ 10981' * ** WELLHEAD = FMC 05 -13 B `*`ORIGI 05- 13A NOT SHOWN ACTUATOR = BAKER C BELOW WHIPSTOCK 4 1/2" CHROME KB. ELEV = 62.5' BF. ELEV = I I 2191' 1-14-1/2" HES X NIP, ID = 3.813" KOP = 10300' ' ' GAS LIFT MANDRELS ' Max Angle = 96° @ 12828' 13 -3/8" CSG, --I 2718' I A ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum MD = NA 72 #, N -80 3 3873 3809 32 MMG DOME RK 16 03/05/11 Datum TVD = 8800' SS I ID = 12.347" 2 7335 6177 49 KBG2 SO BK 20 03/05/11 1 9641 7804 48 KBG2 DMY BK 0 02/06/11 !TOP OF 7" LNR -SCAB I I 4182' I 4182' I- 9 -5/8" X 7" ZXP LTP w /HMC LNR HGR, 1 ID = 6.188" • Minimum ID = 2.370" @ 11484' ' !; I 9759' I-I4-1/2" HES X NIP, ID = 3.813" I 3- 3/16" X 2 -7/8" XO 0 4, _ 9789' H7" X 4 -1/2" HES TNT PKR, ID = 3.956" I 1 ' • •, I 9824' HI4 -1/2" HES X NIP, ID = 3.813" I • 7" SCAB LNR, 26 #, L -80 BTCM, ID = 6.276" I 9878' • ' � 9872' H 9 -5/8" X 7" ZXP PKR, ID = ?? I I TOP OF 7" LNR H 9878' mi l led I ° 4-1/2" TBG, 12.6 #, 13CR -85 VAM TOP, -I 9895' ` 9910' H7" X 4-1/2" UNIQUE OVERSHOT I .0152 bpf, ID = 3.958" 1 9925' HT X 4 -1/2" BKR SAB -L -3 HYD PKR, ID = ? ?? I 14-1/2" TBG STUB (02/02/11) H 9900' g ■ I 9975' J -I4 -112" WRP(12/05;10) I 9 -5/8" MILLOUT WINDOW (05 -13A)- 10030' - 10080' :i 9976 3.70" DEPLOYMENT SLV, ID = 3.00" -13-1/2" T 9996' HES X NIP, ID = 2.813" I •••• • • • • 1 9996' I - 12.81" PX PLUG (04/07110) I � •• I. • A 1 1 3 -1/2" LNR, 9,2 #, L -80 STL, .0087 bpf, ID = 2.992" I--I 10250' I I 10250' 1 -13 -1/2" X 3- 3/16" XO, ID = 2.786" I P • 1 4 -1/2" TBG, 12.6 #, L -80 BTC-M, 10300 I1 ■ '� 10300' I 10278' H4-1/2" HES X NIP, ID = 3.813" I .0152 bpf, ID = 3.958" i 1 14 . ► 10300' 1-14-1/2" WLEG, ID = 3.958" 7" WHIPSTOCK (01/25/08) I-J 10347' ••• .4 1�• 0 1•'• 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 10347' 1/ MILLOUT WINDOW (05-13B) 10352' - 10359' 4. s• , IRA TAG (01/25/08) H 10357' ♦ 4 4v 1 , 11484' -13-3/16" X 2 -7/8" XO, ID = 2.370" I PERFORATION SUMMARY I ■ REF LOG: MEMORY CNL/GR/CCL on 02/01/08 ANGLE AT TOP PERF: 87° @ 11210' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE , 2 6 11210 - 11400 C 02/03/08 3- 3/16" LNR, 6.2 #, L -80 TCII, 11484' 2 6 11440 - 11610 C 02/03/08 .0076 bpf, ID = 2.80" 2 6 11800 - 11930 C 02/03/08 2 6 11990 - 12170 C 02/03/08 2 6 12330 - 12620 C 02/03/08 �4�•, 1 2 6 12820 - 12870 C 02/03/08 I PBTD (02/01/08) H 13059' 2 6 12940 - 13048 C 2/3/2008 12 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.441" I-1 13095' DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 1977 ORIGINAL COMPLETION 05/09/11 DAV /PJC GLV /O / BAIL SLUGGfTS (03/05 11) WELL: 05 -13B 08/22/94 SIDETRACKED 03/10/11 TAR/PJC JNK CATCHER PULLED RIG PERMIT No: '2071460 06/20/98 LAST WORKOVER API No: 50- 029 - 20250 -02 -00 02/03/08 NORDIC 1 CTD SIDETRACK (05 -13B) SEC 32, T11 N, R15E, 2265' FNL & 112' FWL 02/06/11 N7ES RWO 02/21/11 ? /JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • North NorikAtherica - A LASl , gp , Page oft! i Common Well Name: 05 -13 1 AFE No Event Type: WORKOVER (WO) Start Date: 1/25/2011 End Date: 2/6/2011 X4- 00RYF -E (2,136,000.00 ) Project: Prudhoe Bay Site: PB DS 05 1 Rig Name /No.: NABORS 7ES Spud Date/Time: 6/29/1994 12:00:00AM ;Rig Release: 2/6 /2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292025000 Active Datum: 05 -13 @69.00ft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/28/2011 12:00 - 00:00 12.00 MOB N WAIT PRE WAIT ON PAD WORK TO BE COMPLETED - RD PITS & MEZZANINE - CHANGE OUT 4" STANDPIPE VALVE PREP FOR MOVE REMOVE PINS - HOUSE CLEANING -WORK MAINT. ISSUES 1/29/2011 1 00:00 - 10:30 10.50 MOB N WAIT PRE WAIT ON PAD WORK TO BE COMPLETED ON 5-138 - CUT 4" STANDPIPE VALVE OUT AND REPLACE & RE-WELD - WORK ON NEXT MONTHS PM WORK ORDERS COMPLETE DERRICK INSPECTION - INSTALL CHOKE HOSE TO BOP STACK 10:30 - 11:30 1.00 MOB P i PRE SAFETY STAND DOWN UNSECURED VEHICLE WITH BLYDENBURGH'S CREW 11:30 - 12:30 1.00 MOB P PRE SAFETY STAND DOWN UNSECURED VEHICLE WITH JOHNSON'S CREW 12:30 - 00:00 11.50 MOB N WAIT PRE WAIT ON PAD WORK TO BE COMPLETED ON 5-13B INSPECT HAYLON FIRE SUPPRESSION 'SYSTEM PRE- MOVE TIRE INSPECTION I- INSPECT OILER LINE & HOSE ON #2 MUD PUMP 1/30/2011 00:00 - 05:30 5.50 MOB N WAIT PRE 05:30 - 11:00 5.50 MOB N WAIT PRE RIG ON STANDBY WAITING ON TRUCKS DUE TO SHORTAGE OF PERSONNEL ( MOVING RIG 41) - WO TRUCKS TO MOVE PITS. - STAGE RIG MATS, HERCULITE AND I I WELLHEAD EQUIPMENT WHILE WAITING - FUNCTION TEST RIG MOVING HYD. SYSTEMS AND CONTROLS 11:00 - 15:00 4.00 MOB P PRE TRANSPORT - PJSM, RAISE MUD PITS, CONNECT TRUCK & PULL RIG MATS - MOVE PITS AND SUB FROM 5 -30 TO 5 -13B. - HANG X -TREE IN CELLAR 1 - SPOT SUB AND LEVEL. 15:00 - 16:30 1.50 MOB N WAIT PRE RIG ON STANDBY WAITING ON PEAK TRUCKS TO SPOT PITS - RU DOUBLE ANN. VALVE ON OA AND IA (IA 0 PSI) - RU CIRC EQUIPMENT IN CELLAR - CHANGE OUT ROTARY MOTOR IN TOP DRIVE 16:30 - 21:00 4.50 RIGU P PRE SPOT PITS, SPOT CUTTINGS BOX. RU STEAM AND SERVICE LINES - CONT TO RIG UP CIRC LINES IN CELLAR 1** VISUAL INSPECTION ON BOP WITH BORE ! ' I SCOPE** NORMAL WEAR & TEAR. ALL SEALING ' SURFACES LOOKED GOOD. NO ISSUES Printed 3/4/2011 10:39:36AM • 4 O Sul 1 mary Repor Common Well Name: 05 -13 j AFE No Event Type: WORKOVER (WO) Start Date: 1/25/2011 End Date: 2/6/2011 1X4 OORYF -E (2,136,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 6/29/1994 12:00:00AM Rig Release: 2/6/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292025000 Active Datum: 05 -13 @69.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 22:00 1.00 RIGU P PRE PERFORM RIG EVAC DRILL AND AAR - PRE SPUD MTG WITH CREWS 22:00 - 23:00 1.00 RIGU P PRE RU HARD LINE AND MANIFOLD FOR SEAWATER TO IA _ - PRESS TEST TO 3500 PSI 23:00 00:00 1.00 RIGU P PRE RU & TEST MASTER VALVE & SWAB VALVE PRIOR TO PULLING TREE CAP - 250 PSI LOW, AND 3000 PSI HIGH FOR 5 MIN EACH. ** RIG ACCEPTED AT MIDNIGHT ** 1/31/2011 00:00 - 01:00 1.00 RIGU P PRE RU & TEST MASTER VALVE & SWAB VALVE PRIORTO PULLING TREE CAP 1 - 250 PSI LOW, AND 3000 PSI HIGH FOR 5 MIN EACH. PASSED 01:00 - 02:00 1.00 RIGU P PRE RU LUBRICATOR TO TREE & TEST I i 1 250 PSI LOW, AND 3000 PSI HIGH FOR 5 MIN EACH. PASSED 02:00 - 02:30 0.50 RIGU P PRE I PULL BPV & RD LUBRICATOR 02:30 - 03:00 0.50 WHSUR P DECOMP 1 RU LINES TO CIRC OUT FREEZE PROTECT 03:00 - 07:00 4.00 WHSUR - P DECOMP DISPLACE FREEZE PROTECT WITH 8.5 PPG SEAWATER REV CIRC @ 3 BPM, 400 PSI. i- PUMPED 42 BBLS SEAWATER, RECOVER 32 BBLS DIESEL SWAP LINES _ CIRC CONV. @ 3 BPM, 100 PSI. - PUMPED 50 BBL 120 DEG SOAP SWEEP FOLLOWED BY 522 BBLS 8,5 PPG, 120 DEG SW INCREASED PUMP RATE TO 5 BPM, 590 PSI ONCE DIESEL CLEARED IA. - RECOVER 110 BBLS DIESEL i I i TOTAL DIESEL RECOVERED = 142 BBLS MONITOR WELL FOR 10 MIN. TBG & IA STATIC 1 RD LINES 07:00 - 08:30 1.50 1 WHSUR P DECOMP ! RU LUBRICATOR TO TREE & TEST 250 PSI LOW, AND 3000 PSI HIGH FOR 5 MIN EACH. PASSED 08:30 - 09:30 1.00 WHSUR P DECOMP INSTALL BPV & TEST - TEST FROM BELOW TO 1000 PSI FOR 10 MIN. PASSED - RD LUBRICATOR 09:30 - 13:00 3.50 j WHSUR P DECOMP ► I TR : ADAPTER - FMC BLEED OFF 2 CONTROL LINES & TBG HANGER VOID - ND TREE & ADAPTER - INSPECT 5.75" LH ACME TBG HANGER THREADS. THREADS LOOKED GOOD. - MU X -O WITH 11.5 TURNS TO THE LEFT - MU ISA BLANKING PLUG WITH 9.25 TURNS TO THE LEFT 13:00 - 17:00 4.00 BOPSUR P DECOMP ! 1 NU BOPS - NU SPACER SPOOL & BOPS - INSTALL RISER Printed 3/4/2011 10:39:36AM �� $!E Witt VArikerta, ALA � Pago 3vf8 - Opera Summary Repor Common Well Name: 05 -13 AFE No Event Type: WORKOVER (WO) Start Date: 1/25/2011 End Date: 2/6/2011 X4- 00RYF -E (2,136,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES 1 Spud Date/Time: 6/29/1994 12:00:00AM Rig Release: 2/6 /2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292025000 Active Datum: 05 -13 ©69.00ft (above Mean Sea Level) Date From - To Hrs Task ! Code NPT NPT Depth Phase I Description of Operations (hr) (ft) 17:00 - 22:00 5.00 BOPSUR P DECOMP TEST BOPE - TEST BOPE AND CHOKE MANIFOLD TO 250 PSI LOW AND 3,500 PSI HIGH FOR 5 MIN EACH WITH 4 -1/2" TEST JOINT. PASSED P TEST ANNULAR PREVENTER TO 250 PSI � LOW AND 3,500 PSI HIGH FOR 5 MIN EACH WITH 4-1/2" TEST JOINT. PASSED CONDUCT ACCUMULATOR FUNCTION TEST. PASSED i AOGCC REP JOHN CRISP WAIVED WITNESS TO TEST. TEST WITNESSED BY NAD TOUR PUSHER LENWARD TOUSSANT AND BP WSL ;JEFF LOFTIS. 22:00 - 23:00 1.00 BOPSUR P j DECOMP `TEST STANDPIPE MANIFOLD I - MANIFOLD DID NOT TEST. PIN HOLE LEAK ON HP SENSOR. MANIFOLD. 23:00 - 00:00 1.00 BOPSUR . ' N RREP DECOMP RIG REPAIR j - REPAIR STANDPIPE MANIFOLD 2/1/2011 00:00 - 02:00 2.00 BOPSUR " N RREP DECOMP REPAIR STANDPIPE & TEST - TEST STANDPIPE 250 PSI LOW, 4500 PSI HIGH FOR 5 MIN. PASSED 02:00 - 03:00 j 1.00 BOPSUR P ' . DECOMP PULL ISA BLANKING PLUG 03:00 - 04:30 1.50 I BOPSUR P DECOMP { RU LUBRICATOR TO DUTCH RISER & TEST - TESTING FROM BELOW & ABOVE BPV - INITIAL TEST FAILED DUE TO LEAK ON OUTSIDE IA CSG VALVE FLANGE - CHECK MAKE UP NUTS ON FLANGE - RE -TEST - 250 PSI LOW, AND 3000 PSI HIGH FOR 5 MIN EACH. PASSED / 04:30 - 06:00 j 1.50 BOPSUR P - DECOMP PUI I :Ey ' - DID NOT HAVE BPV ON 1ST ATTEMPT - RETRIEVED BPV ON SECOND ATTEMPT - LD LUBRICATOR & EXTENSION 06:00 - 07:30 1.50 PULL P DECOMP RU TBG TOOLS & SPOOLER 07:30 - 08:30 1.00 PULL DECOMP PULL TBG HANGER & LD - ENGAGE TBG HANGER - UNSEAT HANGER W 145K PUW - PULL TBG HANGER ABOVE ROTARY TABLE 1W135KPUW. - MONITOR WELL - WELL STATIC - LD TBG HANGER i I 18.5 PPG SEAWATER - WELL ST TIC ....----. 08:30 - 11:00 2.50 PULL P DECOMP CIRC BARACLEAN SWEEP V 9BPM @1240PSI — — - TAKE SPR 11:00 - 13:30 2.50 PULL P j DECOMP I POOH WITH 4.5" TBG & CONTROL LINES - RU SPOOLER TO CONTROL LINES - POOH W/ TBG AND LAY DOWN SAME 9870' TO 8910' MD - INITIAL PUW 130K, 105 K SOW 13:30 - 15:00 1.50 PULL N RREP ! 8,910.00 DECOMP RIG REPAIR 1 - TROUBLE SHOOT PIPE SKATE - FAULTY RELAY FOR PIPE BUGGY - REPLACE RELAY Printed 3/4/2011 10:39:36AM testa , 045! 4 (1 �F 4`of 8 ple Summlary RepoEt . Common Well Name: 05 -13 AFE No Event Type: WORKOVER (WO) Start Date: 1/25/2011 I End Date: 2/6/2011 X4- OORYF -E (2,136,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 6/29/1994 12:00:00AM Rig Release: 2/6/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292025000 -- - -- - -- - -- - - - - -- Active Datum: 05 -13 @69.00ft (above Mean Sea Level) Date From - To Hrs Task j Code NPT j NPT Depth Phase Description of Operations (hr) (ft) : I DECOMP POOH WITH 4.5" 15:00 - 00:00 9.00 PULL P TBG & CONTROL LINES 9810' I TO 1354' MD - PULL TO SSV & LD - RD CAMCO SPOOLER LD 2 GLM RECOVER 52 SS BANDS 2/2/2011 00:00 - 02:30 2.50 PULL P DECOMP POOH WITH 4.5" TBG 1354' TO CUT OFF JNT. RECOVER 238 JNTS 4.5" TBG & 1 CUT OFF JOINT (20.74' IN LENGTH) TOTAL OF 1 SSV, 3 GLM, 52 SS BANDS 02:30 - 03:30 1.00 PULL P DECOMP I RD TBG HANDLING EQUIPMENT AND CLEAR I FLOOR 03:30 - 05:30 2.00 BOPSUR P DECOMP TEST BOPS WITH 4" TEST JOINT -TEST ANNULAR, LOWER & UPPER PIPE RAMS -250 PSI LOW, AND 3500 PSI HIGH FOR 5 MIN I EACH, PASSED RD TEST EQUIPMENT & BLOW DOWN LINES 05:30 - 07:30 2.00 CLEAN P DECOMP PICK UP DRESS OFF BHA 6" DRESS OFF SHOE, (3) - 5.75" WASH PIPE EXT „4- 13/16” X 3 -7/8" DRESSING MILL, 5.75" WOBB, (2) STRING MAGNETS, X -O -7" CSG SCRAPER, X -O, BUMPER SUB, OIL JARS, PO SUB, (6) 4.75" DC'S, X -O, DP G i TOTAL LENGTH = 245.03'. - MAX OD = 6" X 5" DRESS OFF SHOE - MIN ID = 0.75" -- INNER TUBING DRESS OFF MILL. 07:30 - 14:30 7.00 CLEAN P DECOMP I PU DP & TIH 245' TO 6646' - TAG LINER TOP @ 4182'. SET DOWN SLOWLY WITH 5-7K - PU & ROTATE PAST LT @ 5 -10 RPM -PUW 90K, SOW 90K 14:30 - 15:00 0.50 CLEAN P DECOMP I SERVICE TOP DRIVE 15:00 - 15:30 0.50 CLEAN N RREP 6,649.00 DECOMP I RIG REPAIR - REPAIR BROKEN CHAIN GAURD ON PIPE ;SKATE 15:30 - 18:00 2.50 CLEAN P DECOMP ! CONT. PU DP & TIH 6646' TO 9739' _ ____ - - - - -- PUW 160K, SOW 135K 18:00 19:00 1.00 CLEAN P DECOMP WORKING PIPE & CIRC TO EST. PARAMETERS - CIR @ 5 BPM, 690 PSI. 60 RPM 3.5 K TQ. ROT W 147K - PUMP HIGH VIS SWEEP WHILE WORKING PIPE - WASH & REAM 9739' TO 9833' - DROP PUMP RATE TO 3 BPM, 270 PSI - WASH & REAM - TAG TOP OF TBG STUB @ 9898.5' MD Printed 3/4/2011 10:39:36AM • : P of 8 C on Summary Report: Common Well Name: 05 -13 AFE No Event Type: WORKOVER (WO) Start Date: 1/25/2011 End Date: 2/6/2011 X4- 00RYF -E (2,136,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES ; Spud Date/Time: 6/29/1994 12:00:00AM Rig Release: 2/6/2011 Rig Contractor: NABORS ALASKA DRILLING INC. j UWI: 500292025000 Active Datum: 05 -13 @69.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth li Phase Description of Operations (hr) (ft) 19:00 - 20:00 1.00 CLEAN P DECOMP 'WORKING DRESS OFF MILLS - WORK PIPE 9833' TO 9900' MD - DRESS -OFF TUBING STUB PER BAKER FISHING REP. - WOB = 1 -5 K LBS, 3 -5 K FT -LBS TORQUE. SWALLOW 16' TO INNER MILL. - 450 PSI INCREASE. I - WOB = 5K LBS. - WORK MILL AND MILL -1.5' OFF TUBING. - PU OFF OF TUBING STUB AT 9900' AND EASE BACK DOWN ON STUB SEVERAL TIMES WITH NO PUMP OR ROTATION. ** MONITOR WELL; WELL STATIC ** 20:00 - 21:30 1.50 CLEAN P DECOMP CIRC & COND - . - PUMP 30 BBL HIGH'VIS SWEEP 9 BPM @ 1700 PSI WHILE RECIP PIPE ** MONITOR WELL FOR 15 MIN; WELL STATIC ** **MW IN 8.5 PPG, MW OUT 8.5 PPG ** 21:30 - 00:00 2.50 CLEAN P DECOMP 1 TRIP OUT OF HOLE WITH DRESS OFF BHA x9900' TO 4193' 2/3/2011 00:00 - 02:00 2.00 CLEAN P DECOMP TRIP OUT OF HOLE WITH DRESS OFF BHA 4193' TO 245' - MONITOR WELL- WELL STATIC 02:00 - 02:30 0.50 ' CLEAN P DECOMP i LD DC'S 02:30 - 04:00 1.50 CLEAN P DECOMP LD DRESS OFF BHA - 6" DRESS OFF SHOE, (3) - 5.75" WASH PIPE EXT, 4- 13/16" X 3 -7/8" DRESSING MILL, 5.75" WOBB, (2) STRING MAGNETS, X -O 7" CSG SCRAPER, X -O, BUMPER SUB, OIL JARS, PO SUB 04:00 DECOMP PICK BHA #2 ( EAR ) 04:30 07:00 2.50 WHSUR P 00 04:30 0.50 WHSUR P DECOMP CLEAN & CLEAR RIG FLOOR 04 DEC I UP SP I - - -- 07:00 11 :00 4.00 WHSUR P DECOMP TIH W/ DP 129' TO 9529' / - PUW 155K, SOW 135K -- - — - - - -- 11:00 - 12:00 1.00 WHSUR P DECOMP !PU STORM PACKER & SET - RIH 1 STD BELOW ROTARY TABLE - SET RTTS PKR & HANG OFF STRING 12:00 - 14:00 2.00 WHSUR P DECOMP PRESSURE TEST PKR - TEST FROM BELOW 250 PSI LOW & 1000 PSI HIGH FOR 5 MIN EACH. PASSED - TEST FROM ABOVE 250 PSI LOW & 1000 PSI HIGH FOR 10 MIN EACH. PASSED - BACK OUT RTTS RUNNING TOOL 21 TURNS TO THE LEFT I- POOH & LD RUNNING TOOL 14:00 - 16:00 2.00 WHSUR P DECOMP I ND BOP 16:00 - 20:00 ', 4.00 WHSUR P DECOMP RD TBG SPOOL & 9 -5/8" PACK -OFF. - INSTALL VR PLUG IN OA. - CHANGE OUT OA VALVE & TEST TO 5000 � I i PSI FOR 5 MIN. 21:00 23:00 1.00 WHSUR P DECOMP INSTALL 9 -58" PACK -OFF :00 2.00 WHSUR P DECOMP I NU TBG SPOOL - TEST VOID TO 5000 PSI FOR 30 MIN. PASSED Printed 3/4/2011 10:39:36AM oath Ai1<1erica = ASt6A BP. Page 6 of 8 Opera#ion Summary Report Common Well Name: 05 -13 AFE No Event Type: WORKOVER (WO) Start Date: 1/25/2011 End Date: 2/6/2011 ;X4- 00RYF -E (2,136,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 6/29/1994 12:00:00AM I Rig Release: 2/6 /2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292025000 Active Datum: 05 -13 @69.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) ! (ft) 23:00 - 00:00 1.00 WHSUR P DECOMP NU BOP 2/4/2011 00:00 - 01:30 1.50 WHSUR P DECOMP NU BOP - NU BOP TO 13 -5/8" TBG SPOOL - HOOK UP KILL LINE 01:30 - 03:00 1.50 WHSUR + P DECOMP (TEST BOP - TEST BREAK AT TOP FLANGE ON TBG 10.):;,/if" SPOOL & BOP AND KILL LINE BREAK - 250 PSI, LOW & 3500 PSI HIGH FOR 5 MIN EACH ON CHART. PASSED 03:00 - 04:00 1.00 WHSUR j P DECOMP , RELEASE 'HALLIBURTON 9 -5/8" RTTS PACKER &` 1- MU HALLIBURTON RTTS RUNNING TOOL ON 4" STD OF DP RIH & ENGAGE PACKER ;- SECURE WELL WITH ANNULAR VERIFY 0 PSI BELOW PACKER - RELEASE PACKER PER HALLIBURTON TOOL REP. - VERIFY WELL IS STABLE ' - PUt I PA(:KFR W/ RI INNING TOOL & LD PUW 155K, SOW 135K - BLOW DOWN LINES MONITOR WELL - WELL STATIC 04:00 05:30 1.50 FISH P DECOMP I RIH & LATCH FISH - TIH FROM 9525' TO TOP OF TBG STUB @ 19900' MD - ROT OVER END OF TBG STUB WITH SPEAR - GOOD INDICATION ON SHEAR PINS I � CONT. RIH TO NO-GO @ 9919' & SET DOWN W/ 13K DOWN - PU TO STRING WT @ 155K NO MOVEMENT, I j CONT TO PU TO 200K & FIRE JARS CONT UP TO 225K - SO TO 145K STAGE UP PUMP TO 5 BPM @ 1773 PSI. LOST 10K HOOK LOAD - PU AND FISH WAS FREE - - PUW 155K SOW 135K - PULL 2 STD AND RACK BACK 05:30 - 06:30 1.00 FISH P DECOMP CIRC & COND - DROP 1.875 BALL ROD & PUMP DOWN @ 2 ;BPM I - OPEN CIRC SUB W/ 2000 PSI 06:30 - 08:00 1.50 FISH P DECOMP CIRC & COND - CIRC WELL WITH CLEAN 8.5 PPG SW @ 475 GPM & 1930 PSI * 8.5 PPG SW IN, 8.5 PPG SW OUT I MONITOR WELL - WELL STATIC 08:00 - 16:00 8.00 FISH P DECOMP POOH & LD DP 9808' TO BHA @ 130' - MONITOR WELL - WELL STATIC 16:00 - 20:00 4.00 FISH P DECOMP LD BHA #2 - LD SPEAR BHA - JUNK CATCHER RECOVERED ON SPEAR - LD DP FROM DERRICK 20:00 - 21:00 1.00 RUNCOM ' P I RUNCMP MONITOR WELL - WELL STATIC -- 1 -- -- -- AT I C MAKE UP LANDING JOINT 1 - PULL WEAR BUSHING - MU LANDING JOINT - MAKE DUMMY RUN WITH 4.5" TBG HANGER Printed 3/4/2011 10:39:36AM p� �t SM E P Pa 7 o f 8 Operation' Summary, Repo Common Well Name: 05 -13 AFE No Event Type: WORKOVER (WO) Start Date: 1/25/2011 End Date: 2/6/2011 X4- 00RYF -E (2,136,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 6/29/1994 12:00:00AM Rig Release: 2/6/2011 Rig Contractor: NABORS ALASKA DRILLING INC. j UWI: 500292025000 Active Datum: 05 -13 @69.