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209-055
Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2024.12.16 12:33:28 - 09'00' Sean McLaughlin (4311) By Grace Christianson at 1:36 pm, Dec 16, 2024 See emails about the WS below. -WCB WCB 2-12-2025 RBDMS JSB 122624 DSR-12/16/24 ACTIVITYDATE SUMMARY 10/6/2024 ***WELL S/I ON ARRIVAL*** (Sidetrack) RAN 4-1/2" BRUSH & 3.80" GAUGE RING TO 11,900' SLM SET 4-1/2" X-CATCHER AT 11,757' MD PULLED BK-OGLV FROM STA #3 AT 11,637' MD PULLED BK-LGLV FROM STA #2 AT 7,738' MD PULLED BK-LGLV FROM STA #1 AT 3,720' MD SET BK-DGLV IN STA #1 AT 3,720' MD SET BK-DGLV IN STA #2 AT 7,738' MD PULLED 4-1/2" X-CATCHER AT 11,757' MD RAN 20' x 3.70" DUMMY WHIPSTOCK TO RESTRICTION AT 12,359' SLM (sticky) RAN 2.78" CENT & 10' x 2.50" DRIVE DOWN BAILER TO DEVIATION AT 12,854' SLM (all clear - bailer empty) ***CONTINUE ON 10/7/24 WSR*** 10/7/2024 ***CONTINUED FROM 10/6/24 WSR*** (Sidetrack) RAN 3.78" SWAGE & 10' x 2.50" BAILER TO RESTRICTION AT 12,365' SLM & WORK DOWN TO 12,367' SLM (unable to get further -tools stick) RAN 3.69" CENT, KJ & 10' x 2.50" BAILER TO RESTRICTION AT 12,369' SLM (unable to get further - tools stick) SET 4-1/2" X-CATCHER AT 11,822' MD SET BK-DGLV IN STA #3 AT 11,637' MD SET 4-1/2" PX PLUG IN X-NIP AT 11,822' MD LRS PERFORMED PASSING MI-T TO 3070 psi PULLED P-PRONG AT 11,822' MD ***CONTINUE ON 10/8/24 WSR*** 10/7/2024 T/I/O = 2378/2145/30 - LRS 46 - (SIDETRACK) Assist SL: Loaded IA with 385 bbls of Crude. Loaded TB with 215 bbls of Crude. Performed MIT-T to 3250 psi, see log. ***Job Continued to 10-08-2024*** 10/8/2024 ***CONTINUED FROM 10/7/24 WSR*** (Sidetrack) PULLED 4-1/2" PX PLUG BODY AT 11,822' MD RAN 3.25" CENT & 10' x 2.50" BAILER TO DEVIATION AT 12,874' SLM (LRS pumped 50 bbls at 5 bpm - unable to get further) RAN 3.50" CENT & 10' x 2.50" BAILER TO RESTRICTION AT 12,368' SLM (unable to get further) RAN HES 40 ARM CALIPER FROM 12,869' SLM TO 10,969' SLM ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 10/8/2024 ***Continue Job from 10-08-2024*** Assist Slickline (SIDETRACK) Pumped 108 bbls Crude into TBG to assist SL w/ drift. SL in control of well upon departure. FWHPs= 530/100/40 10/9/2024 T/I/O= 2048/0/19. LRS 72 Assist E-Line (SIDETRACK). Load the TBG with 180 bbls of crude at 5 bpm. Final WHP's 532/198/31 E line on well at departure 10/9/2024 *** WELL SI ON ARRIVAL*** (HOIST GYRO) PT. 300 LOW AND 3000PSI HIGH. STOPPED FALLING AT 12460' AND HAD OVERPULL UP TO 12400'. LOG GYRODATA FROM 12400FT TO SURFACE. ***JOB COMPLETE*** Daily Report of Well Operations PBU 18-29C RAN 20' x 3.70" DUMMY WHIPSTOCK TO RESTRICTION AT Daily Report of Well Operations PBU 18-29C 10/14/2024 T/I/O=0/0/0. Pre CTD. Installed Kill line #5 on tree companion and 4 x7"XO w/ tapped blind on SV. Torqued flanges to Spec. PT'd upper tree against SSV to 300/5000 psi. (Pass), Install swab platform.***Job Complete*** Final WHP's 0/0/0. 1 Christianson, Grace K (OGC) From:Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent:Friday, November 22, 2024 1:27 PM To:Joseph Lastufka Subject:PBU 18-29C (PTD #209-055) Sundry #324-267 Request for Extension Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, November 22, 2024 1:25 PM To: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: [EXTERNAL] RE: PBU 18-29C (PTD #209-055) Sundry #324-267 Request for Extension Joe, Extension approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent: Friday, November 22, 2024 10:49 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PBU 18-29C (PTD #209-055) Sundry #324-267 Request for Extension Mel, CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Due to the 2nd setting of the whipstock on 18-29CL1 (PTD #224-099), I’d like to request an extension to submit the 10-404 to close out sundry #324-267 (Set Whipstock for Lateral). The Ʊrst milling of the window was 10/29/24, however, with the second whipstock being set and milled today sometime, I’d like to wait until post TD / running of liner and cementing to close out sundry #324-267 for PBU 18-29C in the oƯ chance another whipstock may be needed. Please let me know if you have any questions and thanks for all of your eƯorts. Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any d issemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 11/18/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well Name PTD Number API Number AOGCC ESET # 18-29 192-133 50-029-22316-00-00 18-29A 193-040 50-029-22316-01-00 18-29B 198-069 50-029-22316-02-00 18-29BPB1 198-069 50-029-22316-70-00 18-29C 209-055 50-029-22316-03-00 Definitive Directional Surveys (Composited) - Gyrodata Re-Survey 10/09/2024 Main Folder Contents: Please include current contact information if different from above. T39784 T39785 T39786 T39787 T3978818-29C 209-055 50-029-22316-03- Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.19 08:39:28 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 18-29C JBR 12/17/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 2-3/8: and 3-1/8" TJ. Accumualator bottles 16 @ 1043 psi. Fail on C2 Greased and cycled and retest passed. Test Results TEST DATA Rig Rep:Wheeler/FletcherOperator:Hilcorp North Slope, LLC Operator Rep:Burrnett/Scarpella Rig Owner/Rig No.:Nabors CDR2AC PTD#:2090550 DATE:10/23/2024 Type Operation:WRKOV Annular: 250/5000Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopKPS241023103116 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8 MASP: 2460 Sundry No: 324-267 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2-3/8"P Annular Preventer 1 7-1/16"P #1 Rams 1 Blind Shears P #2 Rams 1 2-3/8" Pipe sli P #3 Rams 1 3-1/8" Pipe Sl P #4 Rams 1 2-3/8" Pipe sli P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 2 2-1/16"P Kill Line Valves 2 2-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2300 200 PSI Attained P19 Full Pressure Attained P48 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10 @ 2075 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 P Annular Preventer P7 #1 Rams P2 #2 Rams P2 #3 Rams P2 #4 Rams P1 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 99999 9 9 9 9 9 9 Fail on C2 FP Drilling Manager 05/03/24 Monty M Myers By Grace Christianson at 12:46 pm, May 03, 2024 SFD 5/3/2024 10-404 DSR-5/6/24MGR06MAY24 * BOPE test to 3500 psi. JLC 5/16/2024 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: May 2, 2024 Re:PBU 18-29C Sundry Request Sundry approval is requested to set a whipstock and mill the window in 18-29C, as part of the pre-rig and drilling/completing of the proposed 18-29C L1 CTD lateral. Proposed plan for PBU 18-29C L1 Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. See 18-29C L1 PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation in the 4-1/2" liner. The well will kick off drilling in the Ivishak Zone 1. The lateral will continue in Zone 1 to TD. The proposed sidetrack will be completed with a 3-1/2"x3- 1/4"x2-7/8 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 Ivishak perfs, but leave the upper Sag perfs open. This Sundry covers plugging the existing Ivishak 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 June): 1. Coil: 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. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: Reference PBU 18-29C L1 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. Set Packer Whipstock 3. Mill Window 4. Drill Production Lateral 5. Run and Cement Liner* 6. Freeze Protect and RDMO 7. Set LTP* and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 PTD , p y p p g ( p g completion will completely isolate and abandon the parent Ivishak perfs, but leave thep g) upper Sag perfs open. Sundry 324-267 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/19/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230719 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 07-20C 50029209020300 218036 6/8/2023 HALLIBURTON RBT PBU 13-19 50029206900000 181180 6/8/232 HALLIBURTON WFL-RMT3D PBU 18-29C 50029223160300 209055 6/13/2023 HALLIBURTON CAST-CBL PBU L-213 50029233080000 206053 6/12/2023 HALLIBURTON IPROF PBU M-205 50029237330000 222127 6/6/2023 HALLIBURTON IPROF PBU S-17c 50029211480300 202007 5/29/2023 HALLIBURTON RBT Please include current contact information if different from above. T37859 T37860 T37861 T37862 T37863 T37864 PBU 18-29C 50029223160300 209055 6/13/2023 HALLIBURTON CAST-CBL Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.19 13:22:09 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/10/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230422 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-26 50283200830000 212050 6/2/2023 AK E-LINE PPROF BRU 222-34 50283201860000 222039 6/14/2023 AK E-LINE Perf BRU 244-27 50283201850000 222038 6/13/2023 AK E-LINE Perf KBU 33-06X 50133205290000 203183 6/17/2023 AK E-LINE Patch Paxton 12 50133207100000 223014 6/7/2023 AK E-LINE Perf PBU 18-29C 50029223160300 209055 6/2/2023 AK E-LINE CBL Pearl 10 50133207110000 223028 6/6/2023 AK E-LINE Perf Pearl 11 50133207120000 223032 6/8/2023 AK E-LINE Perf Please include current contact information if different from above. PTD: 190-042 T37810 T37811 T37812 T37813 T37814 T37815 T37816 T37817 PBU 18-29C 50029223160300 209055 6/2/2023 AK E-LINE CBL Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.10 13:32:37 -08'00' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 18-29C CTU Extended Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-055 50-029-22316-03-00 n/a ADL 0028321 15918 Surface Intermediate Liner Liner 8702 3348 3346 8887 3643 15417 13-3/8" 9-5/8" 7" 4-1/2" 8701 28 - 3374 26 - 3374 3189 - 12076 11903 - 15546 2470 28 - 3370 26 - 3370 3187 - 8161 8011 - 8705 none 1950 4760 5410 7500 none 3450 6870 7240 8430 12115 - 15400 4-1/2" 12.6#13Cr80 24 - 119078194 - 8701 Conductor 79 20" 29 - 109 29 - 108 1530 520 4-1/2" Baker S-3 Perm Packer No SSSV Installed 11788 , 7910 No SSSV Installed Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com (907)564-4672 PRUDHOE BAY, PRUDHOE OIL 11/1/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:40 am, Oct 19, 2021 321-546 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.10.16 21:45:01 -08'00' Bo York MGR19OCT21 10-404 DSR-10/19/21 2470 , ADL 28307 SFD 10/19/2021 SFD 10/19/2021 dts 10/20/2021 JLC 10/20/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.20 11:08:48 -08'00' RBDMS HEW 10/22/2021 Extended Patch 18-29C PTD: 209-0550 Well Name:18-29C API Number:500292231603 Current Status:Shut In Rig:EL/SL & CTU Estimated Start Date:November 2021 Estimated Duration:3 days Regulatory Contact:Carrie Janowski Permit to Drill Number:209-0550 First Call Engineer:David Bjork (907) 440-0331 (c) Second Call Engineer:Ryan Thompson (907) 301-1240 (c) Current Bottom Hole Pressure:3,350 psi @ 8,800’ TVD 7.4 PPGE (offset 18-14C 12/19) Current Bottom Hole Temperature:195 degF Max. Anticipated Surface Pressure:2,470 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2,400 psi (Taken on 10/10/2021) Min ID:3.80” ID – milled out ‘XN’ Nipple @ 11,895’ MD Max Angle:94 Deg @ 13,011’ Brief Well Summary: History: July 2009 Rotary sidetrack with 1400' of Z1A perfs. Required in-situ GL perfs, shot Sag September 2010 - came at HGOR (100K+). Straddle set to control Sag gas in January 2011. After pulling the straddle in 10/21 a caliper was ran to verify the condition of the liner. A corroded section was found below the Sag perfs. Objective: The objective of this procedure is to install an extended patch over the corroded liner and to reset the Sag straddle for in-situ lift. Injection Support: There are currently no active injectors within ~4000’ of 18-29C. Eline 1. RIH w/ 4 ½” retrievable packer w/ 2.31” X nipple, set @ 12,670’ MD. Reference Read caliper log 10/09/21 Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the liner. Coiled Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Bullhead ~320 bbls of KWF, 8.4 ppg 1% KCl, seawater or equivalent down the tubing to the formation. a. Wellbore volume to top Ivishak perf = ~197 bbls 3. Perform no flow check prior to breaking lubricator at QTS connection. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of liner. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 4. MU ~340’ of 2 7/8” liner w/ 4 ½” packer on top (~2200 lbs hanging weight in air) assembly. Note that the liner will not have floats installed, a TIW valve can be stabbed and max pump rate established down the liner if needed. Once all the liner is MU, make up packer and setting tool then lower lubricator down until the QTS is MU. Pressure test the QTS prior to deployment. 5. RIH and latch into 4 ½” packer set by EL. Drop ball and set 4 ½” packer (12,330’). End of 10-403 Approval Sundry Procedure Review standing orders flowchart for operations if well begins to flow while deploying liner. Extended Patch 18-29C PTD: 209-0550 Eline 1. RIH w/ 4 ½” retrievable packer w/ 2.31” X nipple, set @ 12,130’ MD. Reference Read caliper log 10/09/21. Slickline 2. Set upper patch section(s) with 2.31 CMD sleeve and upper 4-1/2” Packer (12,091). 3. Verify the sliding sleeve is open and install an insert sleeve with (2) .188” orfices. Extended Patch 18-29C PTD: 209-0550 Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. BOPs 4. Standing Orders 5. Equipment Layout Diagram Extended Patch 18-29C PTD: 209-0550 Current Wellbore Schematic Extended Patch 18-29C PTD: 209-0550 Proposed Schematic Extended Patch 18-29C PTD: 209-0550 BOPs Extended Patch 18-29C PTD: 209-0550 Standing Orders Extended Patch 18-29C PTD: 209-0550 Equipment Layout Diagram STATE OF ALASKA RIECEPv #� ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed ��FF{{�� (f�1 CC ���f11�� Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Ode2lfdhstAfW[ PO ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well RI Re-enter Susp Well ❑ Af6�ll Ori fice 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory ❑ 5. Permit to Drill Number 209-055 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22316-03-00 1 7 Property Designation (Lease Number): ADL 028321 8, Well Name and Number: PBU 18-29C 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 15918 feet Plugs measured None feet true vertical 8702 feet Junk measured None feet Effective Depth: measured 15417 feet Packer measured 11788 feet true vertical 8701 feet Packer true vertical 7910 feet Casing: Length: Size: MD: TVD: Burst: Collapse. Structural Conductor 80 20" 29-109 29-109 1530 520 Surface 3346 13-3/8" 28-3374 28-3370 3450/4930 1950 / 2270 Intermediate 3348 9-5/8" 26-3374 26-3370 6870 4760 Liner 8687 T 3189-12076 3187-8161 7240 5410 Liner 3643 4-1/2" 11903 - 15546 8011-8705 8430 7500 Perforation Depth. Measured depth: 12115 -15400 feet True vertical depth: 8194-8701 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 24-11907 24-8014 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 11788 7910 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Md Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 487 37877 1795 0 607 Subsequent to operation: 128 39772 3336 0 703 14. Attachments:(.,u,md per20MC 25.09025071,825283) 15. Well Class after Work: Daily Report of Well Operations El Exploratory ❑ Development ® Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Authonzed Name: Oestgaard, Finn Contact Name: Oestgaard, Finn Authorized Title: Production Engineer Challenger Contact Email: Finn.OestgaardCQbp.com Authorized Signature: - Date: Z/ti 4P Contact Phone: +1 907 564 5026 Form 10-404 Revised 04/2017 �///��Z� " I"L"2o RBDMS&,J FEB 1 0 2020 Submit Original Only Daily Report of Well Operations PBU 18-29C ACTIVITYr1ATF **'WELL S/I ON ARRIVAL*'*(profile mod) V RIH w/ 4-1/2" GR AND LATCH FLOW THRU SUB AT 11,801' SLM (Sheared GR, POOH). 1/17/2020 **'CONTINUE JOB ON 18 -JAN -2020*** '**JOB CONTINUED FROM 17 -JAN -2020*** (profile mod) PULLED 4 1/2" FLOW THROUGH STOP FROM 11,822' MD JARRED ON UPPER INSITU AICD STRADDLE @ 12,082' MD FOR 5 HOURS PULLED UPPER INSITU AICD STRADDLE FROM 12,082' MD 1/18/2020 ***CONTINUE JOB ON 19 -JAN -2020*** ***JOB CONTINUED FROM 18 -JAN -2020*** (profile mod) RAN 2.34" CENT W/ 2-7/8" BRUSH FROM TOP OF REMAINING STRADDLE TO R -NIPPLE AT 12,136' MD SET 45KB UPPER STRADDLE W/ BAKER BX CMD SLD SLV AT 12,091' MD w/ DPU (SLD SLV IN STRADDLE AT 12,099' MD) NOTE: SLD SLV IN STRADDLE IS OPEN W/ 1.25" ID ORIFICE INSERT PRE-INSTALLED THAT HAS TWO .188" PORTS 1/19/2020 ***WELL S/I ON DEPARTURE*** TREE= 4-1/16" CSN V(ELLFlEAD= FMC ACTUATOR= CM/-SH3000 OKB. ELEV ---5V W ELEV = 44.1' BF. ELEV = 18.03' 20" COPD, 110' KOP= 3300' 91.5#, H-40 Max Angle = 94' (4113011' D =19.124" Datum MD= WA DatumTVD= 8800'SS 13-3/8" CSG, 68#, K-55 BTCXO L-80 BTC 116' 9-5/8" MA-PSTOCVC (06/06/10) 3374) 13-3/8" CSG, 68#, L-80 71D= 12.415" —3391 \ 9-5/8' CSG, 47#, Nr -80 NSCC, D = 8.681" —F---339-1�\ 18-2 Minimum ID = 1.25" I@ 12099' ORIFICE SLEEVE SET IN BKR CMD SLD SLV 4-112' TBG. 12.6#, 13CRVAM TOP, 11907' .0152 bpf, D = 3.958" 7" LNR 26#, 1-80 TC -IX TO L-80 B7GM 11960' 7" LW 26#, L-80 BTC -K .0383 bpf, D = 6276' 12076' PERFORATION SUMMARY REF LOG: MND ON JUNE 0823/09 ANGLE AT TOP PEW: 30" @ 12115' We: Refer to Production DB for historical pert data SIZE SPF INTERVAL Cpn/Sgz SHOT SOZ 3-3/8' 6 12115-12120 O 09/16/10 16 10/14/11 2-W4' 6 13002 - 13750 O 12/30/17 2-7/8" 6 13850 - 14400 O 07/01/09 36 2-7/8" 6 14500 - 14977 O 07/01/09 2-7/8" 6 14977 - 15100 O 07/01/09 2-7/8" 6 15150 - 15400 O 07/01/09 12" LW 12.8#, L-80 BT -M_01 bpf, D = I4-1/2" HES X NP, ID= 3.813" 9-518" X 7" ZXP LTPw / PBR D = 629" 06.32 MILLOUT WNDOW (18-29C) 3374' - 3391' GAC I FT MANDRFI S ISTI MD I TVD DEV TYPE VLV LATCH PORT LATE 1 3720 3700 20 KBG2 BP Exploration (Kaska) BK 16 10/14/11 2 7738 6108 67 KBGZ BK 16 10)14/11 3 11637 7783 36 KBG2 SO I BK 20 10/14/11 1/2' FESX NP, D=3.813" X 4-12" BKR S3 PKR D 112" FES X NP, D=3.813" 3 XN NP MILLED TO 3.80' OUT 11/12110) tD ZXP LTP w / PRB. D = e [- VYLEU, D = :1.90u- 5" BKR FLEX LOCK LF 4-12" XO. D = 3.958" 12091' - 12138'I145KB NSRU STDL w/ CMD SLD SLV 8 OTtS R -NP (01/1920) 12099' BKR BX CMD SLD SLV N 3TRDL, D = 231" (01/19)20) 12099' ORIFDE SLEEVE SETw/TW0.188'PORTS,ID=1.25' (0111920) 1213W 2-39' OTIS R NP, D = 1.781- I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT VYELL: 18-29C PERMIT No: 2090550 API No: 50-029-22316-03 SEC 24, T11 N, R14E, 1474'FNL & 86' FEL 122892 0-09 ORMALCOMPLEYM 0198/19 CJWJMD 2-718' ORFDE NSERTWWTWO 3/16' PORTS 0510993 N2ES RIGSIDE711ACK (18.29A 05AM19 RCB/JMD PULLED 1 TRP PATCH (0428119) 099498 CTD SIDETRACK 18-298 06/06/19 NXWJMC SET STRADDLE W ADD & BP STOP ON X -LOCH 0793108 WE5 SIDETRACK (18-290) 0625/19 CJWJMD PULL/SET BP STOP & STRADDLE (08109/19) 0198/19 MS/JMD SET ONE TRP PATCH (12/11 012020 CJWJMD PULL BP & ADD/SET STRDL wlOF1FICE & NP I BP Exploration (Kaska) 01108119 MS/JMD SETSLD SLV w2-79' X NP (12J1SMB) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutd"n ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redtill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Liner Patch 8 AICD 0 2. Operator Name. BP Exploration (Alaska), Inc 4, Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number 209-055 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigmphic ❑ Service 1 6. API Number: 50-029-22316-03-00 7. Property Designation (Lease Number): ADL 028307 & 028321 8. Well Name and Number: PBU 18-29C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL a 11. Present Well Condition Summary: - z3 ElVe- Total Depth: measured 15918 feet Plugs measured None feet true vertical 8702 feet Junk measured None feet ,JUN 2 ) 12019 Effective Depth: measured 15417 feet Packer measured 11788 feet true vertical 8701 feet Packer true vertical 7910 feet e ®G C 6� IV' Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 79 20" 29-109 29-109 1530 520 Surface 3346 13-3/8" 28-3374 28-3370 3450/4930 1950/2270 Intermediate 3348 9-5/8" 26-3374 26-3370 6870 4760 Liner 8887 7" 3189-12076 3187-8161 7240 5410 Liner 3643 4-1/2" 11903-15546 8011-8705 8430 7500 Perforation Depth: Measured depth: 12115 - 12120 feet True vertical depth: 8194-8701 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 24-11907 24-8014 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 11788 7910 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mct Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 716 9849 452 0 347 Subsequent to operation: 546 9249 377 0 475 14. Attachments: (reeU1.d oer20 nnc 25.07c2s on, &25,283) 15. Well Class after work: Daily Report of Well Operations p Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Authorized Name: Oestgaard, Finn Contact Name: Oestgaard, Finn Authorized Title: Production Engineer Challenger Contact Email: Fmm.Oestgaard0bp.com �L( I`i 6 Authorized Signature: Date: Contact Phone: +1 907 564 5026 Form 10404 Revised 04/2017 �L 1/1A Iii 131,,-v q ;1 R D '$ 415-6 L 0 11919 Submit Original Only 'WELL S/I ON ARRIVAL**'(patch tbg / liner) RAN 3 12" BRUSH, 2.25 LIB TO -4' SLM (inconclusive) RAN 3.75" LIB TO TOP OF PATCH @ -7' SLM (impression of reduced F.neck) ATTEMPTED TO LATCH FISH W/ STANDARD 4 1/2" GR (unsuccessful) PLANTED 45KB RELEASABLE SPEAR IN PATCH @ -6' SLM Oar 45min) 4/212019 "'CONT WSR ON 422/19*** 'CONT WSR FROM 421/19*** (fishing) PULLED TOP 10' OF PATCH W/ ORIFICE INSERT FROM TREE PULLED FLOW CUT SLIDING SLEEVE FROM TOP OF LOWER SECTION OF PATCH FROM 12,092' SLM PLANTED 4 12" RELEASABLE PRT SPEAR IN 28' LOWER PATCH SECTION @ 12,093' SLM Oar 15min) 4/22/2019 ***GO ON WEATHER TICKET*** ***CONT JOB FROM WSR ON 422/19*** (patch tubing / liner) R/U SWCP 4516 SLICKLINE UNIT 4/24/2019 '*'CONT WSR ON 4/25/19*** 'CONTINUED FROM 424/19 WSR*** (Patch tubing / liner) RAN VARIOUS SPEAR / GRAPPLE COMBINATIONS TO LOWER PATCH AT 12,092' SLM. UNABLE TO GET ANYTHING TO HOLD ON FOR MORE THAN 40 MINUTES. 4/25/2019 ***JOB IN PROGRESS, CONTINUED ON 4/26/19 WSR*** ***CONTINUED FROM 4/25/19 WSR*** (Patch tubing / liner) PLANT 4-1/2" x 3-12" RELEASABLE SPEAR IN LOWER PATCH AT 12,092' SLM. JAR FOR 2 HOURS ON BAKER STRADDLE PATCH AT 12,092' SLM (No movement). CURRENTLY RIH W/ 3.50" CENT, 3-1/2" GS TO RELEASABLE SPEAR. 4/262019 ***JOB IN PROGRESS, CONTINUED ON 427/19 WSR*** ***CONTINUED FROM 426/19 WSR**' (Patch tubing / liner) ABLE TO GET BAKER 45KB STRADDLE PATCH MOVING IN HOLE BUT NOT OUT. LRS PUMPED 290 BBLS OF SAFE LUBE & 38 BBLS CRUDE FREEZE PROTECT. RECOVERED COMPLETE BAKER 45KB STRADDLE PATCH FISH FROM 12,099' MD. 4272019 ***JOB IN PROGRESS, CONTINUED ON 428/1 ***CONTINUED FROM 4/27/19 WSR*** (Patch tubing / liner) DRIFT TO DEVIATION AT 12,817' SLM W/ 45KB x 304" DUMMY STRADDLE PATCH. RAN PDS 40 ARM CALIPER FROM 12,880' SLM TO SURFACE (Good data). 