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) _ (ft) 21:00 - 22:30 1.50 RUNCOM P RUNCMP RU 4.5" HANDLING TOOLS & EQUIPMENT 22:30 - 00:00 1.50 RUNCOM P RUNCMP RUN 4.5" 12.6 LB/FT. CR13 -85 VAM TOP TBG TO 530' MD TORQUE TURN TO 4440 FT /LBS 2/5/2011 00:00 - 10:30 10.50 RUNCOM P RUNCMP CONT TO RUN 4.5" 12.6 LB/FT, CR13 -85 VAM 'TOP TBG - TO TURN MAKE UP AT 4440 PSI - PUW 130K SOW 112K - RAN 232 JNTS 1- END OF OVERSHOT = 9909' - GOOD INDICATION ON SHEER PINS - TAG NOGO @ 9915' MD 10:30 - 11:00 0.50 RUNCOM P RUNCMP CONFIRM HANGER LANDED RI LOCK DOWN SCREWS 11:00 - 11:30 0.50 RUNCOM P � ` RUNCMP RU TO REV. CIRC. 11:30 - 14:00 2.50 RUNCOM P RUNCMP 1 REV CIRC,COMPLETION FLUID - PUMP 150 BBLS 8.5 PPG CLEAN SEAWATER - PUMP 330. BBLS 8.5 PPG INHIBITED SEAWATER - 160 GPM @880 PSI 14:00 - 17:00 3.00 RUNCOM P RUNCMP SET HALLIBURTON TNT PACKER & TEST L. DROP 1 -7/8" BALL & ROD AND LAND ON RHC PLUG IN XN NIPPLE - PRESS TEST TBG 250 PSI LOW FOR 5 MIN. & 13500 PSI HIGH FOR 30 MIN. PASSED - 1ST 15 MIN LOST 51 PSI, 2ND 15 MIN LOST 24 PSI - BLEED PRESS OFF TO 1500 PSI & HOLD - 1.9 BBLS TO PRESS UP TO 3500 PSI, 1.5 BBLS BLED BACK @ 1500 PSI - PRESS TEST IA TO 250 PSI LOW FOR 5 MIN. & 3500 PSI HIGH FOR 30 MIN. PASSED 1- 1ST 15 MIN LOST 144 PSI, 2ND 15 MIN LOST 61 PSI, HOLD ADD 15 MIN TO PROVE STAB TREND PRESS LOST LAST 15 MIN 38 PSI. - BLEED OFF IA TO ZERO PSI, THEN BLEED TBG TO ZERO PSI - 6.1 BBLS TO PRESS TO 3500 PSI, 4.5 BBLS BLED BACK @ 0 PSI. 1- PRESS UP ON IA TO 2100 TO SHEER DCR VALVE IN GLM @ 3876' - PUMP 2 BBLS BOTH WAYS THRU DCR @ 2 BPM, @ 170 PSI 17:00 18 :00 1.00 RUNCOM —__ P RUNCMP 1 FMC REP DRY ROD IN TWC. - PRESS TEST TWC FROM ABOVE WITH 250 PSI LOW FOR 5 MIN, & 3500 PSI HIGH FOR 10 MIN. PASSED - PRESS TEST TWC FROM BELOW WITH 250 PSI LOW FOR 5 MIN, & 1000 PSI HIGH FOR 10 MIN. PASSED 18:00 - 18:30 0.50 RUNCOM P RUNCMP BLOW DOWN - CHOKE & KILL LINES - CHOKE & STANDPIPE MANIFOLDS - MUD & HOLE FILL LINES 18:30 - 20:30 2.00 RUNCOM P RUNCMP ND BOPS - RACK BACK STACK Printed 3/4/2011 10:39:36AM • orth A erica- ALASKA BP Page i 8 Operation Summ Report Common Well Name: 05-13 AFE No Event Type: WORKOVER (WO) Start Date: 1/25/2011 I End Date: 2/6/2011 X4- 00RYF -E (2,136,000.00 ) Project: Prudhoe Bay Site: PB DS 05 Rig Name /No.: NABORS 7ES Spud Date/Time: 6/29/1994 12:00:00AM Rig Release: 2/6/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292025000 Active Datum: 05 -13 @69.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 20:30 - 22:00 1.50 RUNCOM P RUNCMP NU TREE & ADAPTER FLANGE 22:00 - 23:30 1.50 RUNCOM ' ' P RUNCMP 1 FMC PRESS TEST ADAPTER VOID - PRESS TEST VOID 250 PSI LOW & 5000 PSI HIGH FOR 5 MIN EACH. PASSED 23:30 - 00:00 0.50 RUNCOM P RUNCMP PRESS TEST TREE PRESS TEST TREE 250 PSI LOW & 5000 PSI 'HIGH FOR 5 MIN EACH. PASSED 2/6/2011 00:00 - 01:30 1.50 WHSUR P RUNCMP CONT PRESS TEST TREE 1- PRESS TEST TREE 250 PSI LOW & 5000 PSI C _ I HIGH FOR 5 MIN EACH ON CHART. PASSED 01:30 - 03:30 2.00 WHSUR P RUNCMP INSTALL DSM LUBRICATOR & PRESS TEST. REMOVE TWC - PRESS TEST LUBRICATOR 250 PSI LOW & 3000 PSI HIGH FOR 5 MIN EACH ON CHART. PASSED I,- PULL TWC I- BLOW DOWN LINES - ROLUB. ; T- 03:30 - 08:30 5.00 WHSUR P RUNCMP FREEZE PROTECT - RU LRS & TEST LINES. I- REV CIRC 150 BBLS 80 DEGREE DIESEL @ 2 BPM "& 500 PSI - ALLOW TO U -TUBE FROM IA TO TBG - RD U -TUBE LINE - - - - -- — -- - - - -- - -- 08:30 - 12:00 3.50 WHSUR P RUNCMP INSTALL DSM LUBRICATOR & PRESS TEST. SET BPV & TEST - PRESS TEST LUBRICATOR 250 PSI LOW & 3500 PSI HIGH FOR 5 MIN EACH ON CHART. PASSED - INSTAI I BPV - LRS PRESS TEST FROM BELOW TO 1000 PSI FOR 10 MIN ON CHART. PASSED I I - BLOW DOWN LINES RD LUB - INSTAL VR PLUG IN IA RD SECURE WELL 1 RIG RELEASES 12:00 NOON 2/6/2011** il l Printed 3/4/2011 10:39:36AM • x ;_~- " ~: ~'~ ~r ,~ ~' ` 'b F ~~s_ f: ~~ ~: :~~ ~,b. „`, , ~ ~ a~ ~_ ~, _, ~. ~~ ~"'~ 3 s~~,,~: ~~ ~ ~;s . ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary tntemet Files\OLK9\Microfilm_Marker.doc 04/12/10 I A f ' ~~ Alaska Data b Consulting Services 2525 Gambsll Street, Suka 400 Anchoregs, AK 99503.2838 ATTN: Bath Well Job # Log Description Date N0.5501 Company: State of Alaska Alaska Oil 8 Oas Cona Comm Ann: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 05-138 F-47A V-123 BAUJ-00013 ANHY-00124 09AKA0152 MEM LDL ,.. SCMT .- ~ OH MW D EDIT 04Po5/10 04/06/10 01/11/10 1 2 1 1 1 1 of cece wrvunw, enr_e een ~,n~ e., c......., ....,.. .,~~ ........... ...... ...._.. _._.. __ BP Exploration (Alaska) Inc. Petrotechnicel Data Center LR2-i 900 E. Benson Blvd. Alaska Dala 8 Consuking Services 2525 Gambell Street, Suite 400 Anchorege, AK 99503-2838 `~ ~"h J _. ~( APR ~. ~ 2010 ~ ~ ~~ i NOT OPERABLE: Producer OS-13B ~D #2071460) TxIA Comm, Secured ~TTP Page 1 of 1 Regg, James B (DOA) ~v _ ~ ~. - From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~aZ~i 3,-6+10 Sent: Monday, March 15, 2010 12:19 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Schwartz, Guy L (DOA) Cc: Janowski, Carrie; NSU, ADW Well Integrity Engineer; GPB, EOC Specialists; Rico Hernandez, Claudia Subject: NOT OPERABLE: Producer 05-136 (PTD #2071460) TxIA Comm, Secured w/ TTP All, Producer 05-13B (PTD #2071460) has been secured with a tubin tact it Dlug and reclassified as Not Operable. The well will be further evaluated for repair options by running~a leak detection log. Please let us know if you have any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 9 ~+t~ ' (}"'~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, February 28, 2010 8:48 AM To: 'Regg, James B (DOA)'; Maunder, Thomas E (DOA); GPB, Area Mgr East (FSi/2/COTU/Seawater); GPB, FSi OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; 'Schwartz, Guy L (DOA)' Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: 05-136 (PTD #2071460) Sustained casing pressure on IA All, Producer 05-13B (PTD #2071460) has been found to have sustained casing pressure on the IA due to TxIA communication. The wellhead pressures were tubing/IA/OA equal to 1610/2020/770 on 02/27/10. The well has been reclassified as Under Evaluation. Once normal operations return following the inclement weather, an MITIA will be conducted. A TIO plot and wellbore schematic have been included for reference. « File: 05-136 02-28-10.doc » « File: 05-136.pdf » Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 3/16/2010 UNDER EVALUATIQN: OS-13B~TD #2071460) Sustained casing press~on IA Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, February 28, 2010 8:48 AM t~~3lj(~o To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; Schwartz, Guy L (DOA) Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: 05-13B (PTD #2071460) Sustained casing pressure on IA Attachments: 05-13B 02-28-10.doc; 05-136.pdf All, Producer 05-136 (PTD #2071460) has been found to have sustained casing pressure on the IA due to TxIA comm_ ation. The wellhead pressures were tubing/IA/OA equal to 16 0 on .The well has been reclassified as Under Evaluation. Once normal operations return following the inclement weather, an MITIA will be conducted. A TIO plot and wellbore schematic have been included for reference. «05-136 02-28-10.doc» «05-136.pdf» Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 3/1/2010 PBU OS-13B PTD# 2071460 2/28/2010 TIO Pressures Plot a,oo~ 3,000 2,000 1,000 -#- T bg -f- IA -~ OA OOA OOOA On • 12!05,'09 12?19105 a1 ro2110 0111 F110 01 /30!10 02113110 02!27110 TREE = CIW WELLHEAD= FMCI a .,,.-.~.w„-,,.,-,.,,,..,,,, ACTUATO ,,,.-,,.-,..,.-,.,, ~,.,. BAKER C R KB. ELEV = 62.5' BF. ELEV KOP = 10300' Max Angle = 96° @ 12828' Datum MD = NA Datum TV D = $800' SS JMD DRA~ 13-3/8" CSG, 72#, N-80, ID = 12.347" ~--~ 2718' Minimum ID = 2.370®° @ 11484' 3-3/16" X 2-718" XO TOP OF 7" LNR -SCAB 4182' 7" LNR -SCAB, 26#, L-80, .0383 bpf, ID = 6.276" (-j 9878' TOP OF 7" LNR 9$78' t11111ed 9-5i8" MILLOUT WINDOW - 10030' -10080' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3874 3809 32 MMG DMY RK 0 02106!09 2 7384 6210 49 KBG2LS DMY INT 0 04!14105 3 9780 7897 48 KBG2LS DMY INT 0 4182' ~ 9-5/8" X 7" ZXP LNR TOP PKR W/ HMC LNR HGR 9872' 9-518" X 7" ZXP 7" FKR 992 7" X 4-1/2" BKR SAB-L-3 HYD PKR 9976, ~- j 3.70" DEPLOYMENT SLV , ID = 3.00" 9896' 3-1/2" HES X NIP, ID = 2.813" 10250' I-j 3-112" X 3-3/16" XO, ID = 2.786" 13-112" LNR, 9.2#, L-80 STL, .0087 bpf, ID = 2.992" I-I 10250' 4-1/2" TBG, 12.6#, L-80 BTGM, .0152 bpf, ID = 3.958" 7" WHIPSTOCK {01/25108 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" RA TAG (01125/08 I 10300' I 10( 3a7' i 10347' 10357' PERFORATION SUMMARY REF LOG: ??? ANGLE AT TOP PERF: 87° @ 11210' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2 6 11210 - 11400 O 02/03/08 2 6 11440 - 11610 O 02!03108 2 6 11800 - 11930 O 02103/08 2 6 11990 - 12170 O 02/03/08 2 6 12330 - 12620 O 02/03/08 2 6 12820 - 12870 O 02/03/08 2 6 12940 - 13048 O 2/3/2048 - ~ ~ ~ SAFETY *** WELL ANGLE ~ 70° @ 10994'*** ***ORIGI & 05-13A WELLBORES NOT SHOWN BELOW WHIPSTOCK*** 1999' 4-1/2 CAMCO SVLN, 9-CR SSSV NIP, ID = 3.812" PBTD {02/01,08) ~- 1~ 3059' ~''" 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 13095' DATE REV BY COMMENTS DATE REV BY COMMENTS 1977 ORIGINAL COMPLETION 08122!94 SIDETRACKED 06/20!98 LAST WORKOVER 02/03108 NORDIC 1 CTD SIDETRACK {05-13B} 03/09/08 ?/PJC DOWNSOZ CORRECTION 02/08/10 ?!JMD DRLGDRAFTCORRECTIONS PRUDHOE BAY UNfI" WELL: 05-136 PERMff No: ~Z0714600 RPI No: 50-029-20250-02-00 SEC 32, T11N, R15E, 2265' FNL & 112' FWL BP Exploration {Alaska} 4-1/2" HES X NIP, ID = 3.813" 4-112" WLEG. ID = 3.958" MILLOUT WINDOW {05-13B) 10352' - 10359' 3-3116" X 2-718" XO, ID = 2.370" 3-3/16" LNR, 6.2#, L-80 TCII, .0076. bpf, ID = 2.80" OPERAB:E: OS-13B (PTD #2QZ1460) OA repressurization manageably bleeds, tubing... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ,~ ;.,+rLl7~,~, Sent: Saturday, February 07, 2009 8:37 AM y J ""' To: Regg, James B (DOA); Maunder, Thomas E (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; GPB, EOC Specialists; Dean, James A Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: OPERAB:E: 05-13B (PTD #2071460) OA repressurization manageable by bleeds, tubing integrity restored Aii, An OA repressurization test was completed on well 05-13B {PTD #2071460) on 01125/09. The test demonstrated that the OA pressure is manageable beiow MOASP with infrea bleeds. However, during the diagnostic work, the well was'found to have TxIA communication that did not result in an IA pressure above MOASP; indicated by a failed TIFL on 01/29009. DC;LVs were set on 42/06/09 and the well passed an MITIA. Tubing integrity has been restored and the well has been reclassified as Operable. The well may be put on production when convenient. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, January 14, 2009 8:58 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS1 OTL; GPB, FSl DS Ops Lead; GPB, Wells Opt Eng; GPB, EOC Specialists; Dean, James A Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Quy, Tiffany Subject: UNDER EVALUATION: 05-13B (PTD #2071460) OA repressurization above 1000 psi All, Well 05-13B (PTD #2071460) was been reclassified as Under Evaluation for having OA repressurization causing the OA pressure to increase above the 1000 psi pressure limit. The well may remain on production while the wellhead seals are serviced and tested. Plan forward: 1. Wellhead: Inner casing packoff test 2. DHD: OA repressure test A wellbore schematic and TIO plot have been included for reference: Please let me know if you have any questions. 2/ 12/2009 OPERAB:E: OS-13B (PTD #2QZ1460) OA repressurization manageably bleeds, tubing... Page 2 of 2 Thank you, Anna 1~u6e, ~' 2. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 2/12/2009 PBU OS-13B PTD 207-146 1 / 14/2009 a,ooo 3:000 2,000 1,000 TIO Pressures -~- T bg --~-- IA ~ OA - OOA -!>- OOOA -~ On • • 10/18/08 10%25108 11101/08 11102/00 11115/08 11122/00 11123108 12/06/08 12/13; n8 12/20/08 12/2/108 01103/09 01110;09 THE = CPJ~J iiV1=l k NEr~ C3 = Ft~hC ACl~J4Tt~R _.. RgKFRG __ __ _ ._ KB ELI~V = F`15' ....__ . _m .._ BF Er f=V = ~~8 IJaturr~NtE~= -- NA CkatiarnTJi'I - ~~f?~, SS i 3->»° cs~. ~?~r. r`~ ec~, Id = #2.347°~ 271$' ~`1IJEtlIITtUt7t ~~ _ ~.~~~~~ ~ 1613' Tt3P ~~ 2-7f8" LINER 7<}pOF i" LN(?-SCAB -~ +~1$2' 7" LNR -S~ u ~6'll L. Sq, .L'383 ttpf, ~ - u,278'" ~ 9$78' It~~'oF 7" LNR ...9878' rnilled~ ~ `-[~ i ~u 9-.ii5" CSi3, 47#, f+l-€i~, 1d - 80381 " ~ 1 ~ 783" -ti,,._.rr ~- ~ ~.. N~iLLOL1T ~r~r~,ii~ovv- i0b3a' -1 ota~~' 4-1t2" TBG, 12.~r#, L-$t1, .g15~ bpf, Id = 3.9~' 1€T3t}0' ~7" X ~ i %~~,~ BKf~ZXP Lr~l~A f'KR, Id=2.2"" 2-7d8" LfJ+~, n.~~, L-80, .t}458 bpt, IC? = 2.441" 4-'!!?_" Tii~, i.~ tab, L-84, :fli 52 hfif, I[~ = 3,958`:`. r~pcrJPnTyC`~1 S! a~x,~rsy Rlote' °2e(er to FY~.3r1~~ctk r, CE's for t'~i<tor'~ca) perf data S~~ a_ OFF ni~-u~ r n i t C~pntac~z ~ ~r>= f1;. , 2'' t., ~~ ~., *y,a ~'" t3 ay LNR: , L-sa, .0371 ~pf, I[:} = s.1 ~4^ 1 i~9$5' S~ 11~0TE5: 7{f° ~ 10954' AND80° ~?? =r? t2 GA h'K,O SV Lfl, 9-GR S:StI NIP, ICS= 3.$i~' SAS LIFT MANdRELS 5T nary -rva ct~r T~rl~ vLV LATH P€~ DRTE 1 3'74 38fl9 32 Fr' dUN1E R 16 R^i29;08 2 7384 r,<~ica 49 KBGZIS dt~Y tNT 0 aar~.a?as 3 97fiQ 7897 48 KRGZL.S L~aTY tNT 0 49 82' 9-5/8" X 7" LXP LNR TQP PlfR W! FiN~ LNR HGR ~s~~-~~.~rg~ s~ ~~ .~x~ ~N P~<ft ~ '9925' - T' v 41 t2" EkR 5tk f1- L-3 HY C PKEt _, ,, 10249` -v2' X 3-3/16" x-over 1~i3f10' ,~. ~ ~~~ Tuerf~~ Tit IL uv~FC~ ~, ~ . ~_.~__ .. 10587` X1,1 c, a c?EF~LC~=`anrntF sL,E~.r~~ i 0453' 10fi78' ?" BRKER 5~1Ett--3 F~<iZ 1073 ' - -- 4.1 2 ~TrS ~ rlt~, i~ - 3 ~~ X0860' 4-i > 3Etk3ir~1~ Tillt~ brVLE~ EI._~v3i~ ~ i fdC1T LC ~ GEt:t 1©58T ~c~ssa I I II I I 2-7l8" LNR 5!_C1T7EC3 6.5~, °-- 1172~U' L-80, .005Ei Fsfxf IG = ?,441" - i n.~~ _ F:cv s~ _ ct~r~s~~t_ri; s t1ATE RE1J ~Y _ cor;r~J^~nrr~ 1 is~7 - C?Rt6[A~L car~~~L~r-©fa t~~3i22t94 _._.. SI[3E~#~,~1C@CFS3 - - - 06I2fll9S Elti,ST t~1t36,'k'.QV C~2 0"210310$ Pt~1F.'OICi CTD ~fDEFRACl~ 03 cig;tr; ?; PJC C~r~~r;~~ ° cv~,I:FCT~c~ra F" 'I IJ~_ BAY UN[T :'~ '~ IL 0;x-9 3.fi, PERK"~"'!c~ 1J•1(~4:~'0 APi No. 5~-fJ29--J025~~~ di SEC 32, T11tJ, Rt 1:", 00`>' FEL ~ 't~,~}ra 16' fNL BPExpseaton {,~11:iska) DATA SUBMITTAL COMPLIANCE REPORT 12/15/2008 Permit to Drill 2071460 Well Name/No. PRUDHOE BAY UNIT 05-13B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20250-02-00 MD 10353 TVD 8247 REQUIRED INFORMATION Completion Date 1/3/2008 Completion Status 1-OIL Current Status 1-OIL UIC N Mud Log No Samples No Directional Surve~/ ~ i DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / RES, MCNL / GR /CCL Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D~ D Asc Directional Survey vf``tpt /tD C Las Directional Survey 16213 Induction/Resisti it v y ~~ES-6 L-ee P1e~rt--- ~ Neutron f ~ ED C / 1630 v N / Lis 5 eutron ~t LIS Verification C Lis 17110f/Induction/Resistivity ,Log Induction/Resistivity ';X og Induction/Resistivity 1 / ryLOg Gamma Ray See Notes Well Cores/Sampl es Information: (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Scale Media No Start Stop CH Received Comments 10346 13107 Open 3/10/2008 10346 13107 Open 3/10/2008 10277 13106 Open 4/11/2008 ATR, RPM, GR, RAM, ROP,RPD 2 Blu 9700 12972 Open 5/23/2008 MCNL, CNL, GR, CCL 9487 12971 Open 5/23/2008 LIS Veri, GR, CNT 9240 13107 Open 11!7/2008 LIS Veri, GR, ROP, RPS, RAD, RAS, RPD 9240 13107 Open 11/7/2008 LIS Veri, GR, ROP, RPS, RAD, RAS, RPD 25 Col 10347 13107 Open 11/7/2008 MD MPR, GR 30-Jan-2008 25 Col 10347 13107 Open 11/7/2008 TVD MPR, GR 30-Jan-2008 25 Col 10347 13107 Open 11/7/2008 MD GR 30-Jan-2008 2 Col 9470 13107 Open 11/7/2008 Depth Shift Monitor Plot Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 12/15/2008 Permit to Drill 2071460 Well Name/No. PRUDHOE BAY UNIT 05-13B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20250-02-00 MD 10353 TVD 8247 ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~#~ Analysis Y~yM- Received? Comments: Completion Date 1/3/2008 Completion Status 1-OIL Daily History Received? Formation Tops Current Status 1-OIL ~! N al /N UIC N Compliance Reviewed By: Date: ~ ~- ~ C1 ® ~ ~J INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken ~ ~l~v$- Reference: 05-13B ~ Contains the following: ~~ G ~~PiJ~ ~~ ~+~ 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 1783798 Corrected digital files. This Data CD replaces all previously delivered digital data. ao~-~y~ ~ ~~a~~- Sent by: Catrina Guidry Date: 12/11/08 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING &. RETURNING OR FAXING YOUR COPY FAX: (90'1j 267-623 d~~`~~ l~.~6NES ._._e_.___.~._ ~- t C~'I"EQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~~ ~~ ~~: COMPANY WELL NAME FIELD BAKER NYl~NES Baker Atlas PRINT DISTRIBUTION LIST BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BOROUGH OS-13B STATE ALASKA PRUDHOE BAY UNTI' DATE 12/11/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: ]783798 Copia of Copies Digital Copies of Copia Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073 This Distribution List Completed Bv: _ 52rrt~ ~~ ~~s ~ wire ~ i ct~ ,~J ~ Page 1 of 1 DATE 10/31/2008 BAKERY i~Y6NE5 Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BP EXYLUKA'CLUN (ALASKA) INC CUUN 1'Y NUK'1'H SLUYIr BUKUUUH WELL NAME OS-13B STATE ALASKA FIELD PRUDHOE BAY UNIT THIS DISTRIBUTION LIST AUTHORIZED BY • CATRINA GUIDRY SO #: 1783798 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE. AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: Cl~'V ~ ~a~~~~ Page 1 of 1 a ~ INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7t'' Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 05-13B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files} 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPIZ/Directional TVD Log (to follow) 1 color print - MPR1Directional Measured Depth Log (to follow) LAC Job#: 1783'798 Sent by: Catrina G i y Date: 10/31/08 Received by Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ '°-- '.j 7260 Homer Drive 4.w '_. _ ~G1~5 Anchorage, Alaska 99518 Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 05/20/08 ~~~~~mU~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2538 ATTN: Beth Woll ~.,h u N0.4712 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPB-04A 12021150 MEM PROD PROFILE ~y 04/17/08 1~ 1 MPG-13 12021151 MEM INJECTION PROFILE =G 04/18/08 1 1 Z-26A 11978454 MEM GLS ~Uip - 04/23!08 1 1 Z-29 11978453 MEM GLS - 04!22/08 1 1 Y-36 12005204 MEM GLS ~/ 02/12/08 1 1 4-14A/S-37 12031471 _ PRODUCTION PROFILE W/FSI 04/12/08 1 1 Y-07A 11966254 SCMT / 05/02/08 1 1 02-01 B 11966257 LDL ~ (p _ 05/10/08 1 1 X-16A 11975771 USIT L .