4/28/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** ***WELL S/I ON ARRIVAL' (patch) HES RELAY UNIT #46 RAN BAKER 10 SETTING TOOL & 3.70" BAKER 45KB LOWER STRADDLE PACKER (DAL LIH=11.99'). SET LOWER PACKER @ 12,129' MD, CCL- M.E. = 16.77', CCL STOP DEPTH @ 12112.2'. RAN 16.91'x 2-7/8" NSAK BLAST JOINT & QCLL LATCH MANDREL (DAL LIH=16.91') (6 pins 10- 32 shear @ 920# ea) & STUNG INTO LOWER STRADDLE PACKER ASSY. RAN BAKER 10 SETTING TOOL & 3.70" BAKER 45 KB UPPER STRADDLE PACKER W/ 4 x TENDEKA FLOWSURE AICD SUBS & NSAK QCLL MANDREL DAL 1-I1-1=28.01' & STUNG INTO MIDDLE PATCH. *'*'*NOTE: PICK UP WEIGHT @ 12,000' SLM = 1650#***** FINAL PATCH DEPTH E TO E = 12,083.33'- 12,129'. TOP OF PATCH @ 12,082', BTM OF PATCH @ 12,137.5TOTAL CAL = 55.59' CORRELATE TO JEWELRY LOG DATED 16 -SEPT -2010 5/122019 ***CONT. ON 05/132019 WSR*** "'CONT. FROM 05/122019 WSR*** (patch) HES RELAY UNIT #46 SET 4 1/2" X -LOCK W/ IBP STOP @ 11,822' MD RAN 4-12" X CHECK SET TO 11,822' MID ... CONFIRMED GOOD SET 5/13/2019 ***JOB COMPLETE / DSO NOTIFIED'** Daily Report of Well Operations PBU 18-29C 'WELL FLOWING UPON ARRIVAL*** (patch tubing / liner) PULLED 4 1/2" X-LOCK W/ FLOW THROUGH SUB FROM 11,822' MD TAGGED TOP OF PATCH W/ 3.70" CENT, 3.50" LIB @ 12,070' SLM SET 1.781" R-PLUG IN 1.781 R-NIPPLE @ 12,124' SLM SET 4 1/2" X-LOCK W/ FLOW THRU SUB IN X-NIPPLE @ 11,822' MD RAN CHECK SET TO FLOW THRU SUB AND CONFIRMED SET FLOWED WELL FOR 8hrs (see log for results) PULLED 4 1/2" X-LOCK W/ FLOW-THRU SUB FROM 11,822' MD RAN 1.781" EQ PRONG TO 1.781" R-PLUG @ 12,124' SLM 6/7/2019 ***CONT WSR ON 6/8/19' "'CONT WSR FROM 6/7/19*** (patch tubing / liner) PULLED 2-3/8" R-PLUG FROM 12,125' SLM JARRED ON UPPER PATCH SECTION @ 12,170' SLM FOR 4 HOURS W/ NO MOVEMENT R/D SWCP SLICKLINE 4516 FOR .160 UNIT TO R/U 6/8/2019 '**WELL S/I ON DEPARTURE'*' T/1/0=2457/100/18 LRS unit 46'** ASSIST SLB/SL*** (PATCH TBG/LINER) Pumped 66 bbls of 6/8/2019 120* KCL SAFE LUBE down TBG at 5 b m,."'WSR continued to 06/09/19'** ***CONTINUE WSR FROM 6/08/19 SWCP 4518"*(patch tbg / liner) PULLED UPPER SECTION OF AICD STRADDLE PATCH FROM 12,071' SLM SET NEW UPPER SECTION OF AICD STRADDLE PATCH @ 12,082' MD (24' oal) SET 4 1/2" IBP STOP IN X NIP@ 11,822' MD RAN 4 1/2" CHECK SET TO IBP STOP RF 11 822' MD sheared 6/9/2019 'CONTINUE ON 06/10/2019'*' 'CONTINUE FROM 06/09/2019"' (patch tubing / liner) SWCP 4518 RIG DOWN 6/10/2019 "'WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS' TRFF= 41/16' CNV SAFETY NOTA: W ELL ANGLE> 70' 0 12770"" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Size: MD: TVD: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown N /7g 15918 Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program None Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set Straddle Patch w/ Orifice 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work None 5. Permit to Drill Number. 209-055 3, Address. P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ measured 11788 AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-22316-03-00 7. Property Designation (Lease Number): ADL 028307 & 028321 8. Well Name and Number: PBU 18-29C 9, Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: 3187-8161 7240 5410 Liner PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Length: Size: MD: TVD: Burst: Collapse: Total Depth: measured 15918 feet Plugs measured None feet true vertical 8702 feet Junk measured None feet Effective Depth: measured 15417 feet Packer measured 11788 fret true vertical 8701 feet Packer true vertical 7910 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Prior to well operation: 165 34775 1905 0 Conductor 80 20" 29-109 29-109 1530 520 Surface 3346 13-3/8" 28-3374 28-3370 3450/4930 1950/2270 Intermediate 3348 9-5/8" 26-3374 26-3370 6870 4760 Liner 8887 7' 3189-12076 3187-8161 7240 5410 Liner 3643 4-1/2" 11903 -15546 8010-8705 8430 7500 Perforation Depth: Measured depth: 12115 - 15400 feet True vertical depth: 8194-8701 feet Tubing (size, grace, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary Intervals treated (measured): 4-1/2" 12.6# 13Cr80 24-11907 24-8014 4-1/2" Baker S-3 Perm Packer 11788 Treatment descriptions including volumes used and final pressure: No SSSV Installed 7910 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 165 34775 1905 0 1087 Subsequent to operation: No Test Available 590 0 14. Attachments (required per 20 nnc 25,070,25 071, a 25 210) Daily Report of Well Operations 0 Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 15. Well Class after work: Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: 1 GSTOR ❑ WINJ ❑ WAG ❑ Oil 0 Gas ❑ WDSPL ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge, Authorized Name: Meixueiro, Pauline Sundry Number or N/A if C.O. Exempt: N/A Contact Name: Meixueiro, Pauline Authorized Title: Production Engineer- Contact Email: paulina.meixueiroLQbp.com Authorized Signature:-IQ�}r-r.�A"4'r tj1,tit cl Contact Phone: +1 907 564 5971 Form 10-404 Revised 04/2017 , oDate: p1( �n1 /"`�r'-----",! RBDMS JAN 1 12019 Submit Original Only Daily Report of Well Operations PBU 18-29C ACTIVITYDATF CI IUKAARV `**WELL S/I ON ARRIVAL***(profile mod) DRIFT W/ 32'8" DRIFT OF 3.70" DUMMY WHIPSTOCK 12/13/2018 TO 12,200' SLM W/ NO ISSUES. ***JOB CONTINUED ON 11/14/18*** ***JOB CONTINUED FROM 11/13/18*** RIG DOWN SWCP SLICKLINE UNIT 4521 *`*WELL LEFT 12/14/2018 S/I ON DEPARTURE*** ***WELL S/I ON ARRIVAL*** (Profile Mod) ***HES RELAY UNIT#46*** INITIAL T/I/O = 2600/575/0. MIRU & PT. RUN 1: DRIFT TO 12,217' SLM W/ 40'x 3.70" DUMMY WHIPSTOCK. RUN 2: SET 4-1/2" X 32' BAKER 45KB ONE -TRIP PATCH 12,100'- 12,132' ELEMENT TO ELEMENT(sliding sleeve open). TOP OF PATCH - 12,099'. MIN. ID = 2.313". CAL LIH - 38'. ALL LOGS CORRELATED TO SLB GR/CCL JEWELRY LOG DATED 16 -SEP -2010. RDMO. WELL LEFT S/I ON DEPARTURE. FINAL TWO = 2600/675/0. 12/18/2018 ***JOB COMPLETE 18 -DEC -2018*** ***WELL S/I ON ARRIVAL*** (profile mod) SET 2-7/8" X LOCK W/ ORIFICE INSERT IN CMD SLD SLV (TWO 3/16" ports) @ 12,106' MD RAN 2-7/8" CHECK SET TO ORFICE INSERT 12106' MD ( good set). 1/1/2019 ***WELL TURNED OVER TO DSO*** TREE 4-1/16, CNV WELLHEAD=_ FM: ACTUATOR= CWSH3000 OKE- E EV = 51' INTERVAL 44.1' BF. aEV = 18.03' KOP = Max Angle = 3300' 94' @ 13071' Datum M)=NA O OratumN0= 8800'SS 91.5#, K40 V= 19A24" 13-3/8' CSG, 68#, K-55 BTC XO L-80 BTC 1—t I 9 -SW WFWSTOCK(Ofiro6lto) 3 13-38' CSG, 88#, L-80 BTC, D = 12.415" 9-5/8" CSG, 47#, NT -80 NSCC, ID= 8.681' Minimum ID = 2.313" @ -12099' 4-1/2" ONE TRIP PATCH 41R'7BG, 126#, 13CRVAM TOP, .0152 hpf, D = 3.956' 7" LW 26#, F80 TC -I XO TO L-80 BTGM FEITORATON SI MMARY Rg LOG: MAD ON JUNE 0823/09 ANGLE AT TOP Pf37F: 30' @ 12115' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 3-38" 6 12115-12120 O 09/16/10 7738 2-314" 6 13002 - 13750 O 1280/17 3 2-71W 6 13650 - 14400 O 07/01109 10/14/11 2-7/8" 6 14500 - 14977 O 07/01/09 2-718" 6 14977-15100 O 07/01/09 2-78" 6 15150-15400 O 07/01/09 41/2" SAFETY NOTES: WELL ANGLE > 70' @ 12770"" 18-29C 4-112" CHROME TBG 14112' HES X NP. D=3.813' 1 3189'—19-5/8"X7"ZXPLTPr 3208' 9-58- X T BR( FLEX MLLOUT WINDOW (18-29C) 3374 - 3391' ST Mi TVD CEV TYPE VLv LATCH PORTI DATE 1 3720 3700 20 KBG2 BK 16 10/14111 2 7738 6108 67 KBG2 BK 16 10/14/11 3 11637 7783 36 KBG2 SO BK 20 10/14/11 1 11788' 1 1 11930" 1 I PBTD I 14112"HIM XNP, D=3.813' 1 4-1/2' HESXN NP MLLED TO 3.80' (MILLED OUT 11112/10) 7" X 5" HFDZXP LTPw / PRB, D= 4.20' 412" MEG, D = 3.958" 7" X 5" BKR FLD( LOCK LNR HGR, ID 5"Xit/2"X0 n=395A" ID=2.313'(12/18/18) 3' BOT CMO SLONG SLEEV E w /2-7/8" X D = 2 313" - PATCH IS OPEN (12/18118) PRUDFOE BAY UNIT WELL 18-29C PBiMT No: 02090550 AR No: 50-029-22316-03 SEC 24, T11N, R14E, 1474' FNL 886' FEL DATE REV BY COMMENTS DATE HTLV BY COMMENTS 1212892 D-09 ORIGINALCOMPLETION 05/23/18 TFA/JM3 PULLED FISH (11/18/17) 0510993 N2PS NIGSIDETRACK(1B-29A) 01/08119 MS/JM) SET ONE TFC PATCH (12M8118) 09104/98 CTDSIDETRACK(18-29B) 01=119 MS/JM7 SETSLDSLVw2-78"XNP(12M8/18) 07103/09 MPS SIDETRACK(18-29C) 01/08/19 CJKJM) 2-718" ORFlCE NSERTw ITWO 3/16" PORTS 01/16/18 N-CDR2 ADPEWS(12/30/17) BP Exploration (Alaska) 01/16/18 JNJJM3 ADD OKB, REF. 8 BF EEV STATE OF ALASKA RECEIVED SKA OILAND GAS CONSERVATION COMMIS SPORT OF SUNDRY WELL OPERATI JAN 2 2 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operationsjh i—'Ct 0 p r Suspend 0 Perforate Il Other Stimulate 0 Alter Casing 0 Changes [[''Arlff,, ❑ Plug for Redd!! 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 209-055 3. Address: P.O.Box 196612 Anchorage, Development IZI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22316-03-00 7. Property Designation(Lease Number): ADL 028307&028321 8. Well Name and Number: PBU 18-29C 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 15918 feet Plugs measured None feet true vertical 8702 feet Junk measured 35 feet Effective Depth: measured 15417 feet Packer measured 11788 feet true vertical 8701 feet Packer true vertical 7910 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20" 29-109 29-109 1530 520 Surface 3346 13-3/8" 28-3374 28-3370 3450/4930 1950/2270 Intermediate 3348 9-5/8" 26-3374 26-3370 6870 4760 Liner 8887 7" 3189-12076 3187-8161 7240 5410 Liner 3643 4-1/2" 11903-15546 8010-8705 8430 7500 Perforation Depth: Measured depth: 12115-15400 feet True vertical depth: 8194-8701 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-11907 24-8014 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 11788 7910 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Kate) _® Ka JAIN S J( Z.LI!u 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: 461 10710 6 440 349 Subsequent to operation: 283 23600 2854 780 1600 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory 0 Development RI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 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: 317-209 Authorized Name: Lastufka,Joseph N Contact Name: Thompson,Ryan Authorized Title: Inf ation a d to troller Contact Email: RYAN.THOMPSON(rD_bp.com Authorized Signature: Date: v/16115 Contact Phone: +1 907 564 4535 Form 10-404 Revised 04/2017 Y / L, l/2 6//V Submit Original Only 4 0Riir R�r.NRc. L' JA."' L.,) 718 • • Daily Report of Well Operations 18-29C ACTIVITYDATE SUMMARY ***WSR job continued from 11/11/2017*** (LRS Unit 46 -Assist Slickline: Brush & Flush) Pumped 115 bbls 180*crude down TBG to assist SL with B&F. SL on well at departure. 11/12/2017 FWHP= 500/441/500 ***CONTINUED FROM 11/11/17 WSR*** (Perforating) BRUSH & FLUSH (Hot) FROM SURFACE TO 45 KB STRADDLE PATCH AT 12,101' MD. JAR 5 HRS AT 2000#'S ON 45 KB STRADDLE PATCH AT 12,091' SLM / 12,101' MD. 11/12/2017 CURRENTLY IN HOLE JARRING (Hour 6) ON PATCH W/4-1/2" GS AT 12,091' SLM. ***CONTINUED FROM 11/12/17 WSR*** (Perforating) JAR 3 HRS @ 2,000#'s ON 45KB STRADDLE PATCH @ 12,091' SLM / 12,101' MD (No movement) (8 HRS TOTAL) PULL 2-7/8" ORIFICE FROM 45KB STRADDLE PACKER @ 12,117' MD (slightly flow cut around orifice) PERFORM SBHPS W/ BP DUAL SPARTEK GAUGES (Made all stops per program) RIG DOWN SLICKLINE & RIG UP BRAIDED LINE TO ATTEMPT TO PULL STRADDLE PATCH. 11/13/2017 ***JOB IN PROGRESS, CONTINUED ON 11/14/17 WSR*** T/I/0=2152/427/4 Temp= Shut in (LRS Unit 72 -Assist SlickLine: Load & Kill) ***Job 11/13/2017 continued to 11/14/2017 ***WSR continued from 11/13/2017*** (LRS Unit 72 -Assist Slickline: Load & Killl) Pumped 285 bbls of 120*crude followed by 20 bbls of ambient dsl to load and kill well for SlickLine. Swab, wing, ssv= closed IA, OA= open to gauge 11/14/2017 FWHP=460/434/60 T/I/O= SSV/400/0 SI. (LRS Unit 46 -Assist Slickline: Freeze Protect Flowline) Freeze protect on FL only per DSO. Pumped 5 bbls 60/40 followed by 23 bbls crude. Dso notified of well status, SV,WV,SSV=closed. MV=open. IA and OA open to gauges. 11/15/2017 FWHP= SSV/400/0 ***WELL S/I ON ARRIVAL*** (Perforating) RIG UP SWCP 4516 TO FISH BAKER 45 KB x 36' STRADDLE PATCH FROM 33' BLM. 11/17/2017 ***JOB IN PROGRESS, CONTINUED ON 11/18/17 WSR*** ***CONTINUED FROM 11/17/17 WSR***(Perforating) LRS LOAD & KILL TUBING W/266 BBLS OF 100*CRUDE. PULL BAKER 45 KB STRADDLE PATCH (Missing one complete element) FROM 34' BLM. (Patch originally pulled from 12,101' md) RIG DOWN BRAIDED LINE, THIRD PARTY CRANE, & RIG UP SLICKLINE. DRIFT TO 12,742' SLM W/3.50"4 - PRONG WIRE GRAB (No recovery). DRIFT TO DEVIATION AT 12,824' SLM W/2-7/8" x 32' DUMMY GUN (No issues). ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 11/18/2017 NOTE: ONE ELEMENT FROM M BAKER 45 KB PACKER LEFT IN HOLE. T/I/O 2540/420/15 Temp= SI (LRS Unit 46 -Assist Slickline: Load & Kill Tubing For Braided Line Operations) Load and kill TBG with 2 bbl 60/40 meth spear followed by 267 bbls of crude . SSL on well at LRS departure. 11/18/2017 FWHP= 201/425/26 T/I/0=2550/400/0. Pre CDR2. Set 4"TWC#427 at 138". TWC LTT Passed. N/D 4" Upper Tree and N/U CDR Tree#7, PT tree cap to 500 psi. Pass. Did Not PTTree. ***Job In 12/5/2017 Progress***See Log. Final WHP's TWC/400/0. • Daily Report of Well Operations 18-29C T/I/O=TWC/400/0. Pre CDR2. Pressure tested CDR Tree#7 to 300/5000 psi. Pass. Pull 4" "H" TWC#427 at 110". Pt Tree cap to 500 psi. Pass. ***Job Complete*** Final WHP's 12/6/2017 2550/400/0. T/I/0=2548/403/7 (PERFORATING) Pre rig Pumped 255 bbls of Inhibited 1% KCL to load IA, followed by 140 bbls of Diesel to freeze protect the IA. Hung caution tags/AFE 12/20/2017 sign on well. SV=Closed IA,OA=Open to gauge MV=Open WV,SSV=NA T/I/O= 2500/500/0 Set 4" H TWC#432 @ 110". Good Set. Bleed tree to Opsi. RDMO 12/20/2017 ***Job Complete*** See log for details. FWHP=2500/500/0 T/I/O = TWC/560/10. Temp = SI. Bleed IA& OA. (Pre-Rig). Well house, flow line, WH scaffold, SSV&WV removed. IA FL @ 690', (37 bbl), OA FL = near surface. Bled OAP 12/21/2017 to 0 psi in —2 minutes, all gas. Continued on WSR 12-22-17. Continued from WSR 12-21-17. TWO = TWC/120/0. Temp = SI. Bleed IA& OA. (Pre-Rig). Well house, flow line, WH scaffold, SSV&WV removed. IA FL @ 690', (37 bbl), OA FL = near surface. Bled OAP to 0 psi in —2 minutes, all gas. Bled IAP from 560 psi to 10 psi in 8 hours 10 minutes, IA FL came to surface @ 190 psi, reduced bleed rate to minimum to retain freeze protect fluids. Rig down & monitor for 30 minutes. IAP increased 10 psi to 20 psi during 30 minute monitor. Final WHP's = TWC/20/0. 12/22/2017 SV= C. MV= 0. IA, OA= OTG. 05:05 T/I/O = TWC/0/0. Pre CDR2. Installed kill line confiruration on Flow Cross and PT to 5000 12/22/2017 psi. Pass. ***Job Complete*** Final WHP's TWC/0/0. See log for details. T/I/O = TWC/40/0. Temp = SI. WHPs (post bleed). Well prepped for rig. IAP increased 20 psi overnight. 12/23/2017 SV= C. MV= 0. IA, OA= OTG. 09:00 hrs. T/I/O = TWC/90/5. Temp = SI. Bleed WHPs <50 psi (Pre-Rig). IA FL @ 730' (40 bbls). Bled IAP from 90 psi to 20 psi in 2.5 hrs (all gas). Monitored for 30 min, IAP increased 5 psi. Final WHPs = TWC/25/5. 12/26/2017 SV= C. MV= 0. IA, OA= OTG. 17:00 hrs. • • North America-ALASKA BP Page 1 of 5 Operation Summary Report Common Well Name:18-29 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2017 End Date 12/30/2017 SAK000000406(987,000.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:CDR-2 Spud Date/Time:12/6/1992 12:00:00AM Rig Release:12/30/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001076 Active datum:KB @44.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 12/26/2017 12:00 - 16:30 4.50 DEMOB P 11,410.00 POST PULL COIL BACK. SECURE. REMOVE SADDLE CLAMPS.PREP FOR REEL SWAP. SWAP STRIPPER TO 2-3/8"BRASS AND PACKOFFS 16:30 - 22:00 5.50 DEMOB P 11,410.00 POST INJECTOR MAINTENANCE-PJSM WITH AFC CREW.-CHANGEOUT INJECTOR / GOOSENECK. 22:00 - 00:00 2.00 DEMOB P 11,410.00 POST NIPPLE BOPE DOWN.NIPPLE UP TREE CAP. PERFORM LTT TO 3500# 12/27/2017 00:00 - 05:00 5.00 RIGD P PRE MOVE RIG OFF E-12 HOLD A PJSM WITH NABORS&PEAK TRUCKING CREW TO MOVE RIG OFF WELL AND TO E-PAD REVIEW PROCEDURE TO MOVE OFF THE WELL REVIEW USE OF 12X12 STOP BLOCK,STOP COMMANDAND GOOD RADIO I COMMUNICATIONS. INVITE PAD OP TO WITNESS MOVE OFF WELL,DECLINED BUSY WITH OTHER OPS PULL MUD MODULE AWAY AND STAGE DOWN THE PAD VERIFY ALL TREE AND CASING VALVES ARE CLOSED PULL SUB AWAY FROM WELL ***RIG ACCEPTED AT 03:30 WITH REEL SWAP TIME REMOVED*** 05:00 - 06:00 1.00 RIGD P PRE MAIN SUB MOVED OFF THE WELL AND SPOTTED FOR REEL SWAP CONTACT PAD OP TO LET HIM KNOW TREE AND CASING VALVES ARE ALL CLOSED, ASKED IF WE COULD OPEN THE CASING VALVES TO THE GAUGES,DONE WELL SIGN LEFT IN E-12'S EMPTY WELL HOUSE AS PER PAD OP 06:00 - 07:00 1.00 RIGD P PRE HOLD A PJSM TO REVIEW REEL SWAP PROCEDURE WITH NABORS AND PEAK TRUCKING CREWS 07:00 - 10:00 3.00 RIGD P PRE SWAP REELS 10:00 - 11:00 1.00 RIGD P PRE INSTALL JEEP FOR MOVE HOLD A PJSM WITH CREW TO MOVE RIG 11:00 - 15:30 4.50 RIGD P PRE MOVE RIG OFF E-PAD HEADING TO DS18 15:30 - 17:30 2.00 RIGU P PRE PERFORM NEEDED WELDING ON INJECTOR OFF THE EDGE OF PAD 17:30 - 19:00 1.50 RIGU P PRE REVIEW PROCEDURE TO MOVE ON THE I WELL REVIEW USE OF 12X12 STOP BLOCK,STOP I COMMAND AND GOOD RADIO COMMUNICATIONS. INVITE PAD OP TO WITNESS MOVE OFF WELL,DECLINED BUSY WITH OTHER OPS VERIFY ALL TREE AND CASING VALVES ARE CLOSED STAGE MAIN SUB OVER WELL, STAGE MUD MODULE Printed 1/16/2016 11:10:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 2 of 5 Operation Summary Report Common Well Name:18-29 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2017 End Date:12/30/2017 SAK000000406(987,000.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:CDR-2 Spud Date/Time:12/6/1992 12:00:00AM Rig Release:12/30/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001076 Active datum:KB©44.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 19:00 - 00:00 5.00 RIGU P PRE PJSM, PERFORM RIG UP CHECKLISTS. TEAM WORKING ON INJECTOR, TEAM WORKING ON MPD LINE/BOPE STACK ***RIG ACCEPTED AT 19:00,BACK OUT 13.5 HRS FOR REEL SWAP AND ACCEPT RIG AT '03:30 FOR BILLING PURPOSES.*** 12/28/2017 00:00 - 03:00 3.00 RIGU P -6.90 PRE PERFORM PASSING LTT ON SWAB/MASTER NIPPLE DOWN TREE CAP FLANGE. INSTALL I MPD LINE TO COMPANION FLANGE FINISH WORKING INJECTOR TESTING. PREPARE INJECTOR FOR PULL TEST. INSTALL PULL BAR. PULL TEST INJECTOR TO '100K. 03:00 - 09:00 6.00 RIGU P PRE RIGGING UP INNER REEL IRON SWAPPING GRIPPER BLOCKS TO 2-3/8" RUN STABBING CABLE THROUGH INJECTOR AND MU GRAPPLE 09:00 - 09:20 0.33 RIGU P PRE PJSM TO STAB PIPE 09:20 - 10:15 0.92 RIGU P PRE STAB PIPE 10:15 - 12:00 1.75 RIGU P. PRE CUTOFF GRAPPLE AND MU CTC AND PULL TEST 12:00 - 14:50 2.83--_ RIGU P PRE HEAD UP BHI AND TEST LINE 14:50 - 16:45 1.92 RIGU P PRE LOAD COIL WITH FRESH WATER 16:45 - 17:30 0.75 RIGU N PRE PRESSURE BULKHEAD FAILED AT 2400 PSI, BLEED OFF,REMOVE INJECTOR FROM THE WELL AND SHELL TEST TO START TESTING BOP'S 17:30 - 00:00 6.50 BOPSUR P r PRE TEST BOPE TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -TEST WITH 2-3/8"TEST JOINTS -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -TEST WITNESS WAIVED BY AOGCC REP GUY COOK -ALL GAS ALARMS TESTED. -7-1/16"ANNULAR,BLIND/SHEAR,2-3/8"PIPE /SLIP,MUD CROSS,2-3/8"x 3.5"VARIABLES, 2-3/8"PIPE/SLIP -R2 VALVE(FAIL/PASS) 12/29/2017 00:00 - 01:45 1.75 BOPSUR P PRE CONTINUE TESTING BOPE TO BP/AOGCC CRITERIA 01:45 - 05:45 4.00 BOPSUR N PRE DURING OPENING OF 2-3/8"x 3.5"VARIABLE RAM. A HYDRAULIC LEAK WAS DISCOVERED ON RAM. LO/TO ACCUMULATOR/EVACUATE STACK. REPAIR. RE-TEST VARIABLE TO 2-3/8" GOOD TEST APPLIED OPENING PRESSURE TO RAM. STILL LEAKING HYDRAULIC FLUID FROM SAME SPOT. TEST LOWER 2-3/8"PIPE/SLIP RAM WHILE GETTING MECHANIC TO LOCATION. 05:45 - 07:00 1.25 BOPSUR N PRE DOORS NEED TO BE PULLED AND CHECK VALVE REPLACED FOR THE AUTO-LOCKS Printed 1/16/2018 11:10:42AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 3 of 5 Operation Summary Report Common Well Name:18-29 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2017 End Date:12/30/2017 SAK000000406(987,000.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:CDR-2 Spud Date/Time:12/6/1992 12:00:00AM Rig Release:12/30/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001076 Active datum:KB @44.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT i Total Depth Phase Description of Operations (hr) (usft) 07:00 - 07:15 0.25 BOPSUR P PRE DOORS INSTALLED,TEST JOINT INPLACE, FUNCTION RAMS AND VERIFY THEY ARE NOT LEAKING HYDRAULIC FLUID GOOD TEST,INSTALL NIGHT CAP AND SHELL • TEST RAM DOOR SEAL ' GOOD TEST 07:15 - 09:30 2.25 BOPSUR P PRE STAB ON AND PT THE IRV 09:30 - 09:50 0.33 BOPSUR P PRE PJSM WITH GREASE CREW TO CHECK TREE BOLTS 09:50 - 10:30 0.67 BOPSUR P PRE GOOD PT,BLEED OFF,SWAP THE COIL OVER TO KCL WHILE CHECKING TREE BOLTS 10:30 - 11:15 0.75 BOPSUR P PRE CHECK TREE BOLTS 11:15 - 11:40 0.42 BOPSUR P PRE PJSM TO PULL THE TWC 11:40 - 12:30 0.83 BOPSUR P PRE BLOW DOWN STACK TO REMOVE THE KCL FROM THE STACKAND MIX THE HVP FOR THE BULL HEAD KILL 12:30 - 13:00 0.50 BOPSUR P • PRE REMOVE INJECTOR,PU LUBRICATOR,MU PULLING RODS AND STAB ON WELL 13:00 - 13:20 0.33 BOPSUR P PRE I LINE UP TO PRESSURE TEST VALVE CREW LUBRICATOR 13:20 - 13:25 0.08 BOPSUR P PRE PT THE VC LUBRICATOR 13.25 - 13:55 0.50 BOPSUR P PRE - tGOOD PT,BLEED OFF,RIH TO THE TWC, PRESSURE UP TO 3000 PSI THEN STING TO EQUALIZE PRESSURE 13:55 - 14:20 0.42 BOPSUR P PRE PRESSURE UP TPO 3000,UNSEAT POPPET WITH 2575 PSI ON THE WELL BLOW DOWN STACK 14:20 - 14:25 0.08 BOPSUR P PRE NFC WELL 14:25 - 14:40 0.25 BOPSUR , P PRE GOOD NFC,RD THE VC LUBRICATOR 14:40 - 14:50 0.17 BOPSUR P PRE PT THE BHI DFCV'S 14:50 - 15:00 0.17 BOPSUR P PRE GOOD PT TO 3690 PSI,LOST 55 PSI IN 5 MIN 15:00 - 15:15 0.25 BOPSUR P PRE STAB ON WELL,PT LUBRICATOR W/QTS BEFORE OPENING UP TO THE WELL 15:15 - 15:20 0.08 BOPSUR P PRE PT LUBRICATOR TO 3693 PSI 15:20 - 15:30 0.17 BOPSUR P PRE GOOD PT,ON LUBRICATOR RIG EVAC DRILL 15:30 - 15:55 0.42 BOPSUR P PRE VERIFY PUMP AND VALVE LINE UPAS PER PCCL(PRESSURE CROSS CHECK LIST) 15:55 - 18:00 2.08 BOPSUR P PRE ONLINE WITH PUMPS TO BH KILL WELL 352BBLS=1.5X WELLBORE VOLUME 10 NEAT 150 KCL 50 HI-VIS 185 KCL 184 FLUID AT TOP PERF 234 FLUID AT BOTTOM PERF 334 HI-VIS AT TOP PERF 384 HI-VIS AT BOTTOM PERF 355 SHUT DOWN PUMP 18:00 - 18:50 0.83 BOPSUR P PRE SLOW PUMP RATE TO ASSESS LOSS RATE HOOK HOSE TO LUBRICATOR TO PURGE GAS I FROM RISER. OUT MM ACTING ERRATIC. PUSH GAS OVER TOP. LINE UP ACROSS TOP TO EVALUATE LOSS RATE Printed 1/16/2018 11:10:42AM *AII depths reported in Drillers Depths* • ALASKA_BP • Page North America_ 4of5 Operation Summary Report Common Well Name:18-29 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2017 End Date:12/30/2017 SAK000000406(987,000.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:CDR-2 Spud Date/Time:12/6/1992 12.00:OOAM Rig Release:12/30/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001076 Active datum:KB @44.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase I Description of Operations (hr) (usft) 18:50 - 20:30 1.67 BOPSUR P PRE ESTABLISH RATE ACROSS TOP 0.24 BPM IN /0.19BPM 8.42 PPG IN/8.42 OUT LOSS RATE OF 3 BPH. 'COME OFF PUMP. PERFORM 30 MINUTE PUMPS OFF FLOW CHECK. WELL DEAD 'I'PUMP ACROSS TOP TO FILL HOLE. 1.25 BBLS TO FILL. (2.5 BPH LOSS RATE) 20:30 - 22:30 2.00 PRFADD P OTHCMPPJSM, MAKE ANNOUNCEMENTS. INSTALL 1 SIGNS ON CELLAR VERIFY PROPER X-OVERS TO PERF GUNS FOR SAFETY JOINT. -MAKEUP(33)2.75"MILLENNIUM PERF GUNS. -MAKE UP BHI TOOLS TO FIRING HEAD. ' -BHI TEST TOOL. NO COMMUNICATION. -POP OFF AND TEST E-LINE AND TOOL. GOOD TEST. -STAB BACK ON AND ESTABLISH HOLE FILL 'ACROSS THE TOP. -REVERSE POLARITY ON E-LINE. TOOL FUNCTIONED PROPERLY. 22:30 - 00:00 1.50 PRFADD P 3,000.00 OTHCMP _RUH WITH 2.75"PERFORATING BHA#1 -RATE:0.33 BPM IN,0.29 BPM OUT.CIRC PRESSURE:100 PSI -MUD WEIGHT:8.38 PPG IN,8.43 PPG OUT 12/30/2017 00:00 - 04:00 4.00 PRFADD_ P 13800.00 OTHCMP RIH WITH 2.75"PERFORATING BHA#1 -RATE:0.54 BPM IN,0.51 BPM OUT.CIRC PRESSURE:430 PSI -MUD WEIGHT:8.38 PPG IN,8.02 PPG OUT. ABOUT 9000'PUT ON CHOKE. ERRATIC OUT MM DENSITY. ALL RETURNS GOING TO FLOW BACK TANK. -LOG DOWN FOR TIE-IN FROM 12950'TO 13030'MD(FORMATION)WITH-15' CORRECTION TO THE TSAD. -PU WEIGHT OF 63K/RIH 20K -RIH 50'PAST SHOT DEPTH. PU AND PREPARE TO PULSE TOOL. -PULSE TOOL PER HALLIBURTON REP. -RIH PUT GUNS ON DEPTH. PERFORATE 13002'TO 13750' -TIE IN LOG:SCHLUMBERGER MEASURED DEPTH LOG DATED 07-JUN-09 04:00 - 04:10 0.17 PRFADD P 13,800.00 OTHCMP PERFORATION GUNS FIRED. SHOT DETECTION, BHI AXIAL VIBRATION, AND LOSS RATE SHOW INDICATIONS OF GUNS FIRING 04:10 - 05:35 1.42 PRFADD P 13,800.00 OTHCMP CIRCULATE A BOTTOMS UP TO TIGER TANK -3.80 BPM IN /3.58 BPM OUT -8.47 PPG IN, 8.44 PPG OUT 05:35 - 05:50 0.25 PRFADD P 13,800.00 OTHCMP FLOW CHECK WELLABOVE ALL PERFS 05:50 - 08:35 2.75 PRFADD P 13,800.00 OTHCMP GOOD NFC PVT SHOWING A CONSISTANT 22 BPH LOSS RATE VS.IN&OUT MM RATES SHOWING 6 BPH CONTINUE POOH MONITORING TRIP SHEET 08:35 - 08:50 0.25 PRFADD P 13,800.00 OTHCMP FLOW CHECK WELL Printed 1/16/2018 11:10:42AM *AII depths reported in Drillers Depths* SNorth America-ALASKA-BP • Page 5 of 5 l Operation Summary Report Common Well Name:18-29 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2017 End Date:12/30/2017 SAK000000406(987,000.