- L 05/14/08 1 1 07-26 12061688 USIT - 05/16/08 1 1 05-34 11966251 USIT - 04/13/08 1 1 05-23A 118966257 USIT ~ 05/13/08 1 1 S-33 11962596 USIT - 04/15/08 1 1 V-223 12061688 CH EDIT PDC GR (USIT $ - / 03/23/08 1 V-220 40016600 OH MWD/LWD EDIT ab _ 03/03/08 2 1 4-14AlS-37 40016545 OH MWD/LWD EDIT p~.-U ( / 02/18/08 2 1 05-22B 11628800 MCNL 10/22/07 1 1 05-136 12021140 MCNL ~ r.- 01/31/08 1 1 Z-10 12066520 RST ~ 04/10/08 1 1 D-10 11975766 RST 04/25/08 1 1 n~ ~ncv nn~-~nuu ---.~-..~.-.-_--~~~_.~..._..~r• • v• v•.n•~••~~w r••~v ••~•v•••~••~V V~~G VVf~ CMVfI IV. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 , , 900 E. Benson Blvd. ~ '~ , ~'~ Anchorage, Alaska 99508 Date Delivered: ~,r1 A"°~~ ~~ ~, ;~Ilfli4 -r:: _ ._. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~\ Date 04-30-2008 Transmittal Number:92964 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 Deliverv Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 05-13B ~~ - 6~l~ E1(oc7~ Y-01A ~' U~--(U~ ~~o a ((f y'°~"/~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1.2 Date 04- I 1-2008 Transmittal Number:92955 BRA W ~.LL DATA TRANSMITTAL Enclosed are the t~i~tei~ials list~c(below. (BPXA FIELD LOG DATA) i you nave any uestlons, lease contact llouglas llortcri at trie Ylll; at Jb4-4y is Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 05-13B ~Q'~--lLl~ ~ ~(00l(3 C-35B c~OCfl -~ c79 ~! /0 8 ( ~ Y-O1APB1 ~~-~5~~/~~~~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2- i 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 ~~~~ STATE OF ALASKA - -d8 ~~~~~~ ALASK~IL AND GAS CONSERVATION COMMISSION ~,• .-~ F~ ~ _~ ~ 20D& WELL COMPLETION OR RECOMPLETION REPORT AND LOG AI21ska a~ ~ Gas Cons. Gommiss 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1b. Well Clas C r0 zoAACZS.~os zoAaczs.r~o ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband 12. Permit to Drill Number BP Exploration (Alaska) Inc. 2/3/2008 207-146 - 3. Address: 6. Date Spudded .3~ 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1/25/2008 ~ 50-029-20250-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 3015' FSL 112' FWL SEC 32 T11 N R15E M 1/30/2008 ~ PBU 05-13B , , . , , , U Top of Productive Horizon: 8. KB (ft above MSL): 62.46 ' 15. Field /Pool(s): , 1604' FSL, 3823' FWL, SEC. 29, T11N, R15E, UM Ground (ft MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 1228' FSL, 299' FWL, SEC. 28, T11 N, R15E, UM 13059 8814 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 697176 y- 5949180 Zone- ASP4 13107 8813 ADL 028325 ~ - TPI: x- 700771 y_ 5953145 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 702538 y- 5952817 Zone- ASP4 None 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): Submit electronic and rinted information er 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information p 20 AAC 25.071) : `' MWD DIR / GR / RES, MCNL / GR / CCL L//A/60~jf /O S3jN,~ ~~~~ STYD 22• CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surfa a 112' Surface 112' 32" 224 sx Arcticset 13-3/8" 72# N-80 Surface 2718' Surface 2718' 17-1/2" 5726 sx Permafrost II 9-5/8" 47# N-80 Surface 10030' Surface 8064' 12-1/4" 675 sx Class'G' 275 sx PF 7" 29# L-80 4182' 1 4058' 8310' 8-1/2" 244 sx Class 'G' a-, /z" x 3-3/16" x 2-7l6" 9.2# ! 6.2# / 6.16# L_80 9977' 13095' 8029' 8813' 4-1 /8" 227 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TuswG RECORD If Yes, list each interval open (MD+TVD of Top 8~ Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10300' 9925' MD TVD MD TVD + 11210' - 11400' 8821' - 8824' ACID 25 FRACTURE CEMENT SQUEEZE ETC 11440' - 11610' 8825' - 8827' . , , , . 11800' - 11930' 8829' - 8829' ' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 11990 - 12170' 8826' - 8822' 2500' Freeze Protected with McOH 12330' - 12620' 8824' - 8821' 12820' - 12870' 8821' - 8817' 12940' - 13048' 8815' - 8814' 26• PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date Of Test: HOUrS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing CaSing PreSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^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. fir:.. _. , af~ None ~ ~fa= .~ i p e... ~ ..~,~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~ ~/~~~~~~C,~«~ /' Jd'SI'y \ LLL (~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS ` NAME ND Well Tested . ^ Yes ®No Permafrost Top If yes, list intervals and formations 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. Shublik A 10365' 8320' None Shublik B 10384' 8335' Shublik C 10405' 8352' Sadlerochit Zone 4B 10438' 8378' Top CGL /Zone 3 / 31 N 10616' 8522' Base CGL /Zone 2C 10691' 8586' 23SB /Zone 26 10768' 8651' 22TS 10821' 8690' 21TS /Zone 2A 10874' 8724' Zone 1 B 10958' 8766' TDF /Zone 1A 11092' 8804' Formation at Total Depth (Name): TDF /Zone 1A 11092' 8804' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Drilling Technologist Date PBU 05-13B 207-146 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Driving Engineer: Abby Warren, 564-5480 INSTRUCTIONS GeNew-~: 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. IreM 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. IreM 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. 1reM 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 25.07E Form 10-407 Revised 02/2007 Submit Original Only i • BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code ~, NPT Phase Description of Operations 1/20/2008 00:00 - 01:00 1.00 MOB P PRE Prepare to jack up rig and move off well A-12. 01:00 - 01:15 0.25 MOB P PRE Safety Meeting prior to pulling off well. 01:15 - 04:00 2.75 MOB P PRE Pull off well and move to side of pad, Weld on guide rollers onto SWS injecterhead support frame to guide injecter into pipe bay. 04:00 - 14:00 10.00 MOB N WAIT PRE Wait on security, security was busy moving another rig on the spine road to K pad. Wind at 20-40 mph, so unable to lay down derrick. 14:30 - 00:00 9.50 MOB P PRE Move to Pad 10. 19:00 -Leak while moving the rig, estimated 1 cup gear oil leaked onto Spine Road near Pump Station 1, from a front drive wheel seal. Spill was reported to x5700 and cleaned up. See Traction incident # 2525892. 1/21/2008 00:00 - 04:00 4.00 MOB P PRE Continue moving from A-12 to Pad 10. 04:00 - 07:00 3.00 MOB P PRE Arrive Pad 10, set rig down and prepare to lay down derrick. 07:00 - 07:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil stub to reel. 07:15 - 10:15 3.00 MOB P PRE Pull coil stub to reel and secure coil. 10:15 - 10:30 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for moving guide arch and placing injector in pipe bay. 10:30 - 14:00 3.50 MOB P PRE Place guide arch in pipe shed. Lower injector into pipe bay and remove pipe straightener. Place pipe straightener on rig floor in front of doghouse. 14:00 - 14:30 0.50 MOB P PRE Crew change. SAFETY MEETING. Review procedure, hazards and mitigaion for laying down wind walls. Wind at 7-12 mph. 14:30 - 18:00 3.50 MOB P PRE Remove chain fall beams in pipe shed. Lower wind walls. 18:00 - 18:45 0.75 MOB P PRE Hook up tugger lines to derrick hydraulic cyliunders, scope out cylinders and pin the bottom ends. 18:45 - 19:00 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigaion for laying down derrick. 19:00 - 19:30 0.50 MOB P PRE Scope derrick down. Open pipe shed doors and prepare to lay down derrick. 19:30 - 20:00 0.50 MOB P PRE Crew change and safety meeting with new crew. 20:00 - 20:30 0.50 MOB P PRE Lay down derrick. 20:30 - 20:45 0.25 MOB P PRE Close pipe shed doors. Conduct Safety Meeting to discuss hazards and mitigation for moving rig under power lines. 20:45 - 22:45 2.00 MOB P PRE Jack up rig and move to DS 05. 22:45 - 23:00 0.25 MOB P PRE Park rig on DS 5 so windwalls on both sides can be accessed. Safety meeting to discuss raising derrick. 23:00 - 00:00 1.00 MOB P PRE Open pipe shed roof and raise derrick. 1/22/2008 00:00 - 01:30 1.50 MOB P PRE Close windwalls. 01:30 - 03:00 1.50 MOB P PRE Rig up pipe straightener onto injector. 03:00 - 03:30 0.50 MOB P PRE R/U blocks to injector. P/U injector to rig floor. 03:30 - 06:00 2.50 MOB P PRE P/U gooseneck from pipeshed and R/U to injector. Install chainfall beams in pipe shed. 06:00 - 07:45 1.75 MOB P PRE Prep to back over well. 07:45 - 08:00 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. Printed: 2/13/2008 2:43:22 PM , BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: 05-13 Common W ell Name: 05-13 Spud Date: 6/29/1994 Event Nam e: REENTE R+COM PLET E Start : 1/17/2008 End: Contractor Name: NORDIC CALIS TA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 I Date From - To i Hours Task Code NPT Phase Description of Operations 1/22/2008 08:00 - 08:30 0.50 MOB P PRE Back rig over well, center rig and set down. ACCEPT RIG AT 0830 HRS, 01/22/2008. 08:30 - 13:30 5.00 BOPSU P PRE N/U BOPE. Rig up cuttings tank and spot trailers. 13:30 - 19:30 6.00 BOPSU P PRE Te t BO .Test witness waived by AOGCC inspector Chuck Scheeve. Rebuild check valve on kill line. Install RA tag on whipstock. 19:30 - 20:45 1.25 RIGU P PRE Safety Meeting for stabbing pipe. P/U injector. R/U internal grapple to coil. Pull test. Pull coil across to injector. 20:45 - 21:00 0.25 RIGU P PRE CT cable is hung up while pulling across. Put CT into horsehead so it can be clamped. Finish pulling CT across. 21:00 - 21:15 0.25 RIGU P PRE Install cable boot. MU injector to riser. 21:15 - 22:00 0.75 RIGU P PRE Safety Meeting to discuss filling reel backwards. Start filling reel backwards. Reverse circulate 97 bbls at 3 bpm rig water for a-line slack management. 22:00 - 22:50 0.83 RIGU P PRE Rig up hydraulic tubing cutter and start cutting back CT to find cable. Cut back 50 ft and cable is found. Dress end of CT for connector. Install CT connector. 22:50 - 00:00 1.17 RIGU P PRE Pull test CT connector to 35 Klbs, good. Install cable head. 1/23/2008 00:00 - 01:00 1.00 RIGU P PRE Install X-over and nozzle on BHA. MU injector to wellhead to pump forward. Pump 1 reel volume forward at 2.8 bpm. 01:00 - 01:30 0.50 RIGU N WAIT PRE Wait on BPV crew to finish another job on F Pad. 01:30 - 02:50 1.33 RIGU P PRE P/U BPV crew lubricator and tools thru beaver slide to rig floor. Safety Meeting to discuss hazards and mitigations for pulling BPV. MU BPV lubricator and pressure test to 1,000 psi. Pull BPV 700 i 02:50 - 03:20 0.50 RIGU P PRE Lay down BPV lubricator and pulling equipment. MU injector to riser. Line up to kill well through CT. 03:20 - 03:50 0.50 KILL P WEXIT Bullhead KCI water to kill well at initial rate of 3 bpm with initial WHP = 740 psi. After 47 bbls away well not taking fluid, WHP = 1,500 psi at 1.7 bpm. (Flo-Pro in well from 1/17 well kill) Shut down and prepare to RIH to circulate gas out. 03:50 - 04:50 1.00 KILL P WEXIT RIH circulate at 0.4 bpm, hold 400 - 500 psi initially while bleeding off gas. 04:50 - 06:00 1.17 KILL P WEXIT Increase rate to 2.6 bpm. At 6,800 ft get some freeze protect fluid back. RIH, 2.5 bpm w/ no returns. Well appears to be on vac. At 9000', start pumping biozan downhole. 06:00 - 06:25 0.42 KILL P WEXIT Getting partial returns w/ 210 psi WHP. Choke partially open, taking returns to tiger tank. RIH to 10,400'. Shut down pumps and close choke. WHP = 160 psi. Fall off to 37 psi. Handover to day shift. Printed: 2/13/2008 2:43:22 PM BP EXPLORATION Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 1 /17/2008 Rig Release: 2/3/2008 Rig Number: N1 Date From - To Hours Task Code NPT Phase 1/23/2008 06:25 - 07:30 ~ 1.08 KILL P~ WEXIT 07:30 - 07:40 I 0.171 KILL I P I I WEXIT 07:40 - 18:00 I 10.331 KILL I N I WAIT I WEXIT 18:00 - 21:45 I 3.751 KILL I N I WAIT I WEXIT 21:45 - 00:00 I 2.25 I KILL I N I WAIT I W EXIT 1/24/2008 ! 00:00 - 01:00 I 1.001 KILL I N I WAIT I W EXIT 01:00 - 01:30 I 0.501 KILL I N I WAIT I W EXIT 01:30 - 02:00 0.50 KILL P WEXIT 02:00 - 03:30 1.50 KILL P WEXIT 03:30 - 03:40 0.17 KILL P WEXIT 03:40 - 04:15 0.58 WHIP P WEXIT 04:15 - 06:55 I 2.67 WHIP P WEXIT 06:55 - 07:20 0.42 WHIP P WEXIT 07:20 - 08:10 0.83 WHIP P WEXIT 08:10 - 10:30 2.33 WHIP P WEXIT 10:30 - 11:30 1.00 ZONISO P WEXIT 11:30 - 13:40 2.17 ZONISO P WEXIT 13:40 - 15:00 1.33 ZONISO P WEXIT 15:00 - 15:30 0.50 ZONISO P WEXIT 15:30 - 15:45 0.25 ZONISO P WEXIT 15:45 - 18:35 2.83 ZONISO P WEXIT Page 3 of 10 ~ Spud Date: 6/29/1994 End: Description of Operations Circulate thru choke 1.9 bpm at 1050 psi. Bottoms up. Phase 3 called @ 0715.. Continue to circulate at bottoms up taking clean returns to pits. Safety meeting to dicsuss future operations .Well ops complete kill and circulate at min rate. WOW. Rig operations contiinue monitoring air intakes Circulate bottoms up. Circulate at min rate while WOW. Phase 3 weather. Phase 3 weather. Continue to circulate at min rate while WOW. Phase 2, Level 3 weather. Access roads and pads are closed. Continue to circ at min rate, 0.39/0.36 bpm. WOW. Phase 3, Level 3 weather conditions on roads and pads. Circulate at min rate. WOW. Notification given that emergency equipment was cleared out. Used loader to make sure pad area around rig was clear. Loader also made sure access road to West Dock road was clear to pad. Pad operator gave permission to resume operations. Rig crew made rounds to ensure that everything was okay to resume ops. Close choke, perform injectivity test. Wellbore and pits are full of 2% KCL w/ 2 ppb biozan. 0.5 bpm C~3 1100 psi, 675 psi WHP 1 bpm ~ 1615 psi, 950 psi WHP 1.5 bpm C~ 2030 psi, 1150 psi WHP 2 bpm ~ 2640 psi, 1440 psi WHP POOH to surface w/nozzle. S/B injector. L/D nozzle. M/U Whipstock setting BHA #1. Overall BHA length = 81.20'. Stab injector. Test BHI tools, open EDC. RIH w/ WS setting BHA. to 10300' Log tie - in. Correction +22'. Log collars. RIH to setting depth.Place top of WS at 10348'. Close ECD and pressure to 3200 psi to shear. Set down 2K. POH LD WS running tool. PU BHA #2 cementing nozzel. RIH circulating at min rate. Swapping to KCL. Tag correct +23. Swap well to KCL. RU cementers. Conduct injectivity test , .5 bpm 1210 psi 1080 Shut in psi, Total 40 bbl injected. Liner vol 26 bbl 1.0 bpm 1780 psi 1460 shut in psi, 1.5 bpm 2238 psi 1780 shut in psi 2.0 bpm 2650 psi 1940 shut in psi PJSM for cementing operation. Flood lines with 5 bbl H2O and PT to 4000 psi. Batch mix 41 bbl 15.8 oob cement. 5 bbl H2O. 30 bbl Bio and KCL. 2 bpm at 670 psi. After 55 bbl away start bullheading C~5bbl 2 bpm at 1770 wh, 2527 psi, 317 IA, 543 OA ~ 10 bbl 2 bpm at 2140 wh, 2900 psi, 317 IA, 543 OA After 10 bbl reduce rate to 1.5 bpm ~ 15 bbl 1.5 bpm ~ 2200 wh climed to 2700 and broke back Printed: 2/13/2008 2:43:22 PM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 i Date ~ From - To Hours Task Code', NPT ; Phase Description of Operations 1/24/2008 15:45 - 18:35 2.83 ZONISO P WEXIT to 2200 psi wh After 19.5 bbl reduce rate to .5 bpm. ~ 20 bbl .5 bpm, 3660 wh, 3200 psi, 340 IA, 550 OA. Stopped bullheading at 20 bbl. Lay in 21 bbl to while holding 2200 psi WH pressure. 1700 Pull to 7000' safety. Shut down pump and shutin holding 1900 psi WH. Attem t to s ueeze Pressure to 3040 psi with 1.4 bbls. Bleed off 2700 psi in 8.5 min. IA 251 psi, OA 485 psi. represure to 3020psi with .4 additional bbls. IA 250 psi,OA 483 psi. Bleed off to 2700 in 10 min repressure to 3000 psi with .6 additional bbls. IA 229, OA 455 psi. 18:35 - 19:45 1.17 ZONISO P WEXIT Wash down to to of whi stock while holdin 2000 si WHP Zero out MM at 9000'. Pressures and weights indicated cement stringers starting at 9400'. Open choke and take returns out bypass line. Tag pinch point at 10351'. Contaminated cement reached surface at 105 bbls on out MM. 19:45 - 21:45 2.00 ZONISO P WEXIT POOH to surface w/ cement nozzle BHA. 21:45 - 22:00 0.25 ZONISO P WEXIT PJSM. P/U injector. UD cement nozzle BHA #2. M/U swizzle stick. Stab injector. 22:00 - 22:15 0.25 BOPSU P WEXIT Jet stack w/ swizzle stick. 22:15 - 23:15 1.00 STWHIP P WEXIT PJSM. P/U injector. UD swizzle stick. S/B injector. M/U window milling BHA #3. Mill, 2 jts 2-3/8" PH6, DPS. Overall BHA length 112.54' Stab injector. 23:15 - 00:00 0.75 STWHIP P WEXIT RIH w/ window milling BHA. 1/25/2008 00:00 - 01:20 1.33 STWHIP P WEXIT Continue to RIH w/ window milling BHA #3. 01:20 - 01:30 0.17 STWHIP P WEXIT Stop at 10,300'. Up wt 47K, do wt 21 K. Shut down pumps and dry tag at 10321'. P/U to 10310'. Increase pump to 2.6 bpm, 1700 psi. RIH, tag pinch point at 10319.3'. Correct depth to _ pinch oint, 10352.6'. +33' correction. .___, .__ . _ l Mill 3.80" window thru 7", 29#, L-80 Liner. Start Milling at 10352.6' at 1 fph. Full returns. 01:30 - 02:30 1.00 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 1950 psi, 2K WOB, 1 fph. Milled to 10354.1'. 02:30 - 04:00 1.50 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2200-2700 psi, 2.5-3.5K WOB, 1 fph. Milled to 10355.3'. 04:00 - 06:00 2.00 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2500-2700 psi, 3-3.5K WOB, 1 fph. Milled to 10357.4'. 