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:CDR-2 Spud Date/Time:12/6/1992 12:00:00AM Rig Release:12/30/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001076 Active datum:KB @44.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 08:50 - 09:10 0.33 PRFADD P 13,800.00 OTHCMP GOOD NO FLOW CHECK,RIH 800'(LENGTH OF GUNS)AND CIRC A BOTTOMS UP FROM THERE 09:10 - 09:20 0.17 PRFADD P 13,800.00 OTHCMP I STOP AT 1950'ALREADY SEEING GAS AT OUT MM AND LOW CO READING AT THE SHAKER GETTING MORE CO AT THE SHAKER STILL LOW LEVEL-9 PPM(OSHA TWA=35 PPM) 09:20 - 09:40 0.33 PRFADD P 13,800.00 OTHCMP I RETURNS HAVE CLEANED UP,POOH 09:40 - 10:05 0.42 PRFADD P 13,800.00 OTHCMP CIRC AT MIN RATE TO KEEP THE HOLE FULL PJSM TOLD MWD AND PERF GUNS WITH HES AND NABORS CREWS 10:05 - 10:45 0.67 PRFADD P 13,800.00 OTHCMP PU INJECTOR AND REMOVE FROM BHA PULL MWD TO THE FIRING HEAD WE HAVE HOLES,LD THE MWD 10:45 - 12:50 2.08 PRFADD P 13,800.00 OTHCMP LD PERF GUNS 12:50 - 13:00 0.17 PRFADD P 13,800.00 OTHCMP LOAD OUT TCP TOOLS 13:00 - 13:30 0.50 PRFADD P 13,800.00 OTHCMP INSTALL NIGHT CAP TO BULLHEAD DIESEL FREEZE PROTECT 13:30 - 13:40 0.17 PRFADD P 13,800.00 OTHCMP CLOSE SWAB AND CHECK INJECTIVITY SHUT DOWN PUMP,INJECTIVITY=2.5 BPM .AT1340PSI 13:40 - 14:30 0.83 PRFADD P 13,800.00 OTHCMP MIRU LRS AND PT THEIR LINE 14:30 - 14:55 0.42 PRFADD; P 13,800.00 OTHCMP GOOD PT,ONLINE WITH 40 BBLS OF DIESEL 14:55 - 15:05 0.17 PRFADD P 13,800.00 OTHCMP SHUT DOWN PUMP AND MONITOR WHP 15:05 - 15:15 0.17 PRFADD P 13,800.00 OTHCMP WHP DOWN TO 0 PSI,GREASE TREE VALVES 15:15 - 15:25 0.17 PRFADD P 13,800.00 OTHCMP TREE VALVES GREASE,INSTALL TWC 15:25 - 16:10 0.75 PRFADD P 13,800.00 OTHCMP PU A TEST JOINT AND FUNCTION RAMS 16:10 - 16:45 0.58 PRFADD P 13,800.00 OTHCMP PU THE INJECTOR,STAB ON AND JET STACK 16:45 - 18:00 1.25 PRFADD P ' 13,800.00 OTHCMP SHUT DOWN PUMP BLOW DOWN REEL WITH AIR COMPRESSOR TO SUMP -BHI REMOVE FLOAT VALVES FROM UQC. 18:00 - 00:00 6.00 PRFADD P 13,800.00 OTHCMP RD CHECKLISTS. -BLOW REEL DOWN WITH BIG BOY AIR COMPRESSOR -RD MANAGE PRESSURE LINE -PULL FLOATS OUT OF UQC FOR UPCOMING BOPE TEST -EVACUATE TREE DOWN TO TWC. -FILL TREE WITH METHANOL -PERFORM LTT ON SWAB/MASTER TO 3500# -NIPPLE STACK DOWN, NIPPLE UP TREE CAP. TEST TO 3500# RIG RELEASE AT 23:59 Printed 1/16/2018 11.10:42AM *All depths reported in Drillers Depths* • • Daily Report of Well Operations 18-29C ACTIVITYDATE SUMMARY T/I/O=TWC/0/0. CDR2 Decompletion. Pulled 4" TWC#432 through stack at 135"with 18' 12/29/2017 of tooling. RKB-25.4' ***Job Complete***See log. Final WHP's 2570/0/0. T/I/O=Vac/0/0. CDR2 Completion. Set 4" "H" TWC#294 through stack with T-bar. RKB- 12/30/2017 25.4'. ***Job Complete***See log. Final WHP's TWC/0/0. T/I/O=TWC/0/0. Post CDR2. N/D CDR2 Kill line#1 and blind companion. PT to 5000 psi. 12/31/2017 Pass. ***Job Complete***See log. Final WHP's TWC/0/0. T/I/O=TWC/0/0 Removed CDR tree Temp#7 Installed production tree. Pulled 4" CIW 1/3/2018 "H" TWC#294. FWP's 300/0/0 see log for details. LRS Test Unit 6. Post Rig Flow Back+ 700' of adperfs. Perform Unit Move, Initial TIO - 1000, 99, 9, Begin Rig Up, PT complete, SB for DSO, SB for CH2MHILL to rerig incorrect DPBGL setup, CH2 had DSO SI DPBGL Well 18-31, CH2 Completed RE-Rig, Called DSO for TBT, DSO POPPED 18-31 and will check wit us after Midnight. Inlet Well 18-29. Outlet 1/9/2018 Well 18-01. Continued on WSR 1/10/18. LRS Test Unit 6. Post Rig Flow Back + 700' of adperfs. Current Well Barrier: Inlet and Outlet: SSV and Swab, Inlet Well 18-29, Outlet Well 18-01. Continued from WSR 01/09/18 SB for DSO, DS18-31 online and in test searator, DSO dialing in DPBGL well and said it won't be ready until changeout. POP Well, Frac found in samples, Perform Solids dumps, Confirmed issues with DSO/WSL/Supv, FPT on location, SI FPT Inlet and Outlet, Depressure, Verify IL/OL/DL Chokes are clear, PT, CH2 Delivering 1/10/2018 Tank Farm. Job to be considered a Frac Flowback. Continued on WSR 01/11/18. T/I/O= 1988/100/50. Freeze protect tbg for well testers. Pumped 1 bbl 60/40 meth spear followed by 38 bbls crude. Freeze protected well 18-01 FL from same tie in on testers 1/10/2018 hardline. Valve positions= SV, SSV, WV= closed. IA/OA= OTG. FWHP= 1985/100/50 LRS Test Unit 6. Post Rig Flow Back+ 700' of adperfs. Current Well Barrier: Inlet: Hardline and Vessel, Outler: SSV and Swab, Inlet Well 18-29, Outlet Well 18-01. Continued from WSR 01/10/18 Complete 3rd Leg RU, SB for CH2MHILL WS, CH2 On location, CH2 Rigging up Tank Lines, CH2 RU complete, 3rd Leg PTed, SB for DSO to Line up for POP, POP Well, Continue Flowback. 1/11/2018 Continued on WSR 01/12/18 LRS Test Unit 6. Post Rig Flow Back + 700' of adperfs. Continued from WSR 01/11/18. Continue Flowback, Perform 8 Hr Piggyback Test, Continue Flowback. Inlet Well 18-29, 1/12/2018 Outlet Well 18-01. Continued on WSR 01/13/18 LRS Test Unit 6. Post Rig Flow Back+ 700' of adperfs. Continued from WSR 01/11/18. Continue Flowback, Perform 8 Hr Piggyback Test, Continue Flowback. Inlet Well 18-29, 1/12/2018 Outlet Well 18-01. Continued on WSR 01/13/18 LRS Test Unit 6. Post Rig Flow Back+ 700' of adperfs. Continued from WSR 01/11/18. Continue Flowback, Perform 8 Hr Piggyback Test, Continue Flowback. Inlet Well 18-29, 1/12/2018 Outlet Well 18-01. Continued on WSR 01/13/18 LRS Test Unit 6. Post Rig Flow Back + 700' of adperfs. Continued from WSR 01/12/18. 1/13/2018 Continue Flowback, RDMO. Inlet Well 18-29, Outlet Well 18-01. Job Complete. T/I/O 2150/1060/0 Freeze protect TBG (Post Well Testers). Pumped 3 bbls 60/40 meth down TBG followed by 38 bbls Crude for FP. Notify DSO, Hang tags SV,WV,SSV=closed 1/14/2018 MV=open IA/OA=otg. FWHp's =1623/1060/0 Well shut in upon departure TREE= 4-1/16"CNV SNOTES:• WELL ACTUATOR= CN1-SH 3000 1 8_2 9 C 4- TBG**i4N >70" 12770'"* OKB.B EV= 51' H 35'BLM -FISH:36.5'BKR 45KB STRADDLE REF H.EV= 44.1'BF.E1B/= 18.03' 20" COND, H 110' ) ik-----------X PATCH(11/14/17) KOP- 3300' 91.5#,H-40 ' ' 2181' -14-1/2"HES X NP,D=3.813" Max Angle= 94°@ 13011' D=19.124" Datum MD= MA _.___a_.a_____..______a_.___.___----- 3189' -i9 5/8°X 7"ZXP LTPw/PBR,D=629" Datum TVD= 8800'SS 13-3/8"CSG,68#,K-55 BTC XO L-80 BTC - 116' 3208' -I9-5/8"X 7"BRK FLEX LOCK LNR HGR D 6.32 9-5/8"WHPSTOCK(06/06/10) -I 3374) 13-3/8"CSG,68#,L-80 BTC,D=12.415" -I -3391 9-5/8"CSG,47#, NT-80 NSCC,ID=8.681" H -3391 \ MNLLOUT WINDOW(18-29C) 3374'-3391' GAS LIFT MANDRELS Minimum ID =3.80" @ 11895' / ST MD TVD DEV TYPE VLV LATCH PORT DATE 4-1/2" XN NIPPLE MILLED ____,-------- 1 3720 3700 20 KBG2 DONE BK 16 10/14/11 I 2 7738 6108 67 KBG2 DONE BK 16 10/14/11 3 11637 7783 36 KBG2 SO BK 20 10/14/11 ' ' 11757' H4-1/2"HES X NP,D=3.813" E X' 11788' H 7"X 4-1/2"BKR S-3 PKR,D=3.870" 11822' H 4-1/2"HES X NP,D=3.813" I I 11895' 4-1/2"HES XN NP MILLED TO 3.80" (MILLED OUT 11/12/10) 11903' 17"X 5'HRD ZXP LTP w/PRB,D=4.20" 4-1/2"TBG,12.6#,13CR VAM TOP, H 1190T -11907' -14-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" 11919' Hr X 5"BKR FLEX LOCK LNR HGR,D=4.250" 7"LNR,26#,1-80 TC-N XO TO L-80 BTC-M -I 11950' H x x 11930' -15"X 4-1/2"XO,ID=3.958" 7"LNR,26#,L-80 BTC-M,.0383 bpf,ID=6.276" - 12076' IL PERFORATION SUMMARY REF LOG:M W)ON JUNE 08/23/09 ANGLE AT TOP PERF:30°@ 12115' Note:Refer to Production DB for historical perf data SIZE SPF NT RVAL Opn/Sqz SHOT SQZ 3-3/8" 6 12115-12120 0 09/16/10 2-3/4" 6 13002-13750 0 12/30/17 --- 2-7/8" 6 13850-14400 0 07/01/09 2-7/8" 6 14500-14977 0 07/01/09 2-7/8" 6 14977-15100 0 07/01/09 I'BTD -� 15417' 2-7/8" 6 15150-15400 0 07/01/09 •••••• 4-1/2"LNR 12.6#,L-80 ET-M,.0152 bpf,ID=3.958" -I 15546' ••••• • DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/28/92 D-09 ORIGINAL COMPLETION 11/15/17 BSEJJMIQ PULL ISO SLV/STRADDLE PULLED UH WELL: 18-29C 05/09/93 N2ES RIG SIDETRACK(18-29A) '11/20/17 BSEJJMD CORRECTION TO MLLED XN NP&MIN PERMIT ND:'2090550 09104/98 CTD SIDETRACK(18-29B) 01/16/18 N-CDR2 ADPERFS(12130/17) API No: 50-029-22316-03 07/03/09 MES SIDETRACK(18-29C) 01/16/18 JN/JMD ADDED CNB,REF,&BF BEV SEC 24,T11 N,R14E,1474'FM_&86'FEL 05/25/16 MGS/JMD PULL/RESET X LOCK w/ISO SLV 02/14/17 KDP/JMD TREE C/O(01/21/17) BP Exploration(Alaska) r � • P7-D oZo 9 —053- 7-1-- Loepp, aSTLoepp. Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Thursday, December 21, 2017 3:36 PM To: Loepp, Victoria T(DOA) Cc: Leemhuis,Jacob; Browning,Zachary H Subject: FW: Updated BOPE Schematic 11-39 (PTD#214-099), 18-11B (PTD#213-195)and ��`18 29C (PTD#20 ) Attachments: ( Nabors CDR2 BOPE Stack- Bighole.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Sorry for any confusion.We have another adjustment to the BOPE sketch.This will be the final correction prior to the adperf jobs for these 3 wells. If you have any questions or concerns, please don't hesitate to let me know. Have a safe and Merry Christmas! Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 BP Exploration AlaskaI900 E. Benson Blvd1Room: 788DjAnchorage, AK From: Leemhuis,Jacob Sent:Thursday, December 21, 2017 2:12 PM To: Lastufka,Joseph N<Joseph.Lastufka@bp.com> Subject: Updated BOPE Schematic Joe, The next 3 perf wells(18-29C, 18-11B,and 11-39)will be using big coil instead of slim coil. This is an efficiency measure that should save time on these next few perf jobs. The next CTD well will be also using this string so it made sense to pick it up. Thanks, Jacob C. Leemhuis GWO I BP Alaska I Drilling Engineer— I Mobile:+1 (907)223-6792 I Office:+1 (907)564-4989 1 c • • • • Well Bighole CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 Quick Test Sub to Otis Topof7"Otis I O.Oft _._._._._._ f--CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub fl 4-- 7-1116"5k Flange X 7"Otis Box Top of Annular I 6.0 ft •1 ri171/1 Top of Annular Element 6.7 ft Annular Bottom Annular 8.0 ft ► - , iimlot Blind/Shear CL Blind/Shears 9.3 ft 2-3/8'Pipe/Slips CL 2-3/8"Pipe/Slips 10.1 ft --- " 81 I B2B3 B4 Choke I_Ine Kill Line owp0 iawr0. 498lsmuemtdd1I "�� da F ii 111 iia id ::8 "n 3-1,2"VBRs CL 2-3/8"x 3-1/2"VBRs 12.6 ft 2-318"PipelSlips iri `, Cu 2-3/8"Pipe/Slips 13.4 ft ► -� ►' It Cl-of Top Swab 16.0 ft 1:0 —Swab Test Pump Hose je T1 if T2 r 1114 CL of Flow Cross I 17.4 ft I •4. •�• = : 4 1 ` Master CL of Master I 18.8 ft I LDS I 1 .. . -. .•4Al IA I W W W, fir II OA • mmn LDS I I 4, IN tor Ground Level e I 1 prD 209 - 055 • loepp, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday, December 05, 2017 11:33 AM To: Loepp, Victoria T(DOA) Cc: Leemhuis,Jacob;Thompson, Ryan Subject: Sundry's for 18-11B (PTD#213-195, Sundry#317-189) and 18-29C (PTD#209-055, Sundry#317-209) Attachments: Nabors CDR2 BOPE Stack- Slimhole (11-21-17).xlsx Follow Up Flag: Follow up Flag Status: Flagged Victoria, There is a contingent plan in place to have these 2 approved sundries done by CDR2 instead of the Well Work Platform. Please see attached for the BOPE sketch for CDR2.The scope remains the same for both sundries. 18-11B(PTD#213-195)Sundry#317-189—Plug Perforations and Perforate. 18-29C(PTD#209-055) Sundry#317-209—Perforate. Please let me know if you have questions or need any additional information. Thank you, Joe Lastufka information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 BP Exploration AlaskaI900 E. Benson Blvd.IRoom: 788D1Anchorage, AK SCA WED MAR 2 1 201 1 • • Well Siimhole CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 Quick Test Sub to Otis ( -1.1 ft r_.—.— —.— —.— —•—.—. .—'- -.—'—•– Topof7"Otis I 0.0ft 1111_.__. a._. 