06:00 - 07:30 1.50 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.5 bpm, 2400-2600 psi, 3-3.7K WOB, 1 fph. Milled to 10357.8'. PT= 305 BBLS. 07:30 - 10:17 2.78 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2300-2600 psi, 3-3.7K WOB, 1 fph. Stall at 10358.7. Milled to10360. PT= 305 BBLS. 10:17 - 10:40 0.38 STWHIP P WEXIT Drill formation to 10363'. j Printed: 2/13/2008 2:43:22 PM • BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ~~ Task Code NPT ~ Phase ~! Description of Operations 11/25/2008 110:40 - 11:10 0.501 STWHIP P 11:10 - 12:20 I 1.171 STWHIPI P 12:20 - 13:15 0.92 STWHIP P 13:15 - 13:40 0.42 STWHIP P 13:40 - 15:30 1.83 STWHIP P 15:30 - 16:00 0.50 STWHIP P 16:00 - 17:15 I 1.251 DRILL I P 17:15 - 19:00 1.75 DRILL P 19:00 - 19:30 0.50 DRILL P 19:30 - 22:00 2.50 DRILL P 22:00 - 00:00 2.00 DRILL I P 1/26/2008 100:00 - 00:50 I 0.831 DRILL I P 00:50 - 01:00 0.17 DRILL P 01:00 - 01:45 0.75 DRILL P 01:45 - 03:30 1.75 DRILL P 03:30 - 06:20 I 2.831 DRILL I P 06:20 - 06:40 0.33 DRILL P 06:40 - 09:40 3.00 DRILL P 09:40 - 11:00 11:00 - 11:45 11:45 - 14:15 14:15 - 14:25 14:25 - 14:45 14:45 - 15:00 15:00 - 15:35 1.331 DRILL I P 0.75 DRILL P 2.50 DRILL P 0.17 DRILL P 0.33 DRILL P 0.25 DRILL P 0.58 DRILL P 15:35 - 17:30 WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 1.921 DRILL I N I DFAL I PROD1 Pick up off bottom shut down power pack for SLB inspection of traction motor brushes. LOTO with Nordic electrian Heyden Elec rep per Nordic procedure. Shut down for convience of SLB to accomodate availability of the Heyden service man and electricial from Nordic 2. Drilling formation to 10370'. 2.6 bpm @ 2350 psi..6K WOB, ROP 12. Ream two passes and dry tag clean. Swap well to flo pro. Circulate Flo Pro to mill. POH swapping well to flo pro. LD milling assembly and PU drilling assembly. Mills gauged 3.8 GO&3.79 NO GO. M/U drilling build BHA #4. HYC bit w/ 1.2 deg motor and res. Overall BHA length = 78.91' Stab injector. RIH w/drilling BHA. Log GR tie-in. +20' correction. Drill build section, 2.6/2.6 bpm C~ 3300-3600 psi, TF 60L, ROP 20-45 fph, WOB 2-3K, 39 deg incl, ECD 10.1. Drilled to 10,423'. Drill build section, 2.5/2.5 bpm ~ 3100-3500 psi, TF 60L, ROP 25-45 fph, WOB 1-2.5K, 40 deg incl, ECD 10.1. Drilled to 10,485'. Drill build section, 2.5/2.5 bpm ~ 3000-3400 psi, TF 120L, ROP 15-30 fph, WOB 1 K, 41 deg incl, ECD 10.1. Drilled to 10,500'. W iper trip to window. Log GR tie-in at RA tag. +0.5' correction. MAD pass to bottom to re-log resistivity. Drill build section, 2.5/2.5 bpm (~ 3000-3300 psi, TF 120R, ROP 30-50 fph, WOB 1 K, 38 deg incl, ECD 10.1. Drilled to 10,565'. Drill build section thru Zone 4 /Zone 3, 2.5/2.5 bpm 3000-3500 psi, TF 120R, ROP 15-60 fph, WOB 1-2K, 33 deg incl, ECD 10.1. Drilled to 10,650'. Wiper to window. OK Drill build section thru Zone 3, 2.5/2.48 bpm C~ 3000-3500 psi, TF 120R, ROP 15-60 fph, WOB 1-2K, 33 deg incl, ECD 10.11. Drilled to 10,715 Exit Zone 3 Drill build section Zone 2, 2.6/2.59 bpm 03500- 3600 psi, TF HS, ROP 75 fph, WOB 2.5K, 32 deg incl, ECD 10.26 Wiper to window. Drill build section 2.6/2.59 bpm @3500- 3600 psi, TF HS, ROP 25-90 fph, WOB 1.8K, 48 deg incl, ECD 10.22 Wiper to 10385 window. Log tie-in. +1' correction wiper to TD. Drill build section 2.6/2.59 bpm X3500- 3600 psi, TF HS, ROP 60 fph, WOB 2.2K, 63.8 deg incl, ECD 10.34 Drill to 10989. Lost MWD data. POH for MWD failure. Printed: 2/13/2008 2:43:22 PM BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 Date ;From - To Hours ~, ~ ~ Phase Description of Operations Task Code NPT 1/26/2008 17:30 - 19:45 2.25 DRILL N DFAL PROD1 S/B injector. UD drilling build BHA #4. Bit graded 6/2/i. Troubleshoot BHI tools. EDC Shortage. 19:45 - 20:00 0.25 DRILL N DFAL PROD1 M/U drilling BHA #5. Resistivity, 1.0 deg motor, Smith BC bit. Overall BHA length = 78.91' Stab injector. 20:00 - 22:00 2.00 DRILL N DFAL PRODi RIH w/drilling BHA. 22:00 - 22:20 0.33 DRILL N DFAL PROD1 Log GR tie-in to RA tag. +21' correction. 22:20 - 22:35 0.25 DRILL N DFAL PROD1 RIH to bottom. Ta at 10,989'. 22:35 - 00:00 1.42 DRILL P PROD1 Drill build section, 2.6/2.4 bpm C~ 3500-3900 psi, TF 45R, ROP 35-50 fph, WOB 1.5K, 73 deg incl, ECD 10.3. Drilled to 11,041'. 1/27/2008 00:00 - 02:00 2.00 DRILL P PROD1 Drill build section, 2.5/2.3 bpm C~ 3300-3900 psi, TF 120R, ROP 55-90 fph, WOB 1.5-3K, 77 deg incl, ECD 10.3. Drilled to f 1,107'. Began mud swap to new FloPro. 02:00 - 03:15 1.25 DRILL P PRODi Drill build section, 2.6/2.45 bpm C~? 3100-3600 psi, 7F 60R, ROP 40-80 fph, WOB 1-2K, 79 deg incl, ECD 9.8. Drilled to 11,150'. 03:15 - 04:00 0.75 DRILL P PROD1 Wiper trip to window. RIH to bottom. Hole clean. 04:00 - 05:30 1.50 DRILL P PROD1 Drill build /lateral, 2.6/2.5 bpm C~ 3100-3900 psi, TF 75R, ROP 70-100 fph, WOB 2-3K, 85 deg incl, ECD 9.9. Drilled to 11,200'. 05:30 - 07:00 1.50 DRILL P PROD1 Drill Z1A lateral, 2.6/2.45 bpm ~ 3100-3600 psi, TF 60L, ROP 80-120 fph, WOB 1.5-3.5K, 89 deg incl, ECD 9.9. Drilled to 11,300'. Note water in cellar floating the spill containment. Very slight bubbling. Notified wells intrgrety engineer. Callled for vac truck to suck cellar. 07:00 - 08:00 1.00 DRILL P PROD1 Wiper to window. 08:00 - 09:45 1.75 DRILL P PROD1 Drill Z1A lateral, 2.53/2.43 bpm @ 3100-3600 psi, TF 100L, ROP 80-100 fph, WOB 1.5-3.5K, 89 deg incl, ECD 9.88. Drilled to 11,450'. 09:45 - 10:30 0.75 DRILL P PROD1 Wiper thru 7" to 10300'. Orienter failure. Not responding to command. 10:30 - 12:00 1.50 DRILL N DFAL PROD1 POOH for orienter failure. Open EDC & POH. 2.7 bpm at 2670 psi 12:00 - 13:30 1.50 DRILL N DFAL PROD1 C/O drilling BHA to BHA #6 13:30 - 15:20 1.83 DRILL N DFAL PROD1 RIH to.10360. 15:20 - 15:30 0.17 DRILL N DFAL PROD1 Log tie-in. correction +19'. 15:30 - 16:00 0.50 DRILL N DFAL PROD1 RIH to TD 16:00 - 16:30 0.50 DRILL N DFAL PROD1 D 'll to 1 stall then no motor work. No pressure changes. PU off bottom vibration severity low compared to previous off bottom readings. Un able to drill. 16:30 - 18:15 1.75 DRILL N DFAL PROD1 POH 18:15 - 20:15 2.00 DRILL N DFAL PROD1 S/B injector. UD drilling BHA #6. BHI troubleshoot BHA tools, orienter failure. M/U new tool string. 20:15 - 20:45 0.50 DRILL N DFAL PROD1 M/U lateral drilling BHA #7. Rebuild Smith BC bit, 1.0 deg motor. Overall BHA length = 78.91' Stab injector. 20:45 - 22:50 2.08 DRILL N DFAL PROD1 Test BHI tools. RIH w/drilling BHA #7. 22:50 - 23:00 0.17 DRILL N DFAL PROD1 Log tie-in to RA tag. +17' correction. 23:00 - 23:30 0.50 DRILL N DFAL PROD1 RIH to bottom. Tag bottom at 11454' 23:30 - 00:00 0.50 DRILL P PROD1 Drill Z1A lateral, 2.65/2.5 bpm C~ 3300-3700 psi, TF 30R, ROP 70 fph, WOB 1.5-3.5K, 87 deg incl, ECD 10.1. Printed: 2/13/2008 2:43:22 PM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task i Code ~I NPT Phase Description of Operations 1/27/2008 23:30 - 00:00 0.50 DRILL P PROD1 Drilled to 11,480'. 1/28/2008 00:00 - 01:45 1.75 DRILL P PROD1 Drill Z1A lateral, 2.6/2.4 bpm @ 3300-3600 psi, TF 100R, ROP 90 fph, WOB 2-3K, 88 deg incl, ECD 10.0. Dr' I t 1 01:45 - 02:50 1.08 DRILL P PROD1 Wiper trip to window. RIH clean to bottom. 02:50 - 04:00 1.17 DRILL P PROD1 Drill Z1A lateral, 2.6/2.4 bpm ~ 3300-3800 psi, TF 90L, ROP 80 fph, WOB 2-3K, 90 deg incl, ECD 10.2. Drilled to 11,660'. 04:00 - 06:00 2.00 DRILL P PROD1 Drill Z1A lateral, 2.5/2.2 bpm C~ 3300-3700 psi, TF 90L, ROP 80-100 fph, WOB 1.5-3K, 90 deg incl, ECD 10.2. Drilled to 11,750'. 06:00 - 07:20 1.33 DRILL P PROD1 Wiper trip to window. 07:20 - 11:45 4.42 DRILL P PROD1 Drill Z1A lateral, 2.5/2.35 bpm C~ 3300-3700 psi, TF 60R, ROP 40-60 fph, WOB 1.85K, 88 deg incl, ECD 10.2. Drilled to 11900. 11:45 - 12;40 0.92 DRILL P PROD1 Wiper to tailpipe. 12:40 - 12;50 0.17 DRILL P PROD1 Log tie-in Correction = +4.5' 12:50 - 13:30 0.67 DRILL P PROD1 RIH to TD. Swap to new mud. 13:30 - 16;00 2.50 DRILL P PROD1 Drill Z1A lateral, 2.4/2.3 bpm ~ 2800-3500 psi, TF 20R, ROP 20-100 fph, WOB 4.OK, 89 deg incl, ECD 9.88. Drilled to 12050 16:00 - 17:35 1.58 DRILL P PRODi Wiper to window. 17:35 - 19:20 1.75 DRILL P PROD1 Drill Z1A lateral, 2.6/2.4 bpm ~ 3300-3600 psi, TF 90R, ROP 120 fph, WOB 1-2K, 90 deg incl, ECD 10.0. Hole getting differentially sticky. Drilled to 12,200' 19:20 - 21:20 2.00 DRILL P PROD1 Wiper trip to window. 10K overpull at 12150'. Ratty hole from 12020'-12045', ream hole section. RIH clean to bottom. 21:20 - 22:00 0.67 DRILL P PRODi Drill Z1A lateral, 2.6/2.45 bpm C~3 3200-3900 psi, TF 100R, ROP 110 fph, WOB 2K, 90 deg incl, ECD 10.1. Drilled to 12,270'. 22:00 - 23:10 1.17 DRILL P PRODi Drill Z1A lateral, 2.6/2.4 bpm @ 3400-4000 psi, TF 110R, ROP 120 fph, WOB 2-3K, 88 deg incl, ECD 10.2. Drilled to 12,350'. 23:10 - 00:00 0.83 DRILL P PROD1 Wiper trip to window. 1/29/2008 00:00 - 00:30 0.50 DRILL P PROD1 Continue wiper trip to window. Hole clean. 00:30 - 00:40 0.17 DRILL P PROD1 Log GR tie-in at RA tag. +7' correction. 00:40 - 01:20 0.67 DRILL P PROD1 RIH clean to bottom. 01:20 - 02:45 1.42 DRILL P PROD1 Drill Z1A lateral, 2.6/2.4 bpm ~ 3400-3800 psi, TF 90L, ROP 115-140 fph, WOB 1-2K, 89 deg incl, ECD 10.2. Drilled to 12 500'. 02:45 - 03:00 0.25 DRILL P PROD1 Wiper trip to window. 03:00 - 04:00 1.00 DRILL N SFAL PROD1 At 12,040', roller broke on SLB injector. Park coil, pump at min rate while SLB repairs injector. Replaced 4 rollers on injector. 04:00 - 06:00 2.00 DRILL P PROD1 Continue wiper trip to window. 06:00 - 08:50 2.83 DRILL P PROD1 Drill Z1A lateral, 2.4/2.3 bpm ~ 3400-3800 psi, 3170 FS, TF 90L, ROP 115-140 fph, WOB 2-3K, 90.8 deg incl, ECD 10.3. 08:50 - 11:00 2.17 DRILL P PROD1 Wiper to window. OK 11:00 - 14:10 3.17 DRILL P PROD1 Pre mud swap drill parameters. Drill Z1A lateral, 2.56/2.37 bpm ~ 4100 psi, 3670 FS, TF 30L, ROP 80 fph, WOB 1.6K, 86.8 deg incl, ECD 10.44. Post Mud swap parameters. 2.53/2.41 3680 psi, 3525 psi = FS, ROP 50, WOB .7 Printed: 2/13/2008 2:43:22 PM • BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 Date Frorn - To Hours '~ Task .Code NPT Phase ~ Description of Operations 1/29/2008 14:10 - 15:45 1.58 DRILL P PROD1 Wiper to 10300'. 15:45 - 15:55 0.17 DRILL P PRODi Log tie-in correction +1'. 15:55 - 16:30 0.58 DRILL P PROD1 Wiper to TD. Set down at 11680 .~ 16:30 - 18:30 2.00 DRILL P PROD1 Drill Z1A lateral, 2.3/2.2 bpm ~ 3400-3800 psi, 3200 FS, TF 60R, ROP 115-140 fph, WOB 2-3K, 90.8 deg incl, ECD 10.3. Drilled to 12947.5 18:30 - 21:00 2.50 DRILL P PROD1 Wiper trip to window 21:00 - 22:30 1.50 DRILL P PROD1 Drill Z1A lateral, 2.89/2.64 bpm ~ 3450-3800 psi, 3200 FS, TF 90R, ROP 80-90 fph, WOB 1-2K, 91.53 deg inc, ECD 10.22. Drilled to 13023'. 22:30 - 23:30 1.00 DRILL P PROD1 Differential) stuck ulled to 80K, .2 bpm losses. Shut down pump and hold neutral weight for 15 min. Still no movement. Wait another 15 min.~Pulled free at 75K. PUH to 12800' 23:15 - 00:00 0.75 DRILL P PRODi Continue drilling ahead. Depth at midnight 13048' 1/30/2008 00:00 - 01:05 1.08 DRILL P PRODi Drilling ahead from 13048' to 13101' - 01:05 - 03:00 1.92 DRILL P PROD1 Wiper trip to window 03:00 - 03:10 0.17 DRILL P PROD1 Tie in, +11.5' correction 03:10 - 05:00 1.83 DRILL P PRODi Wiper trip to TD, laying in new flo-pro 05:00 - 06:40 1.67 DRILL P PROD1 10300', open EDC and POOH 06:40 - 07:00 0.33 DRILL P PROD1 LD drilling BHA 07:00 - 07:30 0.50 BOPSU P PROD1 Weekl function test of BOP's 07:30 - 09:30 2.00 CASE P RUNPRD RU N2. PJSM Inhibit CT and PT lines to 4000 psi. blow down with N2. 09:30 - 10:15 0.75 CASE P RUNPRD POP off well. remove CTC and install grapple. 10:15 - 10:30 0.25 CASE P RUNPRD PJSM for pulling back CT to reel and reel swap. 10:30 - 11:45 1.25 CASE P RUNPRD Pull back CT to reel and secure. 11:45 - 12:00 0.25 CASE P RUNPRD PJSM to swap reels. 12:00 - 13:30 1.50 CASE P RUNPRD Lower reel to trailer. Swap trailer and spot trailer under reelhouse. Raise reel to reel house. Install hardline in reel. Install grapple in CT. 13:30 - 13:40 0.17 CASE P RUNPRD PJSM for pulling CT across to injector. 13:40 - 14:30 0.83 CASE P RUNPRD Pull CT to injector. 14:30 - 15:45 1.25 CASE P RUNPRD Fill hole well took 10 bbl in 8 hours.Prep floor to run liner 15:45 - 16:15 0.50 CASE P RUNPRD PJSM for linerjob. 16:15 - 18:00 1.75 CASE P RUNPRD PU liner and run 51 'ts of 2-7/8" liner. Fill 2-7/8" liner with H2O. 18:00 - 18:30 0.50 CASE P RUNPRD PJSM 18:30 - 23:00 4.50 CASE P RUNPRD Continue PU linen 43 Jts. 3-3/16" and 8 Jts. 3-1/2", CTLRT. Fill liner with H2O 23:00 - 00:00 1.00 CASE P RUNPRD Install CTC, Pump 10 Bbls. MEOH, 5 Bbls. H2O. 1/31/2008 00:00 - 01:00 1.00 CASE N WAIT RUNPRD Wait on MEOH 01:00 - 03:00 2.00 CASE P RUNPRD Pump 10 Bbls. MEOH, 5 Bbls H2O, install dart and displace with flo-pro, coil volume 58.1 03:00 - 05:05 2.08 CASE P RUNPRD RIH total BHA 3128.25'. U wt. at window 40K 05:05 - 06:00 0.92 CASE P RUNPRD 12766', tagging up, down wt, 15K, up wt. 60K. Pulled up to 12700 at 75K. Free down to 12730'. worked pipe in this area, able to pull up past 12700 and weight dropped off to 50K. 06:00 - 09:30 3.50 CASE P RUNPRD Work to liner thru 12706, 12732, 12800, 12836,12929,13025,13050 53K up 14K DN. 13050 c rrect d called TD. Circulation rates .33bpm in and .21 bpm out. ~ 1290 psi. Increased rate to 1.0 bpm in and .66-.8 out C~3 1660 psi. Multiple tags at 13050' lost 20' and after additional circulation working liner reacquired 13050' Printed: 2/13/2008 2:43:22 PM • • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours ~ Task ~ Code 11/31/2008 109:30 - 12:45 3.251 CASE P 12:45 - 13:00 0.25 CEMT P 13:00 - 14:20 1.33 CEMT P 14:20 - 16:10 I 1.831 CEMT I P 16:10 - 18:00 I 1.831 CEMT I P 18:00 - 18:30 0.50 CEMT P 18:30 - 19:30 1.00 CEMT P 19:30 - 20:30 1.00 CEMT P 20:30 - 21:00 0.50 CEMT P 21:00 - 22:50 1.83 CEMT P 22:50 - 00:00 1.17 CEMT P 2/1/2008 00:00 - 02:30 2.50 CEMT P 02:30 - 02:45 0.25 CEMT P 02:45 - 03:10 0.42 CEMT P 03:10 - 03:30 0.33 EVAL P 03:30 - 07:30 4.00 EVAL P 07:30 - 09:25 1.92 EVAL P 09:25 - 11:50 2.42 EVAL P 11:50 - 12:30 0.67 EVAL P 12:30 - 13:30 1.00 EVAL P 13:30 - 14:30 1.00 EVAL P 14:30 - 17:00 2.50 EVAL P 17:00 - 18:00 1.00 EVAL P 18:00 - 19:00 I 1.001 EVAL I P 19:00 - 19:30 0.50 EVAL P 19:30 - 23:30 4.00 EVAL P 23:30 - 00:00 0.50 EVAL P 2/2/2008 00:00 - 00:30 0.50 PERFO P 00:30 - 00:45 0.25 PERFO P Spud Date: 6/29/1994 Start: 1 /17/2008 End: Rig Release: 2/3/2008 Rig Number: N1 NPT ~ Phase Description of Operations RUNPRD Launch 5/8" aluminum ball with 900 psi. Circulate ball to LRT 1.6/1.5 bpm @ 2275 psi. Ball on seat ~ 52.6 bbl Shear at 4025 psi. Shut do pump . PU to 13041 @ 37K. Swap well to KCL. RU cementers. Build 110 bbl of 2# bio in pits 3&4. RUNPRD PJSM for cement job. RUNPRD Batch mix .Flood lines and PT to 4000 psi. Cement to Wt 13:30 hrs, RUNPRD Pum 40 bbl cement 15.8 ppg at 2/1.9 bpm C~? 1600 -2400 psi. Shut in choke and load wiper dart. Had trouble getting dart thru valve. Unable to push dart thru valve Had to launch with pressure and recheck.Took 35 min. Displace dart with 110 bbl 2# bio due to possible of large excess cement over liner top. Displace at 2.57 bpm . Zero out mirco motion when cement hits shoe. Caught cement as just before picking up liner wiper dart. PU liner wiper on the calculated volume and sheared at 4200 psi. Bumped plug on calculated vol. Lost 6 bbl to the i n. Floats held. Un sting with 740- psi circulate. POH filling metal displacement. RUNPRD POH filling metal displacement while laying in bio 30 bbls C~3 .5 bpm & 70 fpm. Then while swapping to KCL ~ approx 2500' start circulate 2 bpm: however we still had full reel vol of Bio 58.2bbls. Our mistake. Thus sweeping the excessive cement (1-2 bbls estimate) to surface filled possum bellywhile POH at approx 1400'. Consult with Anch decision to clean out to liner top. RUNPRD PJSM RUNPRD Cleaning out possum belly and shaker RUNPRD Jet stack RUNPRD MU 2-7/8" motor and 3.76 parabolic mill RUNPRD RIH, 2.6 BPM ~ 1200 CTP, cement in returns from surface. RUNPRD Slight motor work at 8970', Tag deployment sieve at 9937'_ RUNPRD Confirmed tag at 9937' CTMD, POOH pumping 2.6 BPM, RUNPRD Lay down milling BHA, MU jetting nozzle to clean stack RUNPRD Jet BOP stack LOWERI PJSM LOWERI PU motor, mill, logging tools and CSH LOWERI UP injector. MU to BHA. RIH to 9700'. LOWERI Log down ~ 30 fpm. Clean thru liner top. RIH to 11699. Gas alarm 16ppm. Shut in well and monitor. Shut in 103 psi. Bleed off No Flow. Continue to log in & tag TD at 13063 uncorrected. LOWERi Circulate pert pill to bit LOWERI Log up at 60 fpm to 9580'. LOWERI POH to surface. LOWERi Stand back CSH. LOWERi LD logging tools. Good data, PBTD is 13059'. Layed out gun # 2. LOWERI PT liner la to 2000 si for 30 minutes, 2000 is C~3 0 min, 1954psi ~ 15 min, 1949psi C~ 30 min LOWERI PJSM, pert gun handling LOWERI PU perf guns, 87 total including blanks LOWERI PU 21 stands of 1-1/4" CSH LOWERI Continue running CSH, total of 21 stands LOWERi PU injector Printed: 2/13/2008 2:43:22 PM • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code ~'NPT 2/2/2008 00:45 - 02:30 1.75 PERFOB~ P~ 02:30 - 03:15 0.75 PERFO~BI,I P 03:15 - 03:30 I 0.251 PERFOBI P 03:30 - 04:30 1.00 PERFOB P 04:30 - 04:45 0.25 PERFO P 04:45 - 05:45 1.00 PERFO P 05:45 - 07:30 1.75 PERFO P 07:00 - 14:00 I 7.00 PERFOBI P 14:00 - 15:00 1.00 PERFO P 15:00 - 18:00 3.00 PERFO P 18:00 - 20:30 2.50 WHSUR P 20:30 - 22:00 1.50 RIGD P 22:00 - 23:30 1.50 RIGD P 23:30 - 00:00 0.50 WHSUR P 2/3/2008 00:00 - 03:00 3.00 RIGD P 03:00 - 07:00 4.00 RIGD P Spud Date: 6/29/1994 Start: 1 /17/2008 End: Rig Release: 2/3/2008 Rig Number: N1 Phase Description of Operations LOWERI RIH LOWERI Tagged PBTD at 13041' CTMD down, up weight at 13036'. Corrected depth to PBTD of 13059'. Launch 1/2" steel ball, 5 Bbls. Flo-Pro ahead, 6 bbls. behind. Parked coil at 13052'. LOWERI Dropped pump rate at 45 Bbls. away to .8 BPM ~ 450 CTP. Ball on seat at 54.4 Bbls. Pull up hole while pressuring up. Fired at 3200 psi at bottom shot depth of 13048'. Continue POOH. LOWERI POOH, pumping .8 BPM to maintain returns. Out MM not working LOWERI 9833', flow check well. No flow. LOWERi Continue POOH LOWERI Stand back injector, prep to pull CSH. POH with 21 stands CSH. LOWERI LD 87 Perf auns all shots fired. Perforation Intervals: 11210' - 11400' / 190' / 6 SPF 11440' - 11610' / 170' / 6 SPF 11800' - 11930' / 130' / 6 SPF 11990' - 12170' / 180' / 6 SPF 12330' - 12620' / 290' / 6 SPF ~ 12820' - 12870' / 50' / 6 SPF 12940' - 13048' / 108' / 6 SPF Total 1118' of guns LOWERI Clear floor and unload spent guns from pipe shed. LOWERI RIH with CSH in stands and LD same. POST RIH to 2500', FP well with 60/40 methanol POST Flush coil with fresh water, 10 Bbls. inhibited water, 5 Bbls. Methanol. Blow down with N2 POST Tail coil back to reel. Start cleaning Pits. POST Install BPV POST RD injector for derrick down move. Continue cleaning pits POST ND BOP stack NU and test tree cap. Release rig. Printed: 2/13/2008 2:43:22 PM • • b BP Alaska ~~~ p Baker Hughes INTEQ Survey Report INTEQ Company: $P Amoco Date: 1/30/2008 Time: 14136:19 Page: 1 Field: Prudhoe$ay Co-ordinate(NE)Reference: We11:05-13, True North Site: PB DS D5 Vertical (TVD) Reference: 27:13.6/29/1994:00:00 62.5 Well: ' 05-13 Section (VS) Reference: Well (O.OON,O.OOE,57.38Azi) Wellpath; 05-13B SnrveyCakulation Method: Minimum Curvature Db: Orate Field: Prudhoe Bay North Slope UNITED STATES 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 DS 05 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5947204.70 ft Latitude: 70 15 35.696 N From: Map Easting: 697428.91 ft Longitude: 148 24 14.424 W Positron Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 05-13 Slot Name: 13 05-13 Well Position: +N/-S 1981.51 ft Northing: 5949180.16 ft Latitude: 70 15 55.184 N +E/-W -200.70 ft Easting : 697176.35 ft Longitude: 148 24 20.265 W Position Uncertainty: 0.00 ft Wellpath: 05-13B Drilled From: 05-13A 500292025002 Tie-on Depth: 10346.00 ft Current Datum: 27:13 6/29/1994 00:00 Height 62.46 ft Above System Datum: Mean Sea Level Magnetic Data: 12/5/2007 Declination: 23.61 deg Field Strength: 57672 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.46 0.00 0.00 57.38 Survey Program for Definitive Wellpath Date: 1/2/2008 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 649.46 10029.00 1 : Camera based mag multi sho CB-MAG-MS Camera based mag multi shot 10283.00 10346.00 MWD Standard (10283.00-11954.0 MWD MWD -Standard 10347.00 13107.00 MWD (10347.00-13107.00) MWD MWD -Standard Annotation MD TVD ft ft 10346.00 8304.07 TIP 10347.00 8304.90 KOP 13107.00 8812.77 TD Survey: MWD Start Date: 1/28/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path i by BP Alaska sus Baker Hughes INTEQ Survey Report INTE Q Company: BP Amoco. Date: 1/30/2008 Time: 14:36;18 Page: 2 Field: Prudhoe Bay Go-ordinate(NE)Reference: We11: 05-73, True North Site:. PB bS-05 Vertical ('PVD) Reference: 27:'.13:6/29/1 994 00:00 62.5 Weli: 05- 13 Section (VS) Reference::. Wel( (t):OON,O :OQE,57.38Azi) Wellpath: 05- 136 Survey Cakuladon Method: Minimum Curvature Db: OraGe Survey MD ' Incl Azim TVD Sys TVD N/S E/VV MapN MapE VS DLS Tool ft deg deg: ft ft ft ft ft ft ft deg/100ft 10346.00 33.70 72.40 8304.07 8241.61 3621.44 3250.68 5952885.29 700330.89 4690.15 0.00 MWD 10347:00 33.77 72.18 8304.90 8242.44 3621.61 3251.21 5952885.47 700331.42 4690.69 14.08 MWD 10380.93 36.40 65.08 8332.67 8270.21 3628.74 3269.33 5952893.07 700349.34 4709.80 14.30 MWD 10411.23 38.15 59.38 8356.79 8294.33 3637.30 3285.54 5952902.05 700365.32 4728.06 12.77 MWD 10441.32 40.36 54.26 8380.09 8317.63 3647.73 3301.46 5952912.90 700380.96 4747.09 13.03 MWD 10481.96 39.07 47.51 8411.37 8348.91 3664.07 3321.59 5952929.76 700400.65 4772.86 11.07 MWD 10501.48 37.57 44.22 8426.68 8364.22 3672.49 3330.28 5952938.41 700409.12 4784.72 12.97 MWD 10530.52 34.64 48.06 8450.15 8387.69 3684.36 3342.60 5952950.59 700421.12 4801.49 12.74 MWD 10565.20 33.31 57.06 8478.93 8416.47 3696.13 3357.93 5952962.76 700436.14 4820.75 14.99 MWD 10591.07 32.53 62.54 8500.65 8438.19 3703.20 3370.07 5952970.15 700448.09 4834.78 11.90 MWD 10621.55 31.85 70.22 8526.45 8463.99 3709.71 3384.91 5952977.04 700462.76 4850.79 13.60 MWD 10667.29 30.92 76.26 8565.51 8503.05 3716.58 3407.69 5952984.51 700485.34 4873.69 7.17 MWD 10702.13 29.60 68.53 8595.61 8533.15 3721.86 3424.40 5952990.22 700501.91 4890.60 11.80 MWD 10726.95 32.20 65.50 8616.91 8554.45 3726.85 3436.12 5952995.51 700513.50 4903.17 12.21 MWD 10756.21 36.11 62.08 8641.12 8578.66 3734.12 3450.84 5953003.17 700528.02 4919.49 14.88 MWD 10787.55 41.07 60.33 8665.61 8603.15 3743.55 3467.96 5953013.04 700544.88 4938.98 16.20 MWD 10816.51 45.27 56.41 8686.73 8624.27 3753.96 3484.81 5953023.88 700561.45 4958.78 17.20 MWD 10846.39 49.91 55.99 8706.88 8644.42 3766.23 3503.13 5953036.63 700579.45 4980.83 15.56 MWD 10876.87 53.78 56.31 8725.70 8663.24 3779.57 3523.03 5953050.49 700598.99 5004.79 12.72 MWD 10905.31 58.63 57.54 8741.52 8679.06 3792.46 3542.84 5953063.89 700618.45 5028.42 17.43 MWD 10935.19 63.43 58.42 8755.99 8693.53 3806.31 3565.00 5953078.32 700640.24 5054.55 16.27 MWD 10968.21 68.11 60.42 8769.53 8707.07 3821.62 3590.92 5953094.30 700665.75 5084.63 15.21 MWD 10993.97 72.02 62.37 8778.32 8715.86 3833.21 3612.17 5953106.44 700686.69 5108.78 16.76 MWD 11022.35 74.52 66.11 8786.49 8724.03 3845.01 3636.65 5953118.88 700710.85 5135.76 15.39 MWD 11053.87 75.84 68.06 8794.55 8732.09 3856.87 3664.71 5953131.47 700738.59 5165.79 7.30 MWD 11090.89 76.37 72.52 8803.45 8740.99 3868.99 3698.53 5953144.47 700772.08 5200.81 11.78 MWD 11120.37 79.66 76.58 8809.57 8747.11 3876.66 3726.32 5953152.86 700799.66 5228.35 17.49 MWD 11150.97 81.11 81.54 8814.68 8752.22 3882.38 3755.93 5953159.36 700829.11 5256.37 16.67 MWD 11206.37 86.28 84.87 8820.77 8758.31 3888.89 3810.59 5953167.29 700883.57 5305.91 11.08 MWD 11234.49 89.60 81.28 8821.78 8759.32 3892.27 3838.47 5953171.41 700911.35 5331.22 17.38 MWD 11264.67 90.80 78.48 8821.67 8759.21 3897.58 3868.18 5953177.49 700940.91 5359.10 10.09 MWD 11300.89 88.56 73.70 8821.87 8759.41 3906.28 3903.33 5953187.11 700975.81 5393.40 14.57 MWD 11326.75 89.36 71.23 8822.34 8759.88 3914.07 3927.98 5953195.54 701000.25 5418.36 10.04 MWD 11360.49 88.80 67.98 8822.89 8760.43 3925.82 3959.59 5953208.12 701031.55 5451.32 9.77 MWD 11395.01 89.08 64.23 8823.52 8761.06 3939.80 3991.14 5953222.92 701062.72 5485.43 10.89 MWD 11428.80 88.06 59.34 8824.37 8761.91 3955.77 4020.90 5953239.65 701092.05 5519.10 14.78 MWD 11465.80 86.78 62.25 8826.03 8763.57 3973.80 4053.16 5953258.53 701123.82 5555.99 8.58 MWD 11496.28 88.43 66.21 8827.31 8764.85 3987.04 4080.58 5953272.47 701150.88 5586.22 14.06 MWD 11526.88 88.71 70.19 8828.07 8765.61 3998.39 4108.98 5953284.57 701178.97 5616.26 13.03 MWD 11568.94 90.89 76.90 8828.22 8765.76 4010.30 4149.29 5953297.53 701218.95 5656.63 16.77 MWD 11600.54 91.23 81.48 8827.63 8765.17 4016.22 4180.31 5953304.26 701249.81 5685.96 14.53 MWD 11631.22 90.34 79.01 8827.21 8764.75 4021.42 4210.54 5953310.25 701279.89 5714.22 8.56 MWD 11661.64 91.96 75.54 8826.60 8764.14 4028.12 4240.21 5953317.72 701309.37 5742.82 12.59 MWD 11692.99 89.57 72.62 8826.18 8763.72 4036.72 4270.34 5953327.10 701339.27 5772.84 12.04 MWD 11722.41 89.51 67.83 8826.42 8763.96 4046.67 4298.02 5953337.78 701366.68 5801.51 16.28 MWD 11754.52 88.10 66.83 8827.09 8764.63 4059.04 4327.64 5953350.92 701395.96 5833.13 5.38 MWD 11785.73 87.82 70.83 8828.20 8765.74 4070.30 4356.72 5953362.94 701424.73 5863.69 12.84 MWD 11815.52 89.02 73.66 8829.02 8766.56 4079.38 4385.08 5953372.76 701452.84 5892.47 10.32 MWD 11850.27 89.14 79.75 8829.58 8767.12 4087.37 4418.88 5953381.63 701486.42 5925.24 17.53 MWD 11883.18 90.12 81.54 8829.79 8767.33 4092.72 4451.35 5953387.82 701518.73 5955.47 6.20 MWD 11915.52 91.35 82.16 8829.38 8766.92 4097.30 4483.36 5953393.24 701550.61 5984.91 4.26 MWD 11948.40 92.30 85.60 8828.33 8765.87 4100.80 4516.03 5953397.60 701583.18 6014.31 10.85 MWD 11974.62 93.57 88.39 8826.99 8764.53 4102.18 4542.17 5953399.66 701609.28 6037.07 11.68 MWD • • b BP Alaska B P Baker Hughes INTEQ Survey Report 1NTE Q :Company: BP Amoco Date: 1/30/2008 Time: 14:36:19 Page: 3 Field: Prudhoe Bay .. Co-ordinatetNE) Reference: Well: 05-1,3, True North Site: PB DS 05 Vertical (TVD) Reference: 27:13 6!29/1 994 00:00 62.5 WeIL• 05- 13 Section (VS) Reference: Well (O.OON,O .OOE,57.38 Azi) Wellpath:' 05- 13B Snrvey Calculation Method: Minimum Curvature Dh: Orate Survey MD ' Inc! ' Azim TVD Sys TVD N!S E/W MapN MapE: VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/10011 12003.78 93.66 92.96 8825.15 8762.69 4101.83 4571.27 5953400.08 701638.37 6061.39 15.64 MWD 12036.94 92.52 96.33 8823.36 8760.90 4099.15 4604.26 5953398.26 701671.42 6087.74 10.71 MWD 12070.92 89.72 99.78 8822.70 8760.24 4094.39 4637.89 5953394.38 701705.16 6113.50 13.07 MWD 12100.62 89.94 104.35 8822.79 8760.33 4088.19 4666.93 5953388.94 701734.35 6134.61 15.40 MWD 12130.60 90.46 107.90 8822.68 8760.22 4079.86 4695.73 5953381.37 701763.35 6154.37 11.97 MWD 12158.04 90.80 111.70 8822.38 8759.92 4070.57 4721.54 5953372.76 701789.40 6171.10 13.90 MWD 12188.06 91.14 116.02 8821.87 8759.41 4058.43 4748.98 5953361.35 701817.15 6187.67 14.43 MWD 12222.68 90.40 120.11 8821.41 8758.95 4042.15 4779.52 5953345.87 701648.10 6204.62 12.00 MWD 12255.82 89.63 124.17 8821.40 8758.94 4024.52 4807.58 5953328.98 701876.61 6218.75 12.47 MWD 12292.00 87.27 127.81 8822.38 8759.92 4003.27 4836.83 5953308.51 701906.41 6231.93 11.99 MWD 12321.54 87.02 131.16 8823.85 8761.39 3984.52 4859.60 5953290.36 701929.66 6241.00 11.36 MWD 12350.96 88.65 134.95 8824.96 8762.50 3964.45 4881.08 5953270.86 701951.65 6248.27 14.01 MWD 12379.94 89.82 138.57 8825.35 8762.89 3943.34 4900.92 5953250.28 701972.04 6253.61 13.13 MWD 12411.98 90.46 143.01 8825.27 8762.81 3918.52 4921.17 5953226.00 701992.94 6257.28 14.00 MWD 12442.28 92.43 141.44 8824.50 8762.04 3894.58 4939.73 5953202.56 702012.11 6260.00 8.31 MWD 12474.28 93.14 138.42 8822.95 8760.49 3870.13 4960.30 5953178.65 702033.31 6264.15 9.68 MWD 12503.48 92.31 135.25 8821.56 8759.10 3848.86 4980.25 5953157.91 702053.81 6269.48 11.21 MWD 12535.94 91.44 131.45 8820.50 8758.04 3826.59 5003.84 5953136.27 702077.97 6277.34 12.00 MWD 12574.40 89.85 127.46 8820.06 8757.60 3802.16 5033.52 5953112.63 702108.29 6289.18 11.17 MWD 12606.26 87.67 123.83 8820.75 8758.29 3783.60 5059.40 5953094.75 702134.64 6300.97 13.29 MWD 12633.54 86.62 120.44 8822.11 8759.65 3769.11 5082.47 5953080.87 702158.08 6312.59 12.99 MWD 12670.18 88.34 118.46 8823.72 8761.26 3751.11 5114.34 5953063.72 702190.41 6329.73 7.15 MWD 12702.70 89.75 115.70 8824.27 8761.81 3736.31 5143.29 5953049.68 702219.73 6346.13 9.53 MWD 12735.56 91.53 112.80 8823.90 8761.44 3722.82 5173.24 5953036.98 702250.03 6364.09 10.35 MWD 12769.34 89.51 114.71 8823.59 8761.13 3709.21 5204.16 5953024.19 702281.29 6382.79 8.23 MWD 12798.72 93.65 117.62 8822.78 8760.32 3696.27 5230.51 5953011.94 702307.97 6398.01 17.22 MWD 12827.66 96.30 120.10 8820.27 8757.81 3682.36 5255.75 5952998.69 702333.57 6411.77 12.52 MWD 12859.98 93.32 122.41 8817.56 8755.10 3665.65 5283.28 5952982.71 702361.52 6425.95 11.65 MWD 12899.66 91.53 126.63 8815.88 8753.42 3643.19 5315.94 5952961.12 702394.75 6441.34 11.54 MWD 12929.86 90.03 129.70 8815.47 8753.01 3624.53 5339.67 5952943.09 702418.97 6451.28 11.31 MWD 12960.94 91.35 132.77 8815.10 8752.64 3604.05 5363.04 5952923.23 702442.86 6459.92 10.75 MWD 12991.66 91.57 136.07 8814.31 8751.85 3582.56 5384.97 5952902.32 702465.35 6466.80 10.76 MWD 13023.60 90.06 139.06 8813.86 8751.40 3558.99 5406.52 5952879.32 702487.50 6472.25 10.49 MWD 13056.22 90.92 142.61 8813.58 8751.12 3533.70 5427.12 5952854.59 702508.75 6475.96 11.20 MWD 13107.00 90.92 142.61 8812.77 8750.31 3493.36 5457.95 5952815.07 702540.63 6480.18 0.00 MWD TREE = CfW WEI.LHEAD= ACTUATOR = FMC BA KE2 C KB. ELEV = 62.5' BF. ELEV = KOP = Max Angle = 10300' 96° ~ 12828' Datum MD = NA Datum N D = 8800' SS DRLG DRAFT 13-3/8" CSG, 72#, N-80, ID = 12.347" 271$' Minimum ID = 2.441" ~ 10613' TOP OF 2-7/8" LINER TOP OF 7" LNR -SCAB 4182' ~ 7" LNR -SCAB, 26#, L-80, .0383 bpf, ID = 6.276" ~~ 9878' ~ 9-518" CSG, 47#, N-80, ID = 8.681" ~ 11286' 9-5/8" MILLOUT WWDOW - 10030' -10080' 41 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10300' Inflatable cement retainer 10453' 7" X 41/2" BKR ZXP LNR PKR, ~ = 2.992" 10453' TOP OF 4112" TBG 10474 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" 10587' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 1D = 3.958" 10860' PERFORATION SLINMARY REF LOG: AW5 CNL ON 07/08/94 ANGLEATTOPPERF:87° @ 11210' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11210 - 11400 O 02!03/08 2" 6 11440 - 11610 O 02/03/08 2" 6 11800 - 11930 O 02/03/08 2" 6 11990 - 12170 O 02/03/08 2" 6 12330 - 12620 O 02103/08 2" 6 12820 - 12870 O 02/03/08 2" fi 12940 - 13048 O 02/03/08 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~~ 10985' 05-13B ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3874 3809 32 MMG DMY RK 0 04/14/05 2 7384 6210 49 KBG2LS DMY INT 0 04/14!05 3 9780 7897 48 KBG2LS DMY INT 0 1999 41/2 CAMCO SVLN, 9-CR • SSSV NIP, ID = 3.812" GAS LIFTMANDRELS 4182' ~9-5/8" X 7" ZXP LNR TOP PKR W/ HMC LNR HGR 9872' H9-5/8" X 7"ZXP 7" PKR 9925 7" X 4112" BKR SA B-L-3 HY D PKR 9976' Top of 3-1 /2" Liner, TOC I 9986' --~ 3-t;^" X NIP ID 2 81 - 10249` -1/2' X 3-3/16" x-over 10278' 41 /2" HES X NIP, ID = 3.813" 10300' 41/Z" TUBING TA IL WLEG 11500' 3-3116 x 2-7/8 X-over NOTES: 70° ~ 10994' AND 90° ~ 11234' 3-3/16" X 2-7/8" anted 8 perfed 13095' ~1Aechanical WS (elm) 41/2" GS DEPLOYMENT SLEEVE 10678' ~7" BAKER SABL-3 PKR 10733' 41 /2" OTIS X NIP, ~ = 3.81" 10860" 41/2 TUBING TAIL WLEG ELMD TT NOT LOGGED 2-7/8" LNR -SLOTTED, 6.5#, 11720' L-80, .0056 bpf, ID = 2.441" DATE REV 8Y COMMEMS DATE REV BY COMMENTS 1977 ORIGINAL COMPLETION 08!22194 SIDETRACKED 06/20/98 LAST WORKOVEt~ 02/03108 NORDIC? CTD SIDETRACK PRUDHOE BAY UNff WELL: 05-13A PERMIT No: 1940420 API No: 50-029-20250-01 SEC 32, Tt i N, R15E, 605' FEL 8 3599.16' FNL BP Exploration (Alaska) y .~ ~,::; _~.-: BAKER~~ ~~~ NYGNES INTEQ To Whom It May Concern: 7260 Homer Drive Anchorage, Alaska 99518 Tel 907-267-6600 Fax 907-267-6623 March 7, 2008 Please find enclosed directional survey data for the following wells: A-12A OS-13B ~ 15-45BPB 1 15-45B 18-32B C-35B 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: 6 Cc: State of Alaska, AOGCC i ~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, March 10, 2008 12:25 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU 05-13B / PTD # 207-146 H i Art, Please reference the following well: Well Name: PBU 05-13B Permit #: 207-146 API #: 50-029-20250-02-00 Top Perf MD: 11210' Bottom Perf MD: 13048' This welt began Production on March 7, 2008 Method of Operations is: Flowing Date of Test: 03/08108 Hours Tested: 10 24-Hour Rate /Oil-Bbl: 1,636 24-Hour Rate /Gas-Mcf: 5,319 24-Hour Rate /Water-Bbl: 4,352 Test Rate /Oil-Bbl: 682 Test Rate IGas-Mcf: 2,216 Test Rate /Water-Bbl: 1,813 Choke Size: 77 Gas-Oil Ration: 3,251 Flow Tubing Pressure: 609 Casing Pressure: 720 Oil Gravity-API: Unavailable 3/10/2008 t W: V-07 Colombie, Jody J (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, November 07, 2007 1:19 PM To: Colombie, Jody J (DOA) Subject: FW: V-07 & 05-136 PTD's Hi Jody, Page 1 of 2 It appears that these two Permits have gotten lost (hopefully in-house)... until they surface (if they surface), please make a duplicate copy and send it on over to us in today's pouch. Thanks so very much! Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, November 07, 2007 10:34 AM To: Hubble, Terrie L Subject: RE: V-07 Terrie, According to the pick-up log, V-07 and 05-136 were returned by courier on November 2. Tom From: Maunder, Thomas E (DOA) Sent: Wednesday, November 07, 2007 10:24 AM To: 'Hubble, Terrie L' Subject: RE: V-07 I will do a walk around. From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, November 07, 2007 10:23 AM To: Maunder, Thomas E (DOA) Subject: RE: V-07 Hmmm... I don't have it. I got B-37, but not V-07. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, November 07, 2007 10:19 AM To: Hubble, Terrie L Subject: RE: V-07 Hi Terrie, 1 show that permit was sent back to you ail on 11/2 via courier. Tom 11 /7/2007 ~W: V-07 ~ ~ Page 2 of 2 From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, November 07, 2007 10:15 AM To: Maunder, Thomas E (DOA) Subject: FW: V-07 Hi Tom, We haven't received this Permit to Drill yet and as you can see it looks like we will need it for this weekend. Thanks! Terrie From: Peltier, Brandon Sent: Wednesday, November 07, 2007 9:43 AM To: Hubble, Terrie L Subject: V-07 Terrie Have you seen this permit back from the state? We will be moving over this weekend. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon. Peltier@bp. com 11/7/2007 SARAH PALIN, GOVERNOR ~-7~ ®~d A1`~ 333 W. 7th AVENUE, SUITE 100 ~+ AT ~T C®isQL1ri~A-~tI®1tT L~®~II~~7I®1` vaJA is L ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration Inc. Po Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-13-B BP Exploration Inc. Permit No: 207-146 Surface Location: 3015' FSL, 112' FWL, SEC. 32, T11N, R15E, UM Bottomhole Location: 1382' FSL, 261 FWL, SEC. 28, T11N, R15E, UM Dear Mr. Tirpack, Enclosed is the approved application for permit to drill the above referenced development well. 