41--CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub 4---- 7-1116"5k Flange x 7"Otis Box . Top of Annular I 6.0 ft dig 7111 Top of Annular Element 6.7 ft Annular k Bottom Annular 8.0 ft 1 ► ;,m,,;„ Blind/Shear CL Blind/Shears 9.3 ft 2'Pipe/Slips CL 2"Pipe/Slips I 10.1 ft I ► B1 I B2 B3 I 84 Choke Line Kill Line pew la " 7 e vta^ ee a: mm Il �.r{� � 4 sM"dIt�e1M star ira Me lY Cross FIII III 2 3 8"x 3-1,2"VBR, Ill CL 2-3/8"x 3-1/2"VBRs I 12.6 ft I ► e) 2"Pipe/Slips dr,..- 1 CL 2"Pipe/Slips 13.4 ft ► �a 1 CLofTopSwab 16.0ft 04� 4--Swab Test Pump Hose • • • • if T1 jT2 CL of Flow Cross I 17.4 ft I •�• - 01 ` Master CL of Master 18.8 ft . . .,.. LDS ►:4 : : IA ,. .. 11 1 11 i44 II u �r OA MINK LDS 1'.,,. 1115111 Ground Level k I 1 1 • • OF 7,4 y* y/,*, THE STATE Alaska Oil and Gas �� '?►=��►=7� Of LA S KA Conservation Commission = 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Thompson Interventions Engineer NE® JI;, 0 9 20! ; BP Exploration(Alaska), Inc. SCAN P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU 18-29C Permit to Drill Number: 209-055 Sundry Number: 317-209 Dear Mr. Thompson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, )1-1-44 Cathy . Foerster Chair DATED this 6 day of June,2017. RBDMS wJUN - 7 2017 STATE OF ALASKA .ALASKA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate lI. Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 209-055. 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development [JJ 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22316-03-00 • 7. If perforating: 341E . 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 11 . PRUDHOE BAY UNIT 18-29C • 9. Property Designation(Lease Number): 10. Field/Pools: RECElyD ADL 0028321 . � Zt3. tj] /S� S- Zic•A7 PRUDHOE BAY,PRUDHOE OIL• DSS G c// 11. f PRESENT WELL CONDITION SUMMARY MAY 2 3 ZO I7 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): V''' Plugs(MD): u `� 15918 • 8702• 15417 8701 Z 42-3 ��� Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 3348 9-5/8"47#NT-80 26-3374 26-3370 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): I Perforation Depth TVD(ft): Tubing Size: Tubing Grade: I Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 24-11907 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary Ir] Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development ® . Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil a• WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Thompson,Ryan be deviated from without prior written approval. Contact Email: RYAN.THOMPSON@bp.com Authorized Name: Thompson,Ryan Contact Phone: +1 907 564 4535 Authorized Title: Interventions Engineer Authorized Signature: Date: S/Z 2// 7 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number:�] /' Integrity 1 2 0 9 Plug g ty 0 BOP Test l Mechanical Integrity Test 0 Location Clearance 0 Other: / �i! 5 5 J to 3b /7 1- Lc- Pj 1��1vLv/ay- p rt ✓7vL-f--tr� f--r51" -I-0 2 5-Uv /' 5 Post Initial Injection MIT Req'd? Yes 0 No I� Spacing Exception Required? Yes 0 No Subsequent Form Required: ` £ Y t 4' APPROVED BYTHE Approved by COMMISSIONER COMMISSION Date:t(O -/7 r L 4./57.q-- ORIGINAL /5//�ORIGINAL RBDMS w � Y - � �U17 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval.�<j/ ,�,�7 Attachmegts in Duplicat • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue RECEIVED Anchorage, AK 99501-3572 MAY 2 3 2017 AOGCC RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary May 22, 2017 To Whom it May Concern: Attached please find the Sundry Application for adding perforations via a Well Work Platform for 13-29C, PTD # 209-055. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 44 • Sundry Request for Extended Add Perf utilizing the Well Work Platform Well: 18-29C Date: 5/18/2017 Engineers: Jamin Laplante: 907-564-4137 Chris Stone: 907-564-5518 Ryan Thompson: 907-564-4535 MASP: 2423 psi V Well Type: Producer Estimated Start date: June/July 2017 History: 18-29C was a Rotary Sidetrack, drilled in 2009, targeting Zone1A sands in Eastern DS-18. Initially, 1400' of Zone 1A perfs were shot. The well required the use of dirty poor-boy gas lift to flow and required frequent HOTS due to paraffin depositions in the tubing. At times the depositions were so bad that SL and even coil were utilized to clean the tubing and restore flow. Due to safety issues and time constraints the use of dirty poor-boy gas lift was ceased and an in-situ gas lift option was pursued in August 2010. 5' of perforations were shot in the Sag, tested at 40-60 mmscfpd, and straddled to limit gas entry to -8.0 mmscfpd to allow fulltime gas lift and production of 18-29C. • Scope of Work: The objective of this intervention is to utilize Service Coil and the Well Work Platform to add 750' of perforation to increase the productivity of this well. ,;- Pre WWP work SL 1 Pull Patch, Drift to Deviation Proposed WWP Procedure: • MIRU WWP, BOPE and support equipment • MIRU CTU • Test BOPE with four preventers configured top down (annular, blind shears, 1.75" pipe/slips, mud cross, 2-3/8" x 3-1/2" VBR's, 1.75" pipe/slips). Test the blinds, VBR's, and pipe slips to 3500 psi and the annular to 2500 psi. • Drift and tie in run with GR/CCL • Perf-750ft • RDMO CTU and WWP Post WWP work EL 1 Re-set patch SL 2 Re-set Insitu orifice assembly S • Current Wellbore Configuration TREE- ICLIVILAD4-1116'CNV 4.SAF-Lia.TYcHR0INOTEASE:TBWItl.....ANGLL>IV ff 12770'"'V = Fl/C 1 8-29C AC111A 1014= C7I1V-S1130013 Ok0 ELCV- 509 F31- 1-1.I-V- 70 Cf I -^-- KOP- 3309' 20' cotc H 110' 1.) _ MIN A vle- 94 t13011' 91 51t.I-I-46 I I , 2181 1 11 in'iF Si i 1/ DatLAIM)- N/A 12=19.l24" 1 Dat6m TVD- 8800'SS I — 31119' 1--I%503"X r ZXP L TP /113R,10 6 29" 113-3/8'MG.68e,K-55 eic v.)1_ao Bic I 1 lir I ---1 3208' H9-5/8"X T OW Flo<LOCK LM R NOR ID 6,32 ' VAILSTOO‹(O6/0610} I- 3374) \.).. ./ AZ MU I nin'WIV-40V3I(18.2301 ',''4' .rig l' GAS._FT NANDRELS r,3 3/13'Mr.-,688,180 B1C,11.3-12.415" I I -3391 I IL-tar CSG,47#, NT-80 NSCC,13=8.68r - -3391 Sr M) 1%1: IX-V FYI-i- VII.' I Al(l1 P13141 DA 11- --------1 '3720 3700' 20 KBC2'COLE BK 16 to...14m Minimum ID = 125"e 12117" 1 2 1 7738 6168 67 11.8132 L'ullE BK 16 10/14411 1637 1189 11- KHA;7 SO 44K 711 1041411 2-7/8"X LOCK- wl PORTED ISO SLEEVE 3 1 1 1---F 11757 -3 813" X X I 117RW H7^'t 41-1.0•14141R P..3 PIM NI-11170" • i 11822' H 4 112'ICS X MP,13-3 813' i I 11895' (MILLED OUT 11/12/10} 417 1136,12.6F,13CR VAN TOP, -1 11907' 51, 11903' fr X 5-IfiL)LXPL IP*11441 11-4.20" I 9152 IV,1)-1 low T I 11907' H4 112"ALEC,D-3 958- - 11919' I r x S"13/(12 I LLX-4.XLX LARFIGR,13-40' ! :r L NIL 2647,I-80 11;-1 XL)11.-)L.K.El 10-11 I i 11950' - - --'...".......1 11930' 1.--f 5'X 4-V7'X0,r) 3 958* I I r LAR 26$,L-80 ETTC-1,11 3383 opr,0=8.276" H 12078' L F-u-i-ow TIONSUPSARY RJT LCG.MM>CON JUNE 0812309 :, x 1210V-12137 I-SKR 45401 STRA DOLE w/SKR OW/ 1 A NOLL AT TOP KM 30"r7,12115' 1- Si FFVF 1).7 31'101/06/11} NO?:Refer to itr 128 oductiofor husto,aal pert esti t4 12117' (H2449"X-IMO(Iv POI41b11E}OLATION I SIZE SFF NTERVAL Con/Sqz SI-0T SQZ 3-343' 6 12115-12120 0 09.il GM° 1 SLECV C,C 1.25'iosnone) 2-748' 6 13850-14400 0 07431..00 2-748' 6 14500-14977 0 CAMPOS 2-748Y 6 14977-15103 0 0701,09 2-718' 6 15150-15400 0 0.1,01.00 1 FDIU • 15417' J •••:i.e. ••• 1147(l'AR,,178k,:-BO FIT-1A, 0157 bpi,n- ..954r H 166441' ' .1..S.P. 11A IP 'RPV BY 0011.84.8441S17,11.7--F RV SY i COMMITS ;!UE9101 BAY UNIT 12J21092 D-99 ORIGINAL COM PLET1ON 12123115 TBIYJ1.10 1-1 I..1-1-SF-1 X I OM 441150 SI V if31-1., 1I1-20C J5,0$/9,K: N2E5 RIG SCIETRACM(18-29A) —9512506 MSSIJIT'ARL.,,PESCT/I LOCK win°SLY FITAIT Pt,.'2000550 09/04/98. CH)SIDETRACK(16-2913) 02/14117 KEPOMU 118+C70(31171/10 AM PO '30-879-77316.03 3 187/03/139 N7E3S SICETTIACK I18-29C) SEC 24.T11f4 R14E,1474'FeL/3 tif/I LL 111043,14 RCT.. ,PJC RILL/RESET X LOCK w/ISO SLV 1 - , 1 [34,71}158 WAG:,RI-SI-I R11-41 SI V(04/161153 - - EP Exploration(Alaska) S 0 Planned Wellbore Configuration TREE WB_LI-EAO= FRC 18-29C PROPOSED' 1772.,....iTEIT.GwEL.L...N.L.).70'a 12770"- ACMJATCR CAV-SH 3000 CKB ELEV 509' , Ii I KOP= 3307 20- 001,11 H 1111' I/...:7- --- . , kle(Angie= 94'IP 1::1011 915k H-40 , I I 2111' J-14 112"HFS X NP II)=3 813' j ,Datum MD= NA I)-19 124" / !Datum TVIJ= war ss . . I 3189 1--19-543-x r zxpLTPsv?MR u -=629- I ..., I_ -.. 113 378'CSC,684 K 55 0TC:iu I HO 01:: I 1 116' r—i 3201 I 49-WIr X r BM FLEX LOO LI'li liGft,D6.32 I [9-51frIA4-11-",.:'!..K.1‹I 0430-*0 I 0) I ' 3374) r3-3ar CS43,6104,L-80 RTC. J=12 4 It,' }-i, -3391 „ N, 9',.../1"mc,478 NI 80 NSCC.D 81381- L-3391 \ '..... \ FALLOUT W14130VY 118-29C) 3374' 3391' I GAS LFT MANDRELS I ST AU -IVEY DEV TYPE VLV LATCH FCRT DATE .----"-1 -37. 3 3700 20 KEIG2 DOW BK 16 1004/11 Minimum ID = 1.25" @ 12117' I Or 2 7736 6106 67 KEIG2 OG I& BK 16 1004/11 3 .1153/ 1183 36 1(902 SO BK 20 10,14711 2-718"X-LOCK w/PORTED ISO SLEEVE 1 1----r 11757' _Ft4L.12-HES x NP,D.-5 3 813' 7 v I 1178W HT'X L12"RIM&AMR In 5 670' ; I 11-1_ 11027 j-14-1'r Fts x Hp o-3.813' I in—H 11895' I-4-to-Hps x Kip n=3 sito- MILLED OUT 11112110) . _ I .1 1 11903' Hr x 5'httll/W. IP w.,1101. 41 - 4-U2-TBG 1268 13CR v411 TOP, 11907 I . W. 11907' H4 1e2-1/1,41G, .0152 bpf,D=3958- , • t 11919' I-r X 5'1344R FLIE4 LCx::x.LNR 14GR 1O=4 2t4r. j ._....r_ 2"MR,MC I-00 TO II X0 TOL-00 EITC-41 i-L 11950' j---:, ,,.: Iin lar 1.Q....No' 1-15 X 4 1.2 XL.,,1) 3 J36 I 7"I NH.26#..L-80 ci1u-IA 0363 bpi ID 6.276' H 12076' I—Al bk 1 PERFORATION SLAWARY REF LCC:W.1)ON JUKE 0623/09 12101'-12137 &CR 45KB STRABOLEw,ex.R CMJ ANGLE AT TOP PERE'30'0 12116 [II SLEEVE O.231'(01..0601) 1.1o4 Refer lo Production 043 for hestortal pad clida SZE I SPF POEM/AL Opri1Sqr SHOT SO7 -; 12117' 1-2 Mr X LOCK by?P1RT1Tr 1.01 A-DON • 1 3-376-I 6 12115-12120 0 09r1SLVED 1 6/10 EE , - .25'(05720716) 6 13000-13750 0 I 2-/if' 6 13850-14400 0 07.911013 2-7W 6 14500-14977 0 07.911139 2 Mr 8 14977-15100 0 07,01/09 7 7,8- 6 15t50.15400 0 07+01/09 :-'x - 1541T '• ...,.,',..... 4-i 0-1 lP,12 644,t-Kt Frrm. 0152 bor.I)=3 959" - 155413. W.,IE KEV lisr'' COVIVEN I:5 L'01 I E AtkV 14:r C01.4yENTS PRI...7110E BAY MIT . 12128A2 13-09 Of6GINAL COMPLETION 1223,1511BD-0o PILLYRESET X LOCK Vo olSO SLV WELL 18-29C 05499,93 i PRES ;RIG SIDETRACK(18-29A) 05,25,16 ..403..INI3 R-LL1lET X LCCK...y71S0 sof -{ REMIT No "2090550 09iO4/98 GTO SIDETRACK(18-298) 01'14'11 KLIRODITTTE ao i0,,,21"17) AR No 50-029.22316 03 .07?03109; NTES SIDETRACK(18-29C) SIC 24 T11N R141 1474'114 &155'in .10:06714 kT.I R.4 Rib*RESET X LOG<we i SO SLV , *04,21,15NLA4.444.4l-iESEI FORT SLv 104/16115J BP Exploration{Alaska) • • BOP rig up-with utilization of safety joint/TIW stabbing valve during open hole deployment Platform Floor Riser to platform floor 7 Annular ti tDS el ti�� Blind/Shear M■" ;•,•,, ■ Hydraulically Actuated Valve i iii I I: .I w_.IDi Coil PipetSlip imo Choke Linc ����� .•.� '' �"' ■•y 0::' 4111111,1, 7 `'IIRir='�I '�' _ ■',_�11 WA II _,,lif � Kill Line IMP ,il I0f1 Variable Bore Ram 1 '.ii • • ' I Coil Pipe/Slip 7 x 7 Spool as needed ell NitSwab Valve Com. 1 Flaw Cross 1 . © ,.:C.71 SSV liou 1...-1111i {_'" Master Valve illt ■'L THA II 01 iiiim ]. . Ground Level • • m Qo 0 0 0 _O o 0 co Nin co co co co tf) O N O L0 c - N vLnl- N- U N 0 0 0 0 0 0 0 M in N N- - CO CO • IC) O CO N V' m M I0 O N- co O O O O 1 O CO CO O O M CO CO CO CO CI H N- O) CO c) CO CO N N N v- O N CO CO C m � � cocoC N rn v EO O co co 0 0 O M CN O `- 2 1 1 1 1 1 1 1 4.1 �••i Z `4. O coO CO co V C` N N N ° N • W O OO O a2 C)_ d co co IJ O U) N O O ti �# N O • N 0000 O a O M M C CM M C) N 6) V t +' I� co f� M M a)co O) O Nr co O = co N- N CO CO CO JCO Cr) CO CO W rn0 C ~ W W U W � D Q Q � 0 UoLL, WcEtCtZ Z Ct W m W W ODDF- ZZD • • a) co co CO N- N- N O LC) r CO V 'Cr O CO a W U) N- CD O o rn 0) co O O D co co co w cc > 1- 0.a 0 I- CO N t CO N- N V - a 4 00 V f� 0 D .- CO CO CC) OO > 0 CO CO CO CO CO 0 > I- w CC 0 O 0 w Z � W 0 W 0 0 5 5 J 0 > Y C) O U m 0 0 < •Y Y H t CD 0 N- O O J (Dow ;-I-1 w C 011 I o v t o co 0 0 < W w w Z CD CO 0 ¢ Q Q 0 O D a1°i r 1 2 Z 0 0 0 0 S F' 00 0 a 1- 1- Q _1 Q o Z 2 2 2 0 co u) W cn u) co Q0. a � I- c <M y � 00I- O O W a ,- 00OaI1) O N CO LO cti W 0 0_ 0 2 2 O U) CJ) C/) U) U) ate .