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). Sincerel , ~ John K. Norman Chairman DATED this ?day of November, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl, ~ STATE OF ALASKA ~~~ ~~~ ~ ~ .V ~ V ~'~~o ALAS~OIL AND GAS CONSERVATION COMMIT~ION ~^`~ OCT 1 9 2007 I ~~ PERMIT TO DRILL ~ 20 AAC 25.005 Alaska Oi! & Gas Cons. Commission 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 pro ^ 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 05-13B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13015 TVD 8750ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 3015' FSL 112' FWL SEC T11 N 32 R15E UM 7. Property Designation: ADL 028325 Pool , , . , , , Top of Productive Horizon: 1370' FSL, 3419' FWL, SEC. 29, T11 N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 15, 2008 Total Depth: 1382' FSL, 261' FWL, SEC. 28, T11 N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 27,800' 4b. Location of Well (State Base Plane Coordinates): Surface: x-697176 y- 5949180 Zone-ASP4 10. KB Elevation (Height above GL): 62.46 feet 15. Distance to Nearest Well Within Pool: 700' 16. Deviated Wells: Kickoff Depth: 10334 feet Maximum Hole An le: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3300 Surface: 2420 18. Casin P ram: S cification To - Settin De th --Bo ttom uanf of C ment c.f. r sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" s-vz~ X a-~,s" 9.3# / 6.2# L-80 STL / TCII 3040' 9975' 7965'ss 13015' 8750'ss 155 sx Class 'G' x 2-7/8" / 6.16# fig. PRESE NT: WELL`CONDITION S UMMARY (To be completed for RedrilFand Re-entry Operations) Total Depth MD (ft): 11954 Total Depth TVD (ft): ggOg Plugs (measured): 10278 Effective Depth MD (ft): 11954 Effective Depth TVD (ft): 8808 Junk (measured): None Casing Length Size. Cement Volume MD Conductor /Structural 112' 20" 224 sx Ar tic et 112' 112' Surface 2718' 13-3/8" 5726 sx Permafrost II 2718' 2718' Intermediate 10030' 9-5/8" 675 sx Class 'G' 275 sx Permafrost 10030' 8064' Pr d ti n Liner 6803' 7" 244 sx Class 'G' 4182' - 10985' 4058' - 8809' Liner ` 1138' 2-718" Uncemented Slotted Liner 10814' - 11952' 8707' - 8808' '` Liner a ears to have ulled u hole -200', offsettin the Slotted intervals too. Ori final de the Perforation Depth MD (ft): Slotted Liner: 10814' - 11952' Perforation Depth TVD (ft): 8707' - 8808' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. thereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT DriAing Engineer Abby Higbie, 564-5480 _ Prepared By Name/Number: Si nature ~ - Phone 564-4387 Date w 17 0 Terrie Hubble, 564-4628 ~ ommission Use Onl Permit To Drill Number: ~~~~ API Number: 50-029-20250-02-00 Permit Appr val See cover letter for Date: D~ other re uirement Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed meth e, gas hydrates, or gas contained shales: ,-/ Samples Req'd: Yes p No Mud Log Req'd: ,^,/Yes L]el No HZS Measures: ~Ye No it ctional Survey Req'd: UO Yes ^ No Other: //~ 2 ~ ~ PPROVED BY THE COMMISSION Date / ,COMMISSIONER Form 70-401 Revised 12/2005 ~ j / ~ t Submit In Duplicate ~rclvll`~AL v \ BP Prudhoe Bay OS-13B CTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: (scheduled to begin December 15, 2007) 1. O MIT-IA, MIT-OA 2. S Pu114-1/2" PX TT Plug at 10,278 3. S Run 2.25" drift as deep as possible (for kill string in the 2-7/8" liner). 4. S Dummy whipstock drift (3.7" x 17') to 10,400' 5. O AC-LDS; AC-PPPOT-IC, T 6. O PT MV, SV, WV 7. O Bleed gas lift and production flowlines down to zero and blind flange 8. O Remove wellhouse, level pad Rig Work: (scheduled to begin on January 15, 2008) 1. MIIZU and test BOPE to 250 psi low and 3500 psi high. 2. Set cement retainer with kill string below in ZXP packer bore at 10,453' 3. Set 4-1/2" x 7" TTWS at 10334' with HS orientation. 4. Down squeeze 20 bbl of 15.8 nna to isolate the parent well 5 6: 8. 9. 10. 11. 12. ~o~-aa Mi113.8" window at 10334' and 10' of rathole. Swap t ewe to o- ro. Drill Lateral: 4.125" OH, 2681' (12 deg/100 planned) Run 3-1/2" x 3-3/16" x 2-7/8" solid liner leaving TOL at 9975' ~ ~~ S ~Er~ v~ Pump primary cement leaving TOC at 9975', 32 bbls of 15.8 ppg liner cmt planned Cleanout liner and MCNL/GR/CCL log Test liner lap to 2000 psi. Perforate liner per asset instructions (1200') Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's 3. Test separator (1200' of prefs) 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: 4-1/8" Casing Program: fully cemented liner • 3-1/2", L-80 9.3# STL 9975' md-10300' and • 3-3/16", L-80 6.2# TCII 10300' and - 11500' and • 2-7/8", L-80 6.16# STL 11500'md - 13015'md • A minimum of 32 bbls 15.8 ppg cement will be used for liner cementing. TOC planned at 9975' 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. Max. planned hole angle is 91 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 27,800 ft. (West) • Distance to nearest well within pool - 700 ft. (11-34) Anti-Collision • No anti-collision issues Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run. Hazards • The maximum recorded H2S level on DS 15 is 27 ppm. • Lost circulation risk is low. • Zone 3 Conglomerate -plan for extra bit trips. Reservoir Pressure • The max res. press. is estimated to be 3300 psi at 8800'ss (7.3 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2420 psi. TREE _ CNV WELLHEAD = FMC ACTUATOR= BAKERC KB. ELEV = 62.5' BF. ELEV = KOP = 10300' Max Angle = 95 (d3 11932' Datum MD = NA Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, D = 12.347" 11 2718' Minimum ID = 2.441" ~ 10613' TOP OF 2-7/8" LINER TOP OF 7" LNR -SCAB 4182' • 1999' 4-1/2 CAMCO SVLN, 9-CR SSSV NIP, D = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3874 3809 32 MMG DMY RK 0 04/14/05 2 7384 6210 49 KBG2LS DMY NT 0 04/14/05 3 9780 7897 48 KBG2LS DMY AYT 0 4182' 9-5/8" X 7" ZXP LNR TOP PKR W/ HMC LNR HGR 9872' -19-5/8" X 7" ZXP 7" PKR I 7" LNR -SCAB, 26#, L-80, .0383 bpf, ID = 6.276" 9878' 8925' 7" X 4-1l2" BKR SAB-L-3 HYD PKR TOP OF 7" LNR 9878' 111111@d 10278' 4-112" HES X N~, ID = 3.813" 9-5/8" MLLOUT WgJDOW - 10030' -10080' 10278' 4-1/2" PX TTP SET (12/03!05) 4-1/2" TBG, 12.8#, L-80, .0152 bpf, D = 3.958" I-I 10300' TOP OF 4-1/2" TBG I~ 10474' 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" ~--~ 10587• TOP OF 2-7/8" LNR -SLOTTED ~ 0' 14-1/2" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" I-I 10860' PERFORATION SUMMARY REF LOG: AWS CNL ON 07/08/94 A NGLE AT TOP PERF: 40 (a~ 10785' Note: Refer to Productpn DB for historical perf data SIZE SPF M(TER\/AL Opn/Sqz GATE SLTD 2 10785 - 11551 C 08!22/94 SLID 2 10587 - 11720 C 11/09/94 s-s/8" CSG, a7#, N-8o, D = 8.s81" I~ 11286' )300, ~--~4-1/2" TUBNG TAB. WLEG ~ 10453' 7" X 4-1 /2" BKR ZXP LNR PKR, D = 2.992" 10587' I-14-1/2" GS DEPLOYMENT SLEEVE \ \ 10678' ~7" BAKER SABL-3 PKR \ \ \ \\ 10733' 4-1/2" OTIS X NIP, D= 3.81" \ \ \ \ \ ~ \\ ~ 10860' 4-1/2 TUBING TAIL WLEG \ ~ \ ; ELMD TT NOT LOGGED ~` 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" 10985' ` 2-7/8" LNR -SLOTTED, 6.5#, ' L-80, .0056 bpf, D = 2.441" ~~gSZ DATE REV BY COMMENTS DATE REV BY COMMENTS 1977 ORIGINAL COMPLETION 05/03/05 TJP/PJC WANER SAFETY NOTE 08/22/94 SIDETRACKED 12/04/05 DAV/PAG SETTTP 06/20/98 LAST WORKOVER 12/17/05 EZL/PJC WAVER SFTY NOTE Df3ETED 02/06/02 RN/TP CORRECTIONS 06/24/04 DFR/KAK CORRECTIONS 04/27!05 MGS/TLH GLV C/O (04/14/05) PRUDHOE BAY UNff WELL: 05-13A PERMfT No: 1940420 API No: 50-029-20250-01 SEC 32, T11 N, R15E, 605' FEL 8 3599.16' FNL BP t3rploration (Alaska) 05-13A TREE = CNV WELLHEAD= FMC ACTUATOR= BAKERC KB. ELEV = 62.5' BF. ELEV = KOP = 10300' Max Angle = 95 ~ 11932' Datum MD = NA Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, D = 12.347" I--I 271 Minimum ID = 2.441" @ 10613' TOP OF 2-7/8" LINER ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3874 3809 32 MMG DMY RK 0 04/14/05 2 7384 6210 49 KBG2LS DMY INT 0 04/14/05 3 9780 7897 48 KBG2LS DMY INT 0 1999' 4-1/2 CAMCO SVLN, 9-CR O SSSV NIP, D = 3.812" GAS LIFT MANDRELS 4182' ~ 9-5/8" X 7" ZXP LNR TOP PKR W/ HMC LNR HGR 17" LNR -SCAB, 26#, L-80, .0383 bpf, D = 6.276" 9872' I~ 9-5/8" X 7" ZXP 7" PKR 9925' I-{7" X 4-1/2" BKR SAB-L-3 HYD 05-13~ ~ Proposed CTD Sidi; s~ ,~,,,, 997' 9-5/8" CSG, 47#, N-80, ID = 8.681" 11286' 9-5/8" MILLOUT WWDOW - 10030' -10080' 4-1 /2" TBG, t 2.6#, L-80, .0152 bpf, D = 3.958" 10300' Ir~IafaGle _r ,~~nr ~e~-. 10453' 7" X 4-1/2" BKR ZXP LNR PKR, ID = 2.992" 10453' ,v= 4-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 10860' PERFORATION SUMMARY REF LOG: AWS CNL ON 07/08/94 ANGLE AT TOP PERF: 40 C~ 10785' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE SLTD 2 10785 - 11551 C 08/22/94 SLID 2 10587 - 11720 C 11!09/94 7" LNR, 29#, L-80, .0371 bpf, D = 6.184" 10985' 2-7/8" LNR -SLOTTED, 6.5#, ' L-80, .0056 bpf, D = 2.441" 119 $'L 1 I I ---i gg75' I~Top of 3-112" Liner, TOC gg$5' 3-1/2" XN NIP, ID = 2.75" 10278' 4-1 /2" HES X NIP, ID = 3.813" 10300' 4-1/2" TUBING TAIL WLEG 11500' aver NOTES: 70° (81 10994' AND 90° ~ 11049' 3-31',6 X :? ~ ~.; ,~ ceded 13015' Mechanical '~ ' 4-1/2" GS DEPLOYMENT SLEEVE 10733' ~4-1/2" OTIS X NP, ID = 3.81" 10860' 4-1/2 TUBING TAIL WLEG ELMD TT NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 1977 ORIGINAL COMPLETION 05/03/05 TJP/PJC WANER SAFETY NOTE 08/22/94 SIDETRACKED 12/04/05 DAV/PAG SETTTP 08/20198 LAST WORKOVER 12/17/05 QL/PJC WANERSFTY NOTE DELETED 02/06/02 RN/TP CORRECTIONS 06/24/04 DFR/KAK CORRECTIONS 04/27/05 MGS/TLH GLV GO (04/14/05) PRUDHOE BAY UNIT WELL: 05-13A PERMfr No: 1940420 API No: 50-029-20250-01 SEC 32, T11 N, R15E, 605' FEL 8 3599.16' FNL BP Exploration (Alaska) by BP Alaska s Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 10/10/2007. Time: 10:00:48 Page: 1 Field: Prtrcihoe Bay Co-erdi®ate(NE) Reference: We11: 05-13, True North Site: PB OS 05 Vertical (TVD) Reference: 27:13 6129/199400:00 132.5 Well: 05-13 Section (VS) Reterener. WeN'(O.OON,O.OOE,95.OOAzi) Welipath: Plan 11, 05-13B Survey Caknlatioa Method: Minimum Curvature Db: Orede ------ Field: Prudhoe Bay North Slope UNITED STATES 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 DS 05 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5947204.70 ft Latitude: 70 15 35.696 N From: Map Eastiog: 697428.91 ft Longitude: 148 24 14.424 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 05-13 Slot Name: 13 05-13 Well Position: +N/-S 1981.51 ft Northing: 5949180.16 ft Latitude: 70 15 55.184 N +E/ W -200.70 ft Fasting : 697176.35 ft Longitude: 148 24 20.265 W Position Uncertainty: 0.00 ft Wellpath: Plan 11, OS-13B Drilled From: 05-13A 50-029-20250-02-00 Tie-on Depth: 10314.00 ft Current Datum: 27:13 6/29/1994 00:00 Height 62.46 ft Above System Datum: Mean Sea Level Magnetic Data: 12/5/2007 Declination: 23.61 deg Field Strength: 57672 aT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/~ +E/-W DireMion ft ft ft deg 28.46 0.00 0.00 95.00 Plan: Plan #11 Date Composed: 10/5/2007 get more separation from 05-13A Version: 26 Principal: Yes Tied-to: From: Definitive Path Targets Name Description Dip. Dir. 05-13B Polygon -Polygon 1 -Polygon 2 -Poygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 05-136 Fault 1 -Polygon 1 -Polygon 2 OS-13B Target 4 05-13B Target 2 05-13B Target 3 05-136 Target 1 TVD ft 62.46 62.46 62.46 62.46 62.46 62.46 62.46 62.46 62.46 62.46 62.46 8813.46 8819.46 8819.46 8822.46 +N/S ft' 4042.67 4042.67 4227.22 4348.76 3604.61 3338.07 3797.59 3609.92 4316.24 4316.24 4496.89 3619.06 4144.39 4274.33 4012.64 Map Map +E/-W Northing Fasting ft ft ft 3580.95 5953315.00 700650.00 3580.95 5953315.00 700650.00 4441.13 5953522.00 701505.00 4689.41 5953650.00 701750.00 5600.28 5952930.00 702680.00 5273.17 5952655.00 702360.00 4534.91 5953095.00 701610.00 3679.66 5952885.00 700760.00 4403.44 5953610.00 701465.00 4403.44 5953610.00 701465.00 4763.32 5953800.00 701820.00 5430.59 5952940.00 702510.00 4586.01 5953443.00 701652.00 4857.53 5953580.00 701920.00 4116.38 5953299.00 701186.00 G- Latitude --> ~-- Longitude -> Deg Min Sec; Deg Min ...Sec 70 16 34.935 N 148 22 35.989 W 70 16 34.935 N 148 22 35.989 W 70 16 36.746 N 148 22 10.938 W 70 16 37.940 N 148 22 3.706 W 70 16 30.615 N 148 21 37.197 W 70 16 27.996 N 148 21 46.727 W 70 16 32.520 N 148 22 8.215 W 70 16 30.679 N 148 22 33.121 W 70 16 37.622 N 148 22 12.034 W 70 16 37.622 N 148 22 12.034 W 70 16 39.396 N 148 22 1.551 W 70 16 30.758 N 148 21 42.138 W 70 16 35.930 N 148 22 6.721 W 70 16 37.207 N 148 21 58.812 W 70 16 34.637 N 148 22 20.399 W by BP Alaska '~ Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 10/10!2007. Tune: 10:00:48 Page: 2 1Field: Prudhoe Bay Co-ordinate(NE) Reference: We11:05-13. True North Site: PB DS 05 Vertical (TVD) Referetce: 27:13`6/29/1994 00:00' 62.5 Well: 05-13 Seetiea (VS) Reterence: VNea (O.OON,O.OOE,95.OOAzi) Wetipath: Plan 11, 05-138 Snrvey Caknlation 1Netlwd: ` `Minimum Curvature Db: Oracle Annotation MD TVD -ft ft 10314.00 8277.68 10334.00 8294.11 10354.00 8310.48 10404.00 8349.89 10544.00 8462.10 10679.00 8577.45 11184.87 8821.19 11244.87 8821.19 11469.87 8821.19 11649.87 8821.19 11799.87 8820.37 11879.87 8819.75 12229.87 8816.71 12379.87 8815.59 12459.87 8815.23 12659.87 8814.07 12739.87 8813.52 13015.00 8812.04 TIP KOP End of 9 Deg/100' DLS 4 5 6 7 8 9 10 11 12 13 14 15 16 17 TD Plan Section Information MD ft Inc! deg Azim deg TVD ft +N/-S ft +E/-W ft DLS Bniid Tarn deg/100ft deg/100ft deglt00ft TFO Target deg. 10314.00 35.20 73.90 8277.68 3616.20 3233.51 0.00 0.00 0.00 0.00 10334.00 34.26 72.98 8294.11 3619.44 3244.43 5.38 -4.70 -4.60 208.77 10354.00 35.96 71.93 8310.48 3622.91 3255.40 9.00 8.48 -5.24 340.00 10404.00 40.04 64.78 8349.89 3634.33 3283.93 12.00 8.17 -14.30 310.00 10544.00 34.32 38.43 8462.10 3684.80 3349.67 12.00 -4.08 -18.82 240.00 10679.00 29.34 67.97 8577.45 3727.30 3404.35 12.00 -3.69 21.89 120.00 11184.87 90.00 65.00 8821.19 3896.84 3784.74 12.00 11.99 -0.59 356.59 11244.87 90.00 57.80 8821.19 3925.54 3837.39 12.00 0.00 -12.00 270.00 11469.87 90.00 84.80 8821.19 3997.02 4048.54 12.00 0.00 12.00 90.00 11649.87 90.00 63.20 8821.19 4046.34 4220.55 12.00 0.00 -12.00 270.00 11799.87 90.62 81.19 8820.37 4092.02 4362.77 12.00 0.41 11.99 88.00 11879.87 90.28 71.60 8819.75 4110.82 4440.44 12.00 -0.43 -11.99 268.00 12229.87 90.67 113.60 8816.71 4095.32 4782.29 12.00 0.11 12.00 89.30 12379.87 90.18 131.59 8815.59 4014.86 4908.14 12.00 -0.33 12.00 91.50 12459.87 90.34 141.19 8815.23 3957.01 4963.26 12.00 0.21 12.00 89.00 12659.87 90.31 117.19 8814.07 383f.56 5117.14 12.00 -0.01 -12.00 270.00 12739.87 90.47 107.59 8813.52 3801.12 5191.02 12.00 0.20 -12.00 271.00 13015.00 90.13 140.60 8812.04 3649.02 5415.72 12.00 -0.13 12.00 90.50 Survey MD Intl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg. ft ft ft ft ft deg1100fE ft deg 10314.00 35.20 73.90 8215.22 3616.20 3233.51 5952879.60 700313.86 0.00 2906.03 0.00 MWD 10334.00 34.26 72.98 8231.65 3619.44 3244.43 5952883.13 700324.70 5.38 2916.63 208.77 MWD 10354.00 35.96 71.93 8248.02 3622.91 3255.40 5952886.88 700335.57 9.00 2927.25 340.00 MWD 10400.00 39.70 65.31 8284.36 3633.25 3281.61 5952897.90 700361.49 12.00 2952.46 310.00 MWD 10404.00 40.04 64.78 8287.43 3634.33 3283.93 5952899.04 700363.79 12.00 2954.68 315.24 MWD 10500.00 35.47 47.44 8363.52 3666.43 3332.55 5952932.41 700411.55 12.00 3000.32 240.00 MWD 10544.00 34.32 38.43 8399.64 3684.80 3349.67 5952951.21 700428.18 12.00 3015.78 253.76 MWD 10600.00 31.44 49.63 8446.70 3706.65 3370.64 5952973.61 700448.57 12.00 3034.76 120.00 MWD 10679.00 29.34 67.97 8514.99 3727.30 3404.35 5952995.13 700481.73 12.00 3066.54 110.58 MWD 10700.00 31.85 67.69 8533.07 3731.34 3414.25 5952999.42 700491.52 12.00 3076.05 356.59 MWD 10800.00 43.84 66.74 8611.89 3755.12 3470.69 5953024.67 700547.31 12.00 3130.20 356.84 MWD 10900.00 55.83 66.13 8676.27 3785.64 3540.59 5953057.02 700616.38 12.00 3197.18 357.59 MWD 11000.00 67.83 65.68 8723.40 3821.58 3620.91 5953095.05 700695.73 12.00 3274.06 357.98 MWD 11098.84 79.68 65.30 8751.00 3860.88 3707.09 5953136.59 700780.85 12.00 3356.49 358.20 05.1381 11100.00 79.82 65.30 8751.21 3861.36 3708.13 5953137.09 700781.88 12.00 3357.48 358.30 MWD by BP Alaska $ Baker Hughes INTEQ Planning Report INTE Q Sorvey MD <ft Iecl deg Azim deg SS TVD ft N/S ft E/W ft 11184.87 90.00 65.00 8758.73 3896.84 3784.74 11200.00 90.00 63.18 8758.73 3903.45 3798.35 11244.87 90.00 57.80 8758.73 3925.54 3837.39 11300.00 90.00 64.42 8758.73 3952.17 3885.63 11400.00 90.00 76.42 8758.73 3985.62 3979.67 11469.87 90.00 84.80 8758.73 3997.02 4048.54 11500.00 90.00 81.18 8758.73 4000.69 4078.44 11600.00 90.00 69.18 8758.73 4026.22 4174.94 11649.87 90.00 63.20 8758.73 4046.34 4220.55 11700.00 90.21 69.21 8758.64 4066.55 4266.39 11800.00 90.62 81.19 8757.91 4092.04 4362.90 11879.87 90.28 71.60 8757.29 4110.82 4440.44 11900.00 90.31 74.01 8757.18 4116.77 4459.66 12000.00 90.44 86.01 8756.53 4134.08 4557.96 12100.00 90.56 98.01 8755.66 4130.58 4657.71 12200.00 90.65 110.01 8754.60 4106.42 4754.56 12229.87 90.67 113.60 8754.25 4095.32 4782.29 12300.00 90.45 122.01 8753.56 4062.65 4844.26 12379.87 90.18 131.59 8753.13 4014.86 4908.14 12400.00 90.22 134.00 8753.06 4001.19 4922.91 12459.87 90.34 141.19 8752.77 3957.01 4963.26 12500.00 90.34 136.37 8752.53 3926.83 4989.69 12600.00 90.33 124.37 8751.94 3862.18 5065.74 12659.87 90.31 117.19 8751.61 3831.56 5117.14 12700.00 90.39 112.37 8751.36 3814.74 5153.56 12739.87 90.47 107.59 8751.06 3801.12 5191.02 12800.00 90.41 114.50 8750.60 3779.40 5247.04 12900.00 90.28 126.80 8749.99 3728.28 5332.78 13000.00 90.15 138.80 8749.61 3660.46 5406.01 13015.00 90.13 140.60 8749.58 3649.02 5415.72 Map1K MapE DIS ft ft degfl( 5953174.57 700857.53 12.00 5953181.53 700870.95 12.00 5953204.64 700909.40 12.00 5953232.51 700956.92 12.00 5953268.42 701050.05 12.00 5953281.61 701118.60 12.00 5953286.07 701148.39 12.00 5953314.11 701244.18 12.00 5953335.42 701289.24 12.00 5953356.82 701334.54 12.00 5953384.83 701430.34 11.98 5953405.63 701507.35 12.02 5953412.08 701526.41 12.00 5953431.96 701624.22 12.00 5953431.08 701724.03 12.00 5953409.46 701821.46 12.00 5953399.10 701849.47 12.00 5953368.06 701912.28 12.00 5953321.96 701977.39 12.00 5953308.68 701992.51 12.00 5953265.57 702034.00 12.00 5953236.10 702061.21 12.00 5953173.46 702138.92 12.00 5953144.20 702191.10 12.00 5953128.35 702227.95 12.00 5953115.72 702265.75 12.00 5953095.47 702322.32 12.00 5953046.62 702409.36 12.00 5952980.74 702484.34 12.00 5952969.56 702494.34 12.00 vs ri"o roar ft deg 3430.71 358.30 MWD 3443.69 270.00 MWD 3480.65 270.00 MWD 3526.39 90.00 MWD 3617.15 90.00 MWD 3684.77 90.00 MWD 3714.24 270.00 MWD 3808.14 270.00 MWD 3851.83 270.00 MWD 3895.73 88.00 MWD 3989.65 88.01 MWD 4065.26 268.00 MWD 4083.89 89.30 MWD 4180.31 89.31 MWD 4279.99 89.39 MWD 4378.57 89.50 MWD 4407.16 89.62 MWD 4471.74 91.50 MWD 4539.55 91.58 MWD 4555.45 89.00 MWD 4599.50 89.01 MWD 4628.46 270.00 MWD 4709.85 269.97 MWD 4763.73 269.90 MWD 4801.47 271.00 MWD 4839.98 270.97 MWD 4897.68 90.50 MWD 4987.54 90.56 MWD 5066.41 90.63 MWD 5077.08 90.67 3 3/16" by BP Alaska Anticollision Report ~.r f~iu~ias 1NTEQ Company: BP AmOCO Dater .10!10!2007 Time: 10:03;37 Page:. 1 Field: Prudhoe Bay Reference Site: PB DS 05 Co~ordi®ate(NE) Re&r+este: WeII: A5-13, True North Reference We1L• 05-13 Vertical (T'VD) Reter+eace+ 27 : 13 6!29/1994 00. 00 62.5 Reference Wellpath: Plan 11, 05-136 Db: Orade GLOBAL SCAN APPLIED: All welipaths within 200'+ 100/1000 of reference - There are'R~aeel~ to this9feli<5pa1 Plan 8 PLANNED PROGRAM Interpolatioe Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 10314.00 to 13015.00 ft Scan Method: Trav Cylinder North Maaimnm Radios: 2500.00 ft Error Sarface: Ellipse + Casing Snrvey Program for Deftaihve Wellpath Date: 10/5/2007 Validated: No Version: 2 Planned From To Snrvey Toolcode Tool Name ft ft 614.46 10029.00 1 : Camera based mag multi sho CB-MAG-MS Camera based mag multi shot 10283.00 10314.00 MWD Standard ( 10283.00-11954.0 MWD MVHD - Standard 10314.00 13015.00 Planned: Plan #11 V26 MWD MWD - Standard Casieg Points MD TVD Diameter Hok Size Name ft ft in in 13015.00 8812.04 3.188 4.125 3 3/16" Summary < Offset We0path ~ Reference Offset Ctr CU No-Go Allowable Site Well Wellpath MD MD Divtaace Area Deviation Wareing ft ft ft;; ft ft PB DS 05 05-02 05-02A V9 10903.91 10800.00 2016.09 822.22 1193.86 Pass: Major Risk PB DS 05 05-13 05-13 V1 11153.66 11100.00 68.65 713.40 -644.76 FAIL: Major Risk PB DS 05 05-13 05-13A V1 11060.53 11100.00 128.34 705.35 -577.01 FAIL: Major Risk PB DS 05 05-30 05-30 V1 10650.00 10900.00 1057.67 561.72 495.95 Pass: Major Risk PB DS 05 05-32 05-32 V1 10321.85 10000.00 1260.63 219.72 1040.91 Pass: Major Risk PB DS 05 05-32 05-32A V7 12650.00 12128.96 677.37 248.13 429.24 Pass: Major Risk PB DS 11 11-06 11-06 V5 Out of range PB DS 11 11-06 11-06A V10 Out of range PB DS 11 11-34 11-34 V1 12783.43 10600.00 617.55 496.75 120.80 Pass: Major Risk PB DS 11 11-38 11-38 V6 Out of range Site: PB DS 05 Well: 05-02 Rule Assigned: Major Risk Wellpath: 05-02A V9 Inter-Site Error: 0.00 ft Reference. Offset Semi-MajorAais CErLCtr No-Go Allowable. MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSi)ista¢ce Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10361.63 8316.63 9700.00 8638.23 115.36 153.74 173.29 102.53 4.500 2488.69 751.35 1737.34 Pass 10375.00 8327.29 9800.00 8719.30 115.78 154.02 173.76 104.99 4.500 2445.39 749.92 1695.47 Pass 10390.77 8339.67 9900.00 8787.16 116.27 154.30 173.88 107.33 4.500 2390.68 750.03 1640.64 Pass 10403.91 8349.82 10000.00 8834.19 116.66 154.47 173.72 108.93 4.500 2321.60 751.67 1569.93 Pass 10425.00 8366.11 10100.00 8858.75 117.85 154.68 172.44 111.14 4.500 2250.32 757.49 1492.83 Pass 10434.93 8373.87 10200.00 8867.71 118.30 154.70 171.00 111.41 4.500 2183.12 764.91 1418.21 Pass 10450.00 8385.76 10300.00 8873.54 118.98 154.62 168.97 112.04 4.500 2128.87 774.50 1354.37 Pass 10465.61 8398.20 10400.00 8877.39 119.49 154.41 166.52 112.46 4.500 2093.30 785.35 1307.96 Pass 10475.00 8405.74 10500.00 8879.13 119.79 154.23 164.09 111.79 4.500 2070.00 796.05 1273.95 Pass 10811.57 8682.60 10600.00 8878.98 116.36 154.22 164.41 97.76 4.500 2049.63 804.71 1244.92 Pass 10854.13 8711.19 10700.00 8875.80 115.73 154.19 162.43 96.04 4.500 2031.30 814.19 1217.12 Pass 10903.91 8740.91 10800.00 8870.66 115.09 154.16 160.55 94.44 4.500 2016.09 822.22 1193.86 Pass Site: PB DS 05 Well: 05-13 Rale Assigned: Major Risk Wellpath: 05-13 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr:Ctr No-GO' Allowabk MD TVD MD TVD Ref ONset TFO+AZI TFO-HS Casing/ASDtstanee Area Deviation .Warn®g ft ft ft ft ft ft deg deg in ft ft' ft 10395.13 8343.06 10400.00 8310.34 116.40 118.77 29.47 323.51 64.28 363.88 -299.60 FAIL 10495.29 8422.15 10500.00 8378.00 120.20 124.03 33.44 345.07 78.44 326.29 -247.84 FAIL 10586.71 8497.86 10600.00 8446.20 120.57 125.89 46.97 0.15 97.41 308.05 -210.64 FAIL • All Measurements are from top of Riser 10/15/2007 f~ ~ 05-13B top of bag . - . - BAG Dowell bttm of bag middle of slips Blind/Shears TOTs middle of pipes 2 3/8" combi ram/slips Mud Cross Mud Cross middle of flow cross middle of blind/shears variable bore pipe 3 1/2"-2 7/8" TOTs middle of pipe/slips 2 3/8" combi ram/slips Swab Valve Flow Tee Alaska Department of Natural Resources Land Administration System Page 1 of 2 . ,.. .. ~~°s ~~f;,orcie~'s Se~~~ch State Cabins ~tt~ ~e~es ~....~,.,,,. Alaska DN Cass u mart' 4_AS ~n~~ I Case Abstract i Case Detail I Land Abstract _. 1-i/r: ~UL ?'{3?~ Sc~arr,h for Status Plat Updates >> of 10/~2'2lii) Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 L. E3ENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 99~ 196612 Case Type: ~3 OlL & GAS LEASE COMP DNR U~7it: 780 OIL AND GAS File Locatiof7: DOG DIV O[L E1ND GAS Case Status: 35 ISS/APPRV/ACTV/ AUTLI ,Status Dcrte: 09/14/1965 Total Acres: 2560.000 Dale Initiuted: 05/28/1965 Uffice of Prit~7a~y Respof~sihility: DOG DIV OIL AND GAS Last Ti~aftsactioft Date: 12/04/2006 Case SuhtyPe : ~~ NOR~'H SLOPE Last Tra~tsaction: AA-NRB ASSIGNMENT APPROVED l~~ridiaf~: U To~a~nshih: Ol 1N R~ni~r: (i l ~l: .ti~c~~:i~ui: 27 S'rcur,n .(cress 61U Search ~'Iats 1lc~ricliun: U Totit~t~~lri~~: I) I I \ l~urn~e.~ 01 ~1., .~'~~c1iu~~: '.S ~<<~Iruir Acres: 6~Q tl~~j~i~/ia~~t: U 7otiti~r~~~/ri/~~ (11 I V~ l~unc~.~ O1 ~I; ~'~~c~i„n.~ ;_~ 5~~~~~ir~ir _Irres: 640 tlc°i~rc/iujr~ U1n~rnshi~,~ (III\ l~urr~~~.~ OICI: S~°~ti~~n.~ >-4 S~c~crrn~~_lcrc's: 640 Lebal Description U~-?8-196 * * *S':9I_E ;1%OTIC'E I LGrll, DLSC'RIP 1I0~~'* '" C1-t-1JJ TIIN-RISE-UM27,28.33,3-1 ?60.00 U- 3- ? ~ ~~ Last updated on 10/22/2007. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2 $325... 10/22/2007 TRANSMITTAL LETTER CHECKLIST WELL NAME /~~~ G~ ' J3~ PTD# o~O~I~6~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing welt , (If last two digits in permit No. API No. 50- - - ' API number are , between 60-69) 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 through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for dame of well) until after Company 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: 7/138007 ^ ~~7 , ~: ~, N O) O N O- ~ ~ ; O, N: : : : N N : C, N ~ •N O ~ L c . ~, U ~ o , Q ~ a j ~ Q ~ ~, O ~ ~ o: ~, ~: ~: m O y M, ~: , , ~ O: N• N: E O fl. ~ C N: f6 ~ a a~~ i c~ ~ ~: ~ c, c o Q ~ ~: ~ ~ ~ .a ~: u.l ~: ~ ~: : , ~ o ri O m F- ~ N; ~,, ~: 'gin; ~ E; m } i ~ ~: ifj: Z: N O: ~: N: i N, ~: O O: i ~: m ~ ~ tn: M, p o c N ' ~ a D ~ ~ o: ~: , O c a; ~, o: ~, ~, ~: ~: O) U, C: ~~ N: ~, d ~, N: f/J, O: ~: a ~ D. v: ~ rn ~3: N• o: an a ~: ~ ~ Q ~ ~ ~ ~ N: Q: O) fd N' ~ _: a ~ O: vy L: ` . f6 U O: ~: U, O: 6 T U: ~: ~: N: ~: V: Z O: O: >: O: 01 ~ : O: O: fU, Q, N: N: C ~, f N. N, N, ' N, N: ' N, N N ' ' N, N: ' N. ' N N: N: N: N, ' ' N N N: N: N, ' ' ' N. 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N N: O N, L >, O, OJ ~, N, C N ~ -7 a Q E' a ~: ~ U c: U c: 7 N: ~ ~, m: ` ~' o' s o' o ~ c' ~' , N, I o : ~: - o c ' O: a Z' w' ~-' ._; ~' 3' m - as ~ 3' 4 o' o' a~' d L' m' ' 3' _ a~, -- 3 • E rn ' ~ v, m: ~ C~ . ~ m o o 4 d . ai s. ~ a ~ m : a, i E , a' ~' o' N, ° c a~~ ' ~ ~~ M, ~ , : L rn N: ~, ~ o N o a 3: ~ o' ~ ~ : ~ o' c E p Z O ~ Q a~ c _ ~; ~; 'iu' ar ~' > `-°' 3, ~ 3; ~ ~~ ~: ..: ~~ ~ ~: v, 'v. « -:, 30 : ~ : ~ ~: ~ ~ a: y : a n 'Q : o. ~~ ~ 3, : o r~ ~~ °~ W (J o a ~_ v' o: c. „ , d m a~ : o a~, ~, ~: ~, v. o, m v. w o m: ~, o~ c . o , o' ~ o: o: d c: a Y o, o o ~. ar v~ E' a~ ~~ E' o: rn c, ~ w .o v: a~ o N, ~: a~: N, c q'f L: d N: ~: d d ~ ~: ~: fl. N: N. d L, ~ N: U, i Q d w, - ~: ~ N: ~, ~: ~ ~, ~ C U: ~3: N: 'a ~ y, p. N: C: t. U, O: ~: ~, O: O, O: 4 Vl, N, N C, N, ~ Ql N (6 ~ f6: O: O A ~ ~ Z. ( !%~, -O: •N, O: d O ~: ( ~: ~, _, L - d ' d N: N: x U N' p: Q N: O N p 3: C, ' w ~: O)~ ' C 6 6 ~ N y • N p: G > ~ ~, ~: , O O. ~, N ~ ~ p. . " C: 0: O,~ U V N: Q N: T "-' ~, ~ Il d X 6, ar : -: O, E: y, m, O. °:' a: °:: . C: ~°, o v' p: , L, c, . : c: . O. ~ ~: 3' ~: , ~ ~ ' : ~: : : v -a ~~ f6~ ~° : . o v> °' ~ p: t. : _ 3' ~, ,v_' o . _: N N c : o: . I. : o: ~~: ~ j : ~ C: ~: ~: f6: ~ ~ o: m: ~-- w ,~? c 3. cmi' cmi' cmi' ~ ~: o ~ 0 0. 0 o, E ~: ~ o a~ ! -o >, o, ° °~ __ a: a;~ = ~; w ~ ~: o a ~: __ c: o: o: U c. ~ ~ ~- a~, ~, -°: -°; -°~ ~u, •~~ m; m; n -°' a~~ Q o ~ _' ~' >' °' 3' ° ' ~ ~' ~' a~ ' w~ ~ ° w ~ ~'' N' ~ ~ ° U 'E~ ~~ ~i J m E' ~ .a ~, ~, ~: ~, a~ a`>, ' a~~ ~, ~, c ~, 3 ~: c: ; c. 'C, F' ~"' ' c ~ 'm: ' ~ a°i i c m ? = a : a o: ' o: a ~ i ~: r ~: m: .N: c~: c ~ ~, r ` Y c ~ a a~: c, ~' J ~ ~; ~' a a ~, w ~ O d o, O; a o: n m U - ~; Q' o 0 ; Z' i o ~ ~ ~. U. U ~, O' ~ m O' O' a, ~° w Q v, ~ O; m Q ' 0 " O L m U ~ ~ ~' ~ ~ a; ~ ~ ~ V ~ V U W a _ ~ : ~- , : , N M d' ~ , M , -: , O - ., , . : , : ~~ : : N M , -, V ~ . , - : c0 I~ W o : : _ O : : . ~ M M M M M ~ O _ n W O ~ _ ~ ~ _ ~i, N N N N N N N N N N M M M i M U i ti 0 ~ C G p V C r R D N N ~ ~~ ~ N R N ~ N U p O .N N W am R O C •~ ~ O ~ J N ~' c ~ ~ ~ O E Q Q. ~ ~ a~ o c~ U ~ a s a ¢ w a~ I °' as c 7 • • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part ofi the history file. To improve the readability of the Well History file and to simplify finding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. tJo special-effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 08/10/27 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/01/30 1783798 O1 3" 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 9240.0000: Starting Depth STOP.FT 13107.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 05-13B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 18.588"N 148 deg 43' 0.723"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 30 Jan 2008 API API NUMBER: 50029202500200 Parameter Information Block #MNEM.UNIT Value ------------------------------- SECT. 32 TOWN.N 11N . RANG. 15E . PDAT. MSL EPD .F - LMF RF FAPD.F 62.46 DMF DF EKB .F 0 EDF .F 62.46 EGL .F 0 CASE.F 10348 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 ~~--r~~ l~li~ L~ OS1 DIRECTIONAL Other Services Line 1 OS2 PRESSTEQ I Other Services Line 2 Remarks (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 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 and an Ultra Slim Resistivity Sub. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 31 Jan 2008 per Mike McTeague with BP Exploration (Alaska), Inc. (8) Tied to 05-13A at 10346 feet MD (8241.6 feet TVDSS). (9) Baker Hughes INTEQ runs 1 and 2 were used to set whipstock at 10347 ft MD (8242.4 ft. TVDSS) and mill window. (11) The sidetrack was drilled from 05-13A through a milled window in a 7 inch liner. Top of window 10351.5 ft.MD (8246.2 ft.TVDSS) Bottom of window 10359 ft.MD (8252.4 ft.TVDSS) (12) The interval from 13077 ft. to 13107 ft. MD (8750.8 ft. to 8750.3 ft. TVDSS) was not logged due to sensor bit offset. (13) The resistivity interval from 10335 ft. to 10470 ft. MD (8232.ft to 8339.7 ft. TVDSS) was ream logged in the same run 6 hrs. after drilling. (14) USMPR 10299480 was used from 11424 ft. MD (8762 ft. TVDSS) to TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m ohm.m ohm.m ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, TVD -> True Vertical Depth (Subsea) TVD -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 10323.6, 10323, ! -0.62207 10351.9, 10352.7, ! 0.829102 10365.6, 10364.5, ! -1.03613 10433.7, 10433.5, ! -0.208008 10438.1, 10437.6, ! -0.414062 10445.3, 10444.9, ! -0.415039 10461.9, 10461.9, ! 0 10484.3, 10483.7, ! -0.62207 10544.6, 10544.2, ! -0.415039 10548.2, 10547.5, ! -0.621094 10768.6, 10768.4, ! -0.207031 10781.1, 10780, ! -1.03613 10810.1, 10809.9, ! -0.207031 10816.5, 10816.9, ! 0.414062 10862.8, 10862.4, ! -0.415039 10919, 10917.7, ! -1.24316 11027.1, 11025.9, ! -1.24316 11066.3, 11065.9, ! -0.415039 11085, 1 1083.7, ! -1.24316 11126.6, 11128.1, ! 1.45117 11203.6, 11204, ! 0.414062 11784.4, 11782.4, ! -2.07324 11813.1, 11810.4, ! -2.69531 11848.9, 11844.6, ! -4.35254 12023, 12018.6, ! -4.35352 12026.9, 12021.5, ! -5.38965 12040.6, 12034, ! -6.63379 12199.5, 12197.2, ! -2.28027 12219.7, 12218.7, ! -1.03711 12282.5, 12281, ! -1.45117 12291.2, 12289.1, ! -2.07227 12388.3, 12385.4, ! -2.90234 12558, 12556.1, ! -1.86523 12627.4, 12630.1, ! 2.69434 12816.5, 12812.7, ! -3.73145 12873.2, 12872, ! -1.24316 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 122 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 05 13b_5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 05-13B APIN 500292025002 FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Schlumberger GR CNL dated 31 Jan 2008 per Mike McTeague with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX ROP ROP ROPA RAD RAD RACLX RAS RAS RACHX RPD RPD RPCLX RPS RPS RPCHX * 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-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 215 0.0 0.0 0.0 0.0 0.0 0.0 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9240.000000 Tape File End Depth = 13107.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 228 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------ WDFN 05 13b.xtf LCC 150 CN BP Exploration (Alaska) WN 05-13B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!~~!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw unedited field data. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ---------------- CNAM ----- ODEP GR -- GR ---- --- GRAX ----------------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * 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: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 315 Tape File Start Depth = 10276.750000 Tape File End Depth = 13107.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 328 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/01/30 1783798 O1 **** REEL TRAILER **** MWD 08/10/27 BHI Ol Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes r~ Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9240.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9240.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 -999.2500 -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 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9800.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9900.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 54.3000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 287.9000 20.4000 2000.0000 2000.0000 191.2'700 171.3900 10500.0000 43.1000 26.5000 2000.0000 2000.0000 555.3270 346.2530 10600.0000 26.4000 37.9000 2000.0000 2000.0000 2000.0000 665.1100 10700.0000 31.1000 32.7000 2000.0000 2000.0000 1765.0100 485.4060 10800.0000 49.3000 41.9000 548.5900 31,8480 32.4070 34.2000 10900.0000 26.4000 102.0000 2000.0000 2000.0000 1145.1399 559.6339 11000.0000 57.7000 37.7000 2000.0000 2000.0000 265.8000 168.5830 11100.0000 112.1000 61.3000 2000.0000 2000.0000 145.3850 159.8730 11200.0000 48.4000 108.0000 108.2770 100.6510 11300.0000 59.6000 83.1000 291.6670 229.0180 11400.0000 65.7000 114.8000 182.8570 144.6900 11500.0000 55.2000 100.6000 154.2460 126.7950 11600.0000 64.2000 91.6000 132.5170 112.0910 11700.0000 62.5000 92.8000 172.8190 138.6310 11800.0000 79.3000 62.1000 120.9710 90.2630 11900.0000 72.4000 57.1000 120.9710 100.1450 12000.0000 48.9000 103.6000 292.0520 247.1820 12100.0000 57.1000 125.0000 115.8730 94.5520 12200.0000 104.8000 130.1000 163.0370 169.3190 12300.0000 63.4000 146.9000 163.0370 145.3190 12400.0000 36.0000 123.5000 8.0140 5.9500 12500.0000 42.2000 148.4000 163.0370 189.6700 12600.0000 43.4000 102.6000 126.5000 107.8410 12700.0000 109.0000 68.7000 139.0910 121.5310 12800.0000 72.7000 156.7000 102.7230 81.9560 12900.0000 37.3000 139.6000 4.3900 2.8700 13000.0000 37.9000 120.5000 12.1510 8.7270 13100.0000 -999.2500 50.2000 -999.2500 -999.2500 13107.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9240.000000 • 2000.0000 2000.0000 2000.0000 44.3130 46.3120 48.9250 55.8540 44.7450 50.1450 48.4910 39.8230 43.6890 15.2760 35.8500 39.3320 50.6090 44.3130 10.6000 24.0880 -999.2500 -999.2500 2000.0000 2000.0000 2000.0000 2000.0000 443.1690 2000.0000 2000.0000 266.9410 2000.0000 289.6120 448.7880 2000.0000 9.6980 148.2310 134.0630 2000.0000 2000.0000 5.2280 16.8290 -999.2500 -999.2500 ~1 U Tape File End Depth = 13107.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10276.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10277.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 54.3000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 287.9000 20.4000 2179.3999 6064.5400 191.2700 171.3900 10500.0000 43.1000 26.5000 2179.3999 6064.5400 555.3270 346.2530 10600.0000 26.4000 37.9000 2179.3999 6064.5400 2892.8398 665.1100 10700.0000 31.1000 32.7000 2179.3999 6064.5400 1765.0100 485.4060 10800.0000 49.3000 41.9000 548.5900 31.8480 32.4070 34.2000 10900.0000 26.4000 102.0000 2179.3999 6064.5400 1145.1399 559.6339 11000.0000 57.7000 37.7000 2179.3999 6064.5400 265.8000 168.5830 11100.0000 112.1000 61.3000 2179.3999 6064.5400 145.3850 159.8'730 11200.0000 48.4000 108.0000 2179.3999 6064.5400 108.2770 100.6510 11300.0000 59.6000 83.1000 2179.3999 6064.5400 291.6670 229.0180 11400.0000 65.7000 114.8000 2179.3999 6064.5400 182.8570 144.6900 11500.0000 55.2000 100.6000 44.3130 6064.5400 154.2460 126.7950 11600.0000 64.2000 91.6000 46.3120 443.1690 132.5170 112.0910 11700.0000 62.5000 92.8000 48.9250 6064.5400 172.8190 138.6310 11800.0000 '79.3000 62.1000 55.8540 6064.5400 120.9710 90.2630 11900.0000 72.4000 57.1000 44.7450 266.9410 120.9710 100.1450 12000.0000 48.9000 103.6000 50.1450 6064.5400 292.0520 247.1820 12100.0000 57.1000 125.0000 48.4910 289.6120 • 115.8730 94.5520 12200.0000 104.8000 130.1000 163.0370 169.3190 12300.0000 63.4000 146.9000 163.0370 145.3190 12400.0000 36.0000 123.5000 8.0140 5.9500 12500.0000 42.2000 148.4000 163.0370 189.6700 12600.0000 43.4000 102.6000 126.5000 107.8410 12700.0000 109.0000 68.7000 139.0910 121.5310 12800.0000 72.7000 156.7000 102.7230 81.9560 12900.0000 37.3000 139.6000 4.3900 2.8700 13000.0000 37.9000 120.5000 12.1510 8.7270 13100.0000 -999.2500 50.2000 -999.2500 -999.2500 13107.