{3 a0 2• ocrCtf � IrsF- wwww a, coa. oa_ a a O t m a o H D 0 ra � CA O O 0) 0 7 0 O O CD O > > 0 0 0 0 0 0 Z 1 1 Q W O N N W N r c- W 11 011 J D N CC co Z a :9 J :9 0 W W LL W O = t` I` I` I` m 0 Y D Y W J J J D a' d Q a m cn I u_ a s a a, E Z o o o o o rnrnrna) 0) N NN N N 1 1 LL. a cn O w N CL' Li CO CO CO CO CO m a a- a U J O 0 w w Q m m w Li cn co a cc • • Packers and SSV's Attachment PRUDHOE BAY UNIT 18-29C SW Name Type MD TVD Depscription 18-29C PACKER 3200.92 3198.88 7" Baker ZXP Packer 18-29C TBG PACKER 11788.01 7909.96 4-1/2" Baker S-3 Perm Packer 18-29C PACKER 11914.64 8020.71 5" Baker ZXP Top Packer • • Loepp, Victoria T (DOA) From: Thompson, Ryan <RYAN.THOMPSON@bp.com> Sent Thursday,June 01, 2017 10:36 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU 18-29C(PTD 209-055, Sundry 317-209); PBU 18-35(PTD 215-083, Sundry 317-210) Add Perforations w/WWP Follow Up Flag: Follow up Flag Status: Flagged Victoria, The safety joint/TIW valve assembly will be utilized if necessary to close the BOP's during deployment of the perforating assembly. In event of a well control incident,the safety joint/TIW valve will be made up to the perforating assembly and ran in hole across the BOP's. The BOP's will then be closed on the safety joint so we are not closing BOP's on the perforating guns. Please let me know if you need any further information. Thanks, Ryan Thompson BP Interventions Engineer From: Loepp, Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent: Friday, May 26, 2017 9:20 AM To:Thompson, Ryan Subject: PBU 18-29C(PTD 209-055, Sundry 317-209); PBU 18-35(PTD 215-083, Sundry 317-210)Add Perforations w/ WWP Ryan, Please provide further description of the BOP rig up—"with utilization of safety joint/TIW stabbing valve during open hole deployment" Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~ - ~ js Well History File Identifier Organizing (done) RES N Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: .wo..~,~ IIIIII!IIIIIIIVIII DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: BY: Maria Date: l.// (~ Project Proofing BY: Maria Date: Scanning Preparation ~ x 30 = BY: Maria ,^ Date: d ae,~~„~ded III!IIIIIIIIVIII OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: /s/ d iiuaiiuu""'' mP + ~ =TOTAL PAGES~/ (Count does not include cover sheet) t /s! Y Production Scanning /_ """"""" ""' Stage 1 Page Count from Scanned File: ~ IU (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: ~ ~„ ~ fJ /s/ ~' ' 1 `~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO r BY: Maria Date: /s/ niunun.ui~~~~ Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Comments about this file: Date: ^ Other:: Quality Checked iiiuuuuiuii P 10/6/2005 Well History File Cover Page.doc OPERABLE: Producer 18 -29C (PTD #2090555Tubing Integrity Restored • Page 1 J Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] I Sent: Monday, October 17, 2011 8:51 PM f To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; Chivvis, Robert; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Walker, Greg (D &C); Arend, Jon (NORTHERN SOLUTIONS LLC); Olson, Andrew Subject: OPERABLE: Producer 18 -29C (PTD #2090550) Tubing Integrity Restored All, Producer 18 -29C (PTD #2090550) passed a TIFL on 10/16/2011 after gas lift valves were changed out. The passing TIFL confirms two competent barriers and the well is reclassified as Operable. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells ), Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: Reynolds, Charles (Alaska) Sent: Thursday, October 06, 2011 9:18 PM To: AK, D &C Well Integrity Coordinator; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS ^ -ps Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Oper. ions Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Chivvis, Robe Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: UNDER EVALUATION: Producer 18 -29C (PTD #2090550) Sustained Casi Pressure on IA Above MOASP All, Producer 18 -29C (PTD #2090550) has been confirme, to have sustained casing pressure on the IA above MOASP during shutdown activity. On 10/6/1 the wellhead pressures were Tubing /IA/OA equal to SSV/2310/40 psi. Since the drill site is shutdow 'n the process of performing maintenance work the IA pressure has bled down to 900 psi and will be onitored. The well has been classified as Under Evaluation. The plan forward is: 1. Downhole Diagnostics: Monitor 1 A :UR 2. Downhole Diagnostics: TIFL o e Drill Site is back on -line A wellbore schematic an . TIO Plot are included for reference: « File: 18 -29C TIO •- 6- 11.doc» « File: 18- 29C.pdf» 11/2/2011 UNDER EVALUATION: Producer 18, (PTD #2090550) Sustained Casing ossure on IA A... Page 1 of 1 Regg, James B (DOA) From: Reynolds, Charles (Alaska) [Charles.Reynolds @bp.com] \� Sent: Thursday, October 06, 2011 9:23 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Reynolds, Charles (Alaska); AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer 18 -29C (PTD #2090550) Sustained Casing Pressure on IA Above MOASP Attachments: 18 -29C TIO 10- 6- 11.doc; 18- 29C.pdf All, Producer 18 -29C (PTD #2090550) has been confirmed to have sustained casing pressure on the IA above MOASP during shutdown activity. On 10/6/11 the wellhead pressures were Tubing /IA/OA equal to SSV/2310/40 psi. Since the drill site is shutdown in the process of performing maintenance work the IA pressure has bled down to 900 psi and will be monitored. The well has been classified as Under Evaluation. The plan forward is: 1. Downhole Diagnostics: Monitor IA BUR 2. Downhole Diagnostics: TIFL once Drill Site is back on -line t 5C± = 3 ( , `� oof QTY f' A wellbore schematic and TIO Plot are included for reference: «18 -29C TIO 10- 6- 11.doc» «18 -29C. pdf» Charles Reynolds Filling in for... Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 10/7/2011 TREE= 4-1/16" CIW WELLHEAD = FMC • SAFETY IS: WELL ANGLE > 70° @ 12770' *** - ACTUATOR = BAKER C1 1 8-29 C 4-1/2" CHR ME TBG*** _KB. ELEV = 50.9' . , BF. ELEV 20.0' 1 KOP := 33007 I - ........• 20" CONDUCTOR, Max Angle 94@ 13011' -- 1 110" .I/ ..--, = ' / 2181' H4-1/2" HES X NIP, ID = 3.813" 1 91.5#, H-40 Datum MD = N/A 19.124" Datum TVD 8800' SS , ID = 3189' H 9-5/8" X 7" ZXP LTP w / PBR, ID = 6.29" I 113-3/8" CSG, 68#, K-55 BTC XO L-80 BTC H 116' 1 ......L . "t j 1" —19-5/8" X 7" BRK FLEX LOCK LNR HGR, ID 6.32 1 19-5/8" WHIPSTOCK (06/06/10) H 3374) 1 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 1 —3391 1 9-5/8" CSG, 47#, NT-80 NSCC, ID = 8.681" H —3391 MILLOUT WINDOW (18-29C) 3374' - 3391' - - c.:0•0/ , GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV _ LATCH PORT DATE 1 3720 3700 21 KBG2 DOME BK 16 05/11/11 ! 2 7738 6108 67 KBG2 DOME BK 16 05/11/11 3 11637 7783 36 KBG2 SO BK 20 05/11/11 - _ Minimum ID = 1.36" @ 12117' lig 2.31" X-LOCK w/ PORTED SLEEVE 11757' H4-112" HES X NP, D = 3,813" 1 11788' H 7" X 4-1/2" BKR S-3 PKR, ID = 3.870" 1 2 0 1 1 11822' H 4-1 1 2" HES X NIP, ID = 3.813" 1 11895' 114h/2 HES X NIP, ID = 3.80" (M ILLED OUT 11/12/10) 11903' . 1-17" X 5" HRD ZXP LTP w / PRB, ID = 4.20" 1 4-1/2" TBG, 12.6#, 13CR VAM TOP, — 1 . _ 11907' n I 11907' 1-14-1/2" WLEG, ID = 3.958" 1 .0152 bpf, ID = 3.958" [ i 11919' H7" X 5" BKR FLEX LOCK LNR HGR, ID = 4.250" 1 1 7" LNR, 26#, E80 TC-II XO TO L-80 BTC-M H 11950' }—> 11930' H 5" X 4-1/2" XO, ID = 3.958" I kaAtp= .- 72.01 , 51 1 7" LNR, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" H 12076' 1-A PERFORATION SUMMARY REF LOG: MWD ON JUNE 08/23/09 1-... ..,,,, 1 12101' - 12137 1— BKR 45KB STRADDLE w /BKR CMU ANGLE AT TOP PERF: 30° @ 12115' 41 SLEEVE, ID= 2.31" (01/06/11) Note: Refer to Production DB for historical perf data ... 1. 1 12117' 1— 2.31" X-LOCK w/ PORTED SLEEVE SIZE SPF INTERVAL Opn/Sqz DATE I 3-3/8" 6 12115 - 12120 0 09/16/10 SET IN CMU SSD, ID = .188" (08/02/11) 2-7/8" 6 13850 - 14400 0 07/01/09 1 2-7/8" 6 14500 - 14977 0 07/01/09 2-7/8" 6 14977 - 15100 0 07/01/09 2-7/8" 6 15150 - 15400 0 07/01/09 • • 4 1 • ■ • . ****■ * • * , v v 1 4-1/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID .-- 3.958" H 15546' •,.., .4 1 PBTD H 15417' a. 4-... DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/28/92 D-09 ORIGINAL COMPLETION 05/15/11 JLJ/ PJC GLV C/0(5/11/11) WELL: 18-29C 05/09/93 N2ES RIG SIDETRACK (18-29A) 05/15/11 JLJ/ PJC GLV C/0(5111/11) PERMIT No: F4 2090550 09/04/98 CTD SIDETRACK (18-29B) 07/24/11 CD/ PJC SLD SLV CORRECTION API No: 50-029-22316-03 07/03/09 N7ES SIDETRACK (18-29C) 08/08/11 MSS/ PJC RESET PORT SLV (08/02/11) SEC 24, T11N, R14E, 1474' FNL & 86' FEL 02/28/11 GJF/PJC X-LOCK W/ PORTED SLV (01/3C 1/1#22/11 RC/ PJC SLD SLV CORRECTION 04/08/11 WEC/PJC GLV C/O (04/06/11) BP Exploration (Alaska) PBU 18 -29C PTD #2090550 10/6/2011 TIO Pressures Plot Wet 18 -29 4 OW 3,000 - • • - Tby —11I- 2,000 - -A- OA 00A — 4— 000A On 1.000 - ti • • 07/09/11 07/16/11 07/23/11 07/30/11 08/06/11 08/13/11 08/20/11 08/27/11 09/03/11 09/10/11 09/17/11 09/24/11 10./01/11 STATE OF ALASKA ALASKA SAND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other 0 TUBING PATCH Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ 12101'- 12137' Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ .. 209 -0550 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 -6? 50-029-22316-03-00 8. Property Designation (Lease Number) : _ 9. Well Name and Number: ADLO- 028307 ADL- 028321 PAU 18 -29C 10. Field /Pool(s): • PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 15918 feet Plugs (measured) None feet true vertical 8702.32 feet Junk (measured) None feet Effective Depth measured 15416 feet Packer (measured) 11788 feet true vertical 8700.97 feet (true vertical) 7910 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 94.5# H -40 SURFACE - 110 SURFACE - 110 1530 520 Surface 3374 13- 3/8 "68# L -80 37 - 3374 37 - 3370 4930 2270 Intermediate 3374 9 -5/8" 47# NT -80 36 - 3374 36 - 3370 6870 5060 Production 8887 7' 26# L -80 3189 - 12076 3187 - 8161 7240 5410 Liner 3643 4 -1/2" 12.6# L -80 11903 - 15546 8011 - 8705 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13CR VAMTOP SURFACE - 11907 SURFACE - 8014 Packers and SSSV (type, measured and true vertical depth) 7 "X4 -1/2" BKR S -3 PKR 11788 7910 D AN 1 2 LD 12. Stimulation or cement squeeze summary: L... ' if 1 1; Intervals treated (measured): JAN 1 1 2011 Treatment descriptions including volumes used and final pressure: or { ��� 13. Representative Daily Average Production or Iniecfion DaT - r�S• 1311 117 1 4SSIIOn Oil -Bbl Gas -Mcf Water -Bbl Casing+iOrrije Tubing pressure Prior to well operation: SI Subsequent to operation: SI 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil n, 0 Gas ❑ WDSPL El GSTOR ❑ WINJ ❑ WAGO GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564 -4944 Date 1/10/2011 Form 10 -404 Revised 10/2010 RBDMS JAN 12 2911 71/ Submit Original Only 1111 / jJ(j,4% • • . . 18 -29C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1/5/2011 * ** *CONT JOB ON 1- 5 -11 * ** *(pre patch) RUN KJ, 2.50" CENT, PETREDAT GAUGES AS PER PROGRAM.(good data)! 1 FW HP= 2400/1100/0 s ** **WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED * * ** 1/6/2011 ; ** *WELL SHUT IN ON ARRIVAL * ** (E -LINE SET BAKER 4.5" "KB" 1STRADDLE COMPLETION (OAL = 36.46') INITIAL T /I /O = 2500 / 1100 / 0 PSI INITIAL VALVE POSITIONS: MASTER, SSV, WING = OPEN; SWAB = CLOSED !TIE TO SLB JEWELRY LOG DATED 16 -SEP -2010. ;SET BAKER 4.5" "KB" STRADDLE COMPLETION WITH INSERT IN 1SLIDING SLEEVE FROM 12,102' - 12,132' (ELEMENT TO ELEMENT). , { OAL = 36.46', TOP OF STRADDLE = 12,100.62'. BOTTOM OF STRADDLE = 12,136.74'. MAX O.D. = 3.70 ". MIN I.D. = 1.38" WITH INSERT INSTALLED! AND 2.31" W/O THE INSERT INSTALLED. INSERT WITH 2 X 0.188 ORIFICE STILL TO BE SET BY SLICKLINE 1FINAL VALVE POSITIONS: MASTER, SSV, WING = OPEN; SWAB = ;CLOSED. DSO NOTIFIED. ;FINAL T /I /O = 2250 / 1100 / 0 PSI. WELL SHUT -IN ON DEPARTURE J ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 DIESEL 1 METH 2 TOTAL 18 -29C 209 -055 PERF ATTACHMENT Sw Name Perf Operation Code Operation Date Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 18 -29C PER 7/1/09 13,850. 