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10276.750000 Tape File End Depth = 13107.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • 39.8230 43.6890 15.2760 35.8500 39.3320 50.6090 44.3130 10.6000 24.0880 -999.2500 -999.2500 448.7880 6064.5400 9.6980 148.2310 134.0630 6064.5400 2459.7900 5.2280 16.8290 -999.2500 -999.2500 • ~~ Tape Subfile 4 is type: LIS • • **** REEL HEADER **** MWD 08/11/25 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/01/30 1783798 O1 3.0" 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. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 10278.0000: Starting Depth STOP.FT 13107.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 05-13B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 15' 55.184"N 148 deg 24' 20.265"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 30 Jan 2008 API API NUMBER: 500292025002 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 32 TOWN.N T11N RANG. R15E PDAT. MSL EPD .F 0 LMF DF FAPD.F 62.46 DMF DF EKB .F 0 EDF .F 62.46 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) (3) (4) (5) Advantage i All depths are Bit Depths unless All True Vertical Depths (TVDSS) All Formation Evaluation data is Baker Hughes INTEQ utilized Coil otherwise noted. are Subsea corrected. realtime data. Prak downhole tools and the 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 has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL per the request of Priya Maraj with BP Exploration (Alaska), Inc. (8) Tied to 05-13A at 10346 feet MD (8241.6 feet TVDSS). (9) The sidetrack was drilled from 05-13A through a milled window in a 7 inch liner. Top of window 10351.5 ft.MD (8246.2 ft.TVDSS) Bottom of window 10359.0 ft.MD (8252.4 ft.TVDSS) (10) Baker Hughes INTEQ runs 1 and 2 were used to set whipstock top at 10347 ft. MD (8242 ft TVDSS) and mill window. (11) The interval from 13077 feet to 13107 feet MD (8750.8 feet to 8750.3 feet TVDSS) was not logged due to sensor to bit offset at well TD. (12) The resistivity interval form 10335 ft to 10470 ft MD (8232.5 ft to 8339.7 ft TVDSS) was ream logged in the same run 6 hours after drilling. (13) USMPR 10299480 was used from 11424 ft MD (8762 ft TVDSS) to TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour ' RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10283.2, 10281.9, ! -1.24316 10286.9, 10285.7, ! -1.24316 10294.6, 10295, ! 0.415039 10301.6, 10301.2, ! -0.414062 10309.1, 10303.5, ! -0.62207 10306.6, 10306.6, ! 0 10312.4, 10311.6, ! -0.829102 10315.7, 10315.1, ! -0.62207 10321.1, 10320.7, ! -0.415039 10323.6, 10322.8, ! -0.829102 10333.7, 10334.3, ! 0.62207 10338.5, 10338, ! -0.414062 10342.2, 10341.8, ! -0.414062 10352.1, 10351.9, ! -0.207031 10355, 10354.4, ! -0.62207 10357.1, 10356.1, ! -1.03711 10359, 10358.2, ! -0.829102 10365.3, 10364.3, ! -1.03613 10369.2, 10367.8, ! -1.45117 10372.3, 10371.1, ! -1.24316 10374.4, 10374, ! -0.415039 10378.8, 10376.7, ! -2.07324 10382.1, 10381.1, ! -1.03613 10383.5, 10382.9, ! -0.62207 10385.2, 10385.2, ! 0 10386.2, 10386.4, ! 0.208008 10394.7, 10392.7, ! -2.07227 10397.4, 10396.8, ! -0.62207 10402.2, 10402, ! -0.207031 10404.1, 10403.6, ! -0.415039 10405.5, 10405.5, ! 0 10407, 1 0406.5, ! -0.414062 10409.7, 10409.2, ! -0.415039 10412.4, 10412.1, ! -0.208008 10413.6, 10413.4, ! -0.207031 10415.7, 10415.5, ! -0.207031 10420.5, 10419.9, ! -0.62207 10421.8, 10421.8, ! 0 10428, 10427.8, ! -0.207031 10431.3, 10430.7, ! -0.62207 10433.8, 10433.4, ! -0.414062 10435.5, 10435, ! -0.414062 10437.7, 10437.3, ! -0.414062 10440, 10440.6, ! 0.62207 10442.9, 10442.9, ! 0 10445.6, 10445.2, ! -0.415039 10452.7, 10451.4, ! -1.24414 10462.2, 10462.4, ! 0.207031 10480, 10479.4, ! -0.62207 10484.4, 10483.8, ! -0.62207 10486.7, 10485.6, ! -1.03613 10490.5, 10490.7, ! 0.207031 10495.7, 10494.9, ! -0.829102 10504.6, 10504.2, ! -0.414062 10508.6, 10507.5, ! -1.03613 10517.5, 10516.2, ! -1.24414 10521.4, 10520.6, ! -0.829102 10523.5, 10522.9, ! -0.62207 10529.9, 10530.5, ! 0.62207 10533.4, 10533.2, ! -0.207031 10536.8, 10536.5, ! -0.207031 10541.5, 10539.2, ! -2.28027 10544.4, 10544.4, ! 0 10546.3, 10545.9, ! -0.414062 10548.1, 10547.5, ! -0.62207 10550.4, 10550.6, ! 0.207031 10552.5, 10551.9, ! -0.621094 10560.6, 10560.8, ! 0.207031 10568.3, 10569.1, ! 0.829102 10571.8, 10571.2, ! -0.62207 10578.8, 10577.8, ! -1.03613 10581.7, 10581.9, ! 0.207031 10588.6, 10588.2, ! -0.415039 10597.9, 10597.1, ! -0.829102 10602.7, 10604.2, ! 1.45117 10607.5, 10608.9, ! 1.45117 10617, 10616.2, ! -0.829102 10627.9, 10626.8, ! -1.03711 10652.1, 10651.3, ! -0.830078 10657.1, 10655.9, ! -1.24414 10664.1, 10664.1, ! 0 10692, 10691.2, ! -0.829102 10695.7, 10694.9, ! -0.829102 10699.1, 10698.9, ! -0.207031 10707.8, 10707.8, ! 0 10713.6, 10712.3, ! -1.24316 10723.9, 10724.1, ! 0.207031 10759.5, 10758.3, ! -1.24414 10768.6, 10768.2, ! -0.415039 10771.8, 10771.3, ! -0.415039 C~ 10775.7, 10775.1, 10778.6, 10777.4, 10781.1, 10780, 10782.3, 10782.7, 10785.2, 10785, 10792.9, 10792.5, 10795, 10794.6, 10797.1, 10796.3, 10798.1, 10797.3, 10802.3, 10801.9, 10804.1, 10803.9, 10806, 10805.6, 10807.9, 10807.7, 10809.9, 10809.7, 10813.7, 10813.5, 10815.3, 10815.7, 10816.4, 10817, 10822.8, 10822.2, 10825.9, 10824.5, 10829.2, 10826.9, 10834.8, 10834.4, 10846, 10843.9, 10858, 10856.6, 10859.5, 10858.6, 10862.4, 10862.4, 10865.9, 10864.7, 10868.8, 10868.6, 10871.7, 10871.1, 10875.6, 10875, 10877.9, 10878.1, 10880.8, 10881.7, 10889.1, 10888.3, 10894.3, 10894.1, 10905.6, 10905.2, 10916.2, 10915.5, 10918.9, 10917.8, 10921.3, 10920.3, 10923.8, 10922.6, 10928.6, 10929, 10931.5, 10930.7, 10935.2, 10934.4, 10937.7, 10936.1, 10939.2, 10937.9, 10956.8, 10953.7, 10957.9, 10956.8, 10961.4, 10960.6, 10968.2, 10967, 10969.9, 10970.7, 10975.1, 10973.4, 10978.6, 10977.6, 10990.2, 10989.4, 10992.9, 10991.7, 10999.3, 11002.2, 11006, 11006.4, 11010.7, 11010.9, 11022.6, 11022.4, 11027.2, 11026, 11030.5, 11029.5, 11041.3, 11039.2, 11052.1, 11052.1, 11054.6, 11054.6, 11057.9, 11057.3, 11061.2, 11059.5, 11062.4, 11061.4, 11064.5, 11063.5, 11066.2, 11065.3, 11073.8, 11073.2, -0.62207 -1.24414 -1.03613 0.414062 -0.208008 -0.414062 -0.415039 -0.829102 -0.829102 -0.414062 -0.207031 -0.414062 -0.207031 -0.207031 -0.207031 0.414062 0.62207 -0.62207 -1.45117 -2.28027 -0.415039 -2.07227 -1.45117 -0.829102 0 -1.24316 -0.207031 -0.62207 -0.62207 0.207031 0.829102 -0.829102 -0.208008 -0.415039 -0.62207 -1.03613 -1.03613 -1.24414 0.414062 -0.829102 -0.830078 -1.6582 -1.24414 -3.10938 -1.03711 -0.829102 -1.24316 0.829102 -1.6582 -1.03613 -0.829102 -1.24414 2.90234 0.414062 0.207031 -0.207031 -1.24414 -1.03613 -2.07227 0 0 -0.62207 -1.6582 -1.03613 -1.03711 -0.829102 -0.62207 • • 11079.6, 11078.3, 11081.9, 11080.4, 11085.2, 11084.1, 11090.1, 11088.7, 11094.5, 11091.8, 11096.6, 11094.1, 11102.4, 11100.9, 11104.2, 11103.4, 11106.7, 11105.7, 11117.7, 11117.7, 11119, 11119.4, , 11123.5, 11122.9, 11126.4, 11128.1, 11131.2, 11132.6, 11135.1, 11134.9, 11147.5, 11145.2, 11154.9, 11151.8, 11157.8, 11156.2, 11177.5, 11174.8, 11184.6, 11182.9, 11195.3, 11194.5, 11197.4, 11197, 11199.2, 11198.8, 11203.6, 11204, 11208.5, 11207.3, 11212.9, 11211, 11249.6, 11246.3, 11273.1, 11276.8, 11285.7, 11287.8, 11288, 11291.8, 11326.2, 11324.9, 11346.9, 11346.1, 11377.7, 11374.8, 11408.3, 11406.3, 11416.2, 11414.1, 11467.3, 11468.5, 11665.5, 11663, 11672.6, 11669.6, 11675, 11672.1, 11678.4, 11675.7, 11684.4, 11681, 11686.4, 11682.9, 11699.5, 11695.6, 11701, 11697, 11703, 11700.1, 11706.3, 11702.6, 11724.5, 11723.2, 11727, 11724.9, 11731.1, 11729, 11735.2, 11731.9, 11748.3, 11747.3, 11757.4, 11755.4, 11759.5, 11757.2, 11777.8, 11775.3, 11781.3, 11779.4, 11784.4, 11782.6, 11788.8, 11786.7, 11792.3, 11789.6, 11813.2, 11810.5, 11834.6, 11832.3, 11841.6, 11839.5, 11852.6, 11847.2, 11859.9, 11857.6, 11866.9, 11866.3, 11882.6, 11880.3, 11920.5, 11920.3, 11936.9, 11936.2, ! -1.24414 ! -1.45117 ! -1.03613 ! -1.45117 ! -2.69434 ! -2.4873 ! -1.45117 ! -0.829102 ! -1.03613 ! 0 ! 0.415039 ! -0.621094 ! 1.6582 ! 1.45117 ! -0.208008 ! -2.28027 ! -3.10938 ! -1.6582 ! -2.69531 ! -1.6582 ! -0.829102 ! -0.415039 ! -0.414062 ! 0.415039 ! -1.24414 ! -1.86523 ! -3.31641 ! 3.73047 ! 2.07324 ! 3.73145 ! -1.24414 ! -0.829102 ! -2.90234 ! -2.07324 ! -2.07324 ! 1.24414 ! -2.4873 ! -2.90234 ! -2.90234 ! -2.69434 ! -3.31641 ! -3.52441 ! -3.93848 -3.93848 ! -2.90234 ! -3.73145 ! -1.24414 ! -2.07227 ! -2.07324 ! -3.31641 ! -1.03613 ! -2.07227 ! -2.28027 ! -2.4873 ! -1.86523 ! -1.86523 ! -2.07324 ! -2.69434 ! -2.69531 ! -2.28027 ! -2.07324 ! -5.38965 ! -2.2793 ! -0.62207 ! -2.28027 ! -0.207031 ! -0.621094 11950.7, 11949.3, ! -1.45117 11956.7, 11955.7, ! -1.03613 11972.7, 11967.9, ! -4.76758 11977.5, 11973.3, ! -4.14551 11983.7, 11977.9, ! -5.80371 11997.4, 11992.4, ! -4.97461 11999.9, 11996.3, ! -3.52344 12012.7, 12006.4, ! -6.21875 12019.3, 12012, ! -7.25488 12023.2, 12014.7, ! -8.49902 12025.1, 12016.8, ! -8.29199 12027, 12021.4, ! -5.59668 12028.6, 12023.6, ! -4.97559 12029.4, 12025.1, ! -4.35352 12037.7, 12031.9, ! -5.80371 12040.4, 12033.6, ! -6.84082 12047.1, 12045, ! -2.07324 12060.1, 12056.4, ! -3.73145 12074.6, 12069, ! -5.59766 12101.1, 12099.4, ! -1.6582 12111.5, 12107.7, ! -3.73145 12121.6, 12115.8, ! -5.80469 12128, 12120.8, ! -7.25488 12163.3, 12159.1, ! -4.14648 12173.4, 12169.9, ! -3.52441 12175.9, 12172, ! -3.93848 12180.6, 12178.5, ! -2.07227 12185.6, 12183.5, ! -2.07324 12189.1, 12187, ! -2.07227 12191.6, 12191.8, ! 0.207031 12195.5, 12194.5, ! -1.03711 12198.8, 12197.4, ! -1.45117 12204.8, 12202.4, ! -2.4873 12214.1, 12212, ! -2.07324 12217.4, 12216.4, ! -1.03613 12223.4, 12221.1, ! -2.28027 12230.3, 12225.5, ! -4.76855 12233.2, 12228.4, ! -4.76758 12262.2, 12260.1, ! -2.07324 12268, 12266.5, ! -1.45117 12276.9, 12274.8, ! -2.07227 12282.3, 12280.4, ! -1.86523 12286.9, 12284.6, ! -2.28027 12291.1, 12289.3, ! -1.86621 12294.5, 12292.2, ! -2.28027 12298, 12295.5, ! -2.48828 12364.1, 12359.3, ! -4.76855 12369.9, 12365.1, ! -4.76758 12384.4, 12381.9, ! -2.4873 12388.5, 12385.2, ! -3.31738 12431.7, 12429.9, ! -1.86621 12435.5, 12433.8, ! -1.6582 12445, 12439.8, ! -5.18262 12447.1, 12441.7, ! -5.38965 12449.5, 12445, ! -4.56055 12451.6, 12446.9, ! -4.76855 12454.3, 12449.8, ! -4.56055 12457.2, 12452.7, ! -4.56055 12460.5, 12456, ! -4.56055 12535.7, 12533.6, ! -2.07324 12549.8, 12547.5, ! -2.28027 12558.7, 12556.2, ! -2.4873 12564.9, 12563.3, ! -1.6582 12572.2, 12568.7, ! -3.52344 12575.1, 12572.6, ! -2.4873 12578.6, 12576.1, ! -2.4873 12588, 12583.9, ! -4.14648 12594.9, 12592.4, ! -2.48828 12618.3, 12619.3, ! 1.03711 12624.1, 12624.7, ! 0.621094 12633.8, 12633.8, ! 0 12640.7, 12640.9, ! 0.208008 12645.9, 12644, ! -1.86523 12691.6, 12693.4, ! 1.86621 12738.6, 12741.3, ! 2.69434 12745.8, 12748.5, ! 2.69531 12751.2, 12752.9, ! 1.6582 12754.1, 12756, ! 1.86523 12764.3, 12764.9, ! 0.62207 12767.8, 12769, ! 1.24316 12776.4, 12773.9, ! -2.48828 12778.5, 12776.2, ! -2.28027 12781.1, 12779.1, ! -2.07324 12783.4, 12783, ! -0.415039 12785.9, 12786.1, ! 0.207031 12788.8, 12787.8, ! -1.03711 12800, 12798.6, ! -1.4502 12804.6, 12803.1, ! -1.4502 12808.9, 12805.6, ! -3.31641 12814.5, 12810.6, ! -3.93848 12816.4, 12812.9, ! -3.52441 12821, 12817.6, ! -3.31738 12829.7, 12830.7, ! 1.03613 12835.7, 12836.3, ! 0.62207 12844.2, 12844.8, ! 0.62207 12854.2, 12854.2, ! 0 12861.6, 12861.4, ! -0.208008 12870.1, 12869.3, ! -0.829102 12873.6, 12872.4, ! -1.24316 12876.5, 12874.7, ! -1.86523 12877.8, 12876.8, ! -1.03711 12888.7, 12889.8, ! 1.03613 12894.3, 12893.3, ! -1.03613 12900.3, 12899.7, ! -0.62207 12918.7, 12918.5, ! -0.208008 12921.8, 12920.9, ! -0.830078 12931.9, 12929.6, ! -2.28027 12937.7, 12933.8, ! -3.93848 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 411 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 05-13B 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 05-13B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!'~ " " !'!!! Remark File Version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary D log provided by Schlumberger GR CNL per the request of Priya Maraj with BP Explo *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT -------------- CNAM ODEP GR ---- GR ------------ GRAX ----------------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * 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-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 158 Tape File Start Depth = 10278.000000 Tape File End Depth = 13107.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet r: **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .002 1024 171 records... 54 bytes 4124 bytes • *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 05-13B.xtf LCC 150 CN BP Exploration (Alaska) WN 05-13B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * 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: 315 Tape File Start Depth = 10278.000000 Tape File End Depth = 13107.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 328 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/01/30 1783798 O1 **** REEL TRAILER **** MWD 08/11/25 BHI 01 • 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 ROP RAD RAS RPD RPS 10278.0000 84.6346 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10278.5000 84.0751 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 54.8381 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 287.9000 21.2500 2000.0000 2000.0000 201.7121 176.2076 10500.0000 47.9506 28.7914 2000.0000 2000.0000 624.1511 349.2916 10600.0000 25.9829 38.0390 2000.0000 2000.0000 2000.0000 651.0858 10700.0000 30.4016 32.6302 2000.0000 2000.0000 1765.0100 485.4060 10800.0000 40.8573 31.6796 386.1013 34.7892 37.0929 42.1391 10900.0000 25.4205 103.1631 2000.0000 2000.0000 1145.1399 514.1934 11000.0000 45.8329 35.1329 2000.0000 2000.0000 265.8000 174.4609 11100.0000 73.9194 64.8530 2000.0000 2000.0000 141.8151 154.9712 11200.0000 50.5126 108.4743 2000.0000 2000.0000 109.1600 101.8444 11300.0000 66.9478 81.4105 2000.0000 2000.0000 320.5721 244.8427 11400.0000 64.7038 105.3766 2000.0000 2000.0000 184.8414 144.6900 11500.0000 53.4991 90.5428 47.4701 2000.0000 154.2460 126.7950 11600.0000 63.4794 88.9956 46.3120 481.6462 132.5170 107.8410 11700.0000 64.8915 104.8730 48.7359 2000.0000 172.8190 138.6310 11800.0000 64.8586 47.6195 53.4024 2000.0000 157.7658 116.6420 11900.0000 74.6881 42.4958 45.0092 297.8784 118.2616 96.6500 12000.0000 37.6007 106.1146 48.3816 2000.0000 262.5040 219.9530 12100.0000 60.1875 124.2173 47.7481 334.0565 119.4515 96.6500 12200.0000 95.6617 121.6356 172.8190 174.7610 12300.0000 69.3462 97.2385 168.7737 149.5906 12400.0000 38.6670 124.1575 9.2283 7.3049 12500.0000 40.5489 92.5442 171.7515 189.6700 12600.0000 49.5665 104.2089 132.5170 112.0910 12700.0000 111.1355 65.6656 139.0910 116.6420 12800.0000 73.0041 143.2436 89.3903 73.3560 12900.0000 36.8068 139.3424 4.4298 2.8925 13000.0000 42.0012 112.9391 12.8430 9.1380 13100.0000 -999.2500 81.6766 -999.2500 -999.2500 13107.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10278.000000 Tape File End Depth = 13107.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • 39.8230 356.7717 43.4076 2000.0000 15.6624 10.7263 36.8172 150.4440 39.3320 135.0168 48.3691 2000.0000 43.6890 399.2288 10.8378 5.3054 25.7541 17.9693 -999.2500 -999.2500 -999.2500 -999.2500 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10278.0000 88.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10278.2500 87.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 54.3000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 287.9000 20.4000 2179.3999 6064.5400 191.2700 171.3900 10500.0000 43.1000 26.5000 2179.3999 6064.5400 555.3270 346.2530 10600.0000 26.4000 37.9000 2179.3999 6064.5400 2892.8398 665.1100 10700.0000 31.1000 32.7000 2179.3999 6064.5400 1765.0100 485.4060 10800.0000 49.3000 41.9000 548.5900 31.8480 32.4070 34.2000 10900.0000 26.4000 102.0000 2179.3999 6064.5400 1145.1399 559.6339 11000.0000 57.7000 37.7000 2179.3999 6064.5400 265.8000 168.5830 11100.0000 112.1000 61.3000 2179.3999 6064.5400 145.3850 159.8730 11200.0000 48.4000 108.0000 2179.3999 6064.5400 108.2770 100.6510 11300.0000 59.6000 83.1000 2179.3999 6064.5400 291.6670 229.0180 11400.0000 65.7000 114.8000 2179.3999 6064.5400 182.8570 144.6900 11500.0000 55.2000 100.6000 44.3130 6064.5400 154.2460 126.7950 11600.0000 64.2000 91.6000 46.3120 443.1690 132.5170 112.0910 11700.0000 62.5000 92.8000 48.9250 6064.5400 172.8190 138.6310 11800.0000 79.3000 62.1000 55.8540 6064.5400 120.9710 90.2630 11900.0000 72.4000 57.1000 44.7450 266.9410 120.9710 100.1450 12000.0000 48.9000 103.6000 50.1450 6064.5400 292.0520 247.1820 12100.0000 57.1000 125.0000 48.4910 289.6120 115.8730 94.5520 12200.0000 104.8000 130.1000 163.0370 169.3190 12300.0000 63.4000 146.9000 163.0370 145.3190 12400.0000 36.0000 123.5000 8.0140 5.9500 12500.0000 42.2000 148.4000 163.0370 189.6700 12600.0000 43.4000 102.6000 126.5000 107.8410 12700.0000 109.0000 68.7000 139.0910 121.5310 12800.0000 72.7000 156.7000 102.7230 81.9560 12900.0000 37.3000 139.6000 4.3900 2.8700 13000.0000 37.9000 120.5000 12.1510 8.7270 13100.0000 -999.2500 50.2000 -999.2500 -999.2500 13107.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10278.000000 Tape File End Depth = 13107.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 39.8230 448.7880 43.6890 6064.5400 15.2760 9.6980 35.8500 148.2310 39.3320 134.0630 50.6090 6064.5400 44.3130 2459.7900 10.6000 5.2280 24.0880 16.8290 -999.2500 -999.2500 -999.2500 -999.2500 Tape Subfile 4 is type: LIS