14,400. 8,698.73 8,695.47 18 -29C PER 7/1/09 14,500. 14,977. 8,694.71 8,697.42 18 -29C PER 7/1/09 14,977. 15,100. 8,697.42 8,700.09 18 -29C PER 7/1/09 15,150. 15,400. 8,700.5 8,700.65 18 -29C APF 9/16/10 12,115. 12,120. 8,194.34 8,198.67 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • TREE= 4- 1/16" CM/ WELLHEAD = FMC • SAFETY FS: WELL ANGLE> 70° @ 11730' * ** ACTUATOR„= BAKER C 1 8 -2 9 C 4 -1/2" CHROME TBG * ** KB. ELEV = 51.0' BF. ELEV = 20.0' - KOP = 3300' Max Angle = 93 @ 10385' 2181' I- 14 -1/2" HES X NIP, ID = 3.813" I Datum MD = N/A Datum TV D = 8800' SS 1 3189' I—I 9 -5/8" X 7" ZXP LTP w / PBR, ID = 6.29" I 113 -3/8" CSG, 68 #, K -55 BTC (TOP 2 JOINTS) H ?? 1 1 3208' H9-5/8" X 7" BRK FLEX LOCK LNR HGR, ID 6.32 1 19 -5/8" WHIPSTOCK (06/06/10) I — I 3374) 13 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" I — 3391 19 -5/8" CSG, 47 #, NT -80 NSCC, ID = 8.681" H - 3391 MILLOUT WINDOW (18 -29C) 3374' - 3391' / GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 3720 3700 21 KBG2 DOME BK 16 10/07/09 ♦ 2 7738 6180 67 KBG2 DOME BK 16 10/07/09 3 _11637 7783 36 KBG2 SO BK 20 10/07/09 MinimumID= 2.31 "@12120' SL CMD SLV HES SELECTIVE X PROFILE 11757' H4 -1/2" HES X NIP, ID = 3.813" I 11788' I X 4 -1/2" BKR S -3 PKR, ID = 3.870" 1 1 11822' 1 HES X NIP, ID = 3.813" 1 I 11895' I — 4-1/2'' HES X NIP, ID = 3.80" (MILLED OUT 11/12/10) I 11903' 1 X 5" HRD ZXP LTP w / PRB, ID = 4.20" 1 4 -1/2" TBG, 12.6 #, 13CR VAM TOP, 11907' 1 11907' H4 -1/2" WLEG, ID = 3.958" I .0152 bpf, ID = 3.958" 11919' HT X 5" BKR FLEX LOCK LNR HGR, ID = 4.250" 1 1 7" LNR, 26 #, 1 -80 TC-II XO TO L -80 BTC-M I - 1 11950' I — x 11930' H5" X 4 -1/2" XO, ID = 3.958" I 1 7" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 1-1 12076' 1-- h PERFORATION SUMMARY REF LOG: MWD ON JUNE 08/23/09 12101' - 1213711 BKR 45KB STRADDLE w /BKR CMD ANGLE AT TOP PERF: 30° @ 12115' •, 11111 SLEEVE, ID = 2.31" (01/06/11) Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE , 3 -3/8" 6 12115 - 12120 O 09/16/10 ' 2 -7/8" 6 13850 - 14400 O 07/01/09 2 -7/8" 6 14500 - 14977 0 07/01/09 2 -7/8" 6 14977 - 15100 0 07/01/09 2 -7/8" 6 15150 - 15400 0 07/01/09 ( PBTD I—I 15417' I I ■ 1 4 -1/2" LNR, 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" 1—I 15546' •••■ DATE REV BY COMMENTS U DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/28/92 D -09 ORIGINAL COMPLETION 01/06/10 RC /PJC FINAL DRLG CORRECTIONS WELL: 18 -29C 05/09/93 N2ES RIG SIDETRACK(18 -29A) 01/09/11 AMW/PJC STRADDLE /W SLV (1/6/11) PERMITNo:'2090550 09/04/98 CTD SIDETRACK (18 -29B) API No: 50- 029 - 22316 -03 07/03/09 N7ES SIDETRACK (18 -29C) SEC 24, T11 N, R14E, 1474' FNL & 86' FEL 11/16/09 MH/PJC MILLOUT XN NIP (11/12/10) 11/19/10 PJC _DRLG DRAFT CORRECTIONS ; BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 8/26/2010 Permit to Drill 2090550 Well Name/No. PRUDHOE BAY UNIT 18-29C Operator BP EXPLORATION (ALASKIy INC API No. 50-029-22316-03-00 MD 15918 TVD 8702 Completion Date 7/2/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: MWD GR / DIR, GR, MWD GR / RES / NEU / Azimuthal DEN (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ryp meairrmc IYUIIIVCI a .aa.a~o n~cV~a IYV JLp,I JIV FJ vl~ ~.O VO~ncV D C Lis 18704 nduction/Resistivity 3330 15918 Open LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, RAS, RAM, DRHO, NPHI, TRPM Plus Graphics Log Induction/Resistivity 25 Blu 3330 15888 Open MD Vision Service Log Induction/Resistivity 25 Blu 3330 15888 Open TVD Vision Service L g Induction/Resistivity 25 Blu 12040 15888 Open MD Vision Resisitivity r Log Induction/Resistivity 25 Blu 12040 15888 Open TVD Vision Resisitivity /ell Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y V N l Chips Received? ~' Analysis "/ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~/ N Formation Tops ~ N Comments: DATA SUBMITTAL COMPLIANCE REPORT 8/26/2010 Permit to Dritl 2090550 Well Name/No. PRUDHOE BAY UNIT 18-29C Operator BP EXPLORATION (ALASKIy INC MD 15918 ND 8702 Completion Date 7/2/2009 Completion Status 1-OIL Current Status 1-OIL Compliance Reviewed By: API No. 50-029-22316-03-00 UIC N Date: ~ _~__ ~ L~ r, STATE OF ALASKA ALASKA I AND GAS CONSERVATION COMM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.~os zoAAC zs.>>o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: }}~~ ®Developm~~0'[J ~c~loratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7 2009 12. Permit to Drill Number 209-055 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/8/2009 ~ 13. API Number 50-029-22316-03-00 4a. Location of Well (Governmental Section): Surface: 3805' FSL 86' FEL SEC 24 T11N R14E UM 7. Date T.D. Reached 6/23/2009 14. Well Name and Number:. PBU 18-29C , , . , , , Top of Productive Horizon: 3242' FSL, 1501' FWL, SEC. 20, 711 N, R15E, UM 8. KB (ft above MSL): 44.1' Ground (ft MSL): 15.9' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3613' FSL, 4622' FWL, SEC. 20, 711 N, R15E, UM 9. Plug Back Depth (MD+TVD) 15416' 8701' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 691688 y- 5960392 Zone- ASP4 10. Total Depth (MD+TVD) 15918' 8702' 16. Property Designation: ADL 028307 & 028321 TPI: x- 698244 y_ 5959999 Zone- ASP4 Total Depth: x- 701354 y- 5960452 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No bmi electr ni and rin inform ion r 20 AA 25.0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): , MWD GR / DIR, GR, MWD GR / RES / NEU / Azimuthal DEN 'GJ~//YfSOJ'VG'~,~,3'~~ ' ,3„69. ~'w~ 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 2 4. H-4 Surfa 110' S rf 11 3 20 # Cold t II 3-/" - 7' 1 7 III 9-5/8" 47# NT-80 36' 3370' 12-1/4" 221 c ft CI ss' ' 7" 26# L- 0 18 ' 12076' 3187 161' 8-1/2" 1 7 cu lass'G' - 1 - 1 1' - / ' 17 I 23. Open to production or inject If Y li t h i ion? ®Yes ^ No 24. TuelNC RECORD es, s eac nterval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr 11907' 11788' MD TVD MD TVD 13850' - 14400' 8699' - 8695' 14500'-14977 8695'-8697 2rj, ACID, FRACTURE, .CEMENT SQUEEZE, ETC. 14977' - 15100' 6697' - 5700' 1 ' ' ' ' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 5150 -15400 8701 - 8701 2200' Freeze Protected w/ 151 Bbls of Diesel 26. PRODUCTION TEST Date First Production: July 23, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test: 7/24/2009 Hours Tested: $ PRODUCTION FoR TEST PERIOD OIL-BBL: 290 GAS-MCF: 1,526 WATER-BBL: -0- CHOKE SIZE: 77 GAS-OIL RATIO: 5,271 Flow Tubing Press. 526 Casing Press: 1,800 CALCULATED 24-HOUR RATE. OIL-BBL: 869 GAS-MCF: 4,578 WATER-BBL: -0- OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25 .071. COMPLETION None ~8 Form 10-407 Revised 02/2007 r•,,.~T~.~, ~~„ n.. nn,~.,~~ c.~~r~:a air r~,rnc ,~, .v ~~ ~ - 1~0'°I.. a,~~ ~) ~ ?~0~ .~ nil RECEIVED. JUL 2 9 2009 it7tt 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND S ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD 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. Ugnu 4878' 4735' None West Sak 7809' 6135' Colville Mudstone 8728' 6499' Top HRZ 11833' 7949' Base HRZ / LCU 12065' 8151' Sag River 12095' 8177' Shublik A 12145' 8220' Shublik B 12167' 8239' Shublik C 12180' 8251' Sadlerochit 12212' 8279' Top CGL /Zone 3 12366' 8413' Base CGL /Zone 2C 12435' 8473' 23S6 Zone 26 12483' 8512' 22TS 12504' 8528' 21 TS /Zone 2A 12582' 8584' Zone 1 B 12632' 8616' Zone 1A /TDF 12744' 8670' Base Sadlerochit 12898' 8704' Formation at Total Depth (Name): Zone 1A /TDF 12744' 8670' 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. ,,~ - 07~2~10 Signed Terrie Hubble Title Drilling Technologist Date PBU 18-29C 209-055 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. OriUing Engineer: Ryan Ciolkosz, 564-5977 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Fomt 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 18-29 Common Name: 18-29 Test Date Test Type 6/8/2009 LOT 6/18/2009 LOT Test Depth (TMD) Test Depth (TVD) I AMW 3,374.0 (ft) 3,370.0 (ft) 9.50 (ppg) 12,076.0 (ft) 8,161.0 (ft) 8.50 (ppg) Surface Pressure 'Leak Off Pressure (BHP) EMW 620 (psi) 2,283 (psi) 13.04 (ppg) 2,466 (psi) 6,070 (psi) 14.32 (ppg) Printed: 7/16/2009 4:51:08 PM • BP EXPLORATION Page 1 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To I Hours Task Code I NPT I ..Phase Description of Operations 6/3/2009 14:00 - 00:00 10.00 MOB P PRE Move sub, pits, camp, shop, and other equipment from DS-15 to DS-18. 6/4/2009 00:00 - 02:30 2.50 MOB P PRE Finish moving sub, pits, camp, shop, and other equipment from DS-15 to DS-18. 02:30 - 12:00 9.50 MOB P PRE MIRU sub and pits over 18-29B. Ria accented at 12:00. 12:00 - 14:00 2.00 WHSUR P DECOMP~ Take on seawater to the pits. RU circulating lines in the cellar. 14:00 - 15:30 1.50 WHSUR P DECOMP Test the IA to 2500 psi and hold for 10 minutes -good test. Test the OA to 2000 psi and hold for 10 minutes -good test. Bleed down lines. 15:30 - 16:30 1.00 WHSUR P DECOMP RU Drill Site Maintenance lubricator and pull BPV. RD Drill Site Maintenance. 16:30 - 18:30 2.00 WHSUR P DECOMP Circulate out freeze protect. Reverse circulate out 33 bbls of diesel from the tubing. Swap lines and circulate out 111 bbls of diesel from the annulus. 18:30 - 20:00 1.50 WHSUR P DECOMP Confirm well is static. Install two-way check. Test from below to 1000 psi for 10 minutes -good test. Test from above to 3500 psi for 10 minutes -good test. 20:00 - 21:30 1.50 WHSUR P DECOMP ND tree and adapter flange. 21:30 - 00:00 2.50 BOPSU P DECOMP NU BOPE. 6/5/2009 00:00 - 01:00 1.00 BOPSU P DECOMP Continue to NU BOPE. 01:00 - 01:30 0.50 BOPSU P DECOMP RU BOPE testing equipment. 01:30 - 05:30 4.00 BOPSU P DECOMP Test BOPE to 250 psi low / 3500 psi high with 3-1/2" and 5" test joints. Test annular preventer to 250 psi low / 3500 psi high. All tests pass. Test witness waived by AOGCC Rep Chuck Scheve. Test witnessed by NAD Toolpusher Biff Perry and BP WSL Travis Peltier. 05:30 - 06:30 1.00 BOPSU P DECOMP RD BOPE testing equipment. 06:30 - 07:30 1.00 BOPSU P DECOMP RU Drill Site Maitenance lubricator. Pull TWC. RD Drill Site Maintenance. 07:30 - 09:00 1.50 PULL P DECOMP RU to pull 4-1/2" x 3-1/2" tubing completion. 09:00 - 09:30 0.50 PULL P DECOMP Screw into tubing hanger, back out lock-down screws, PU 70k and unseat hanger. Pull hanger to floor. 09:30 - 12:00 2.50 PULL P DECOMP Circulate surface to surface sweep of Safe-Surf-O. Pre-spud meeting with crews coming on tour at noon. 12:00 - 19:00 7.00 PULL P DECOMP POH with 4-1/2" x 3-1/2" tubing completion. Recovered: 74 - 4-1/2" full tubing joints 1 - Camco SSSV 56 of 57 SS bands 1 - 4-1/2" x 3-1/2" XO 38 - 3-1/2" full tubing joints 1 - 3-1/2" GLM 1 - 3-1/2" cut tubing joint (9.49' long) Tubing shows no corrosion on the outside and appears to be moderately to heavily pitted on the inside. 19:00 - 19:30 0.50 PULL P DECOMP RD tubing handling equipment. 19:30 - 20:30 1.00 BOPSU P DECOMP RU BOPE testing equipment for the lower pipe rams. Printetl: 7/16/2009 4:51:13 PM i ~ BP EXPLORATION Page 2 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date I From - To I Hours ' Task I Code I NPT 6/5/2009 20:30 - 21:30 1.00 BOPSU P 21:30 - 22:00 0.50 BOPSU P 22:00 - 00:00 2.00 CLEAN P 6/6/2009 100:00 - 00:30 I 0.50 I CLEAN I P 00:30 - 04:00 I 3.50 I CLEAN I P 04:00 - 05:00 I 1.00 I CLEAN I P Phase , Description of Operations DECOMP Test lower set of VBR's with 4" and 5" test joints to 250 psi low / 3500 psi high. All tests pass. DECOMP RD BOPE testing equipment. DECOMP MU BHA #1, casing scraper (8.5" bit, 9-5/8" casing scraper, 8.5" string mill, DC's, HWDP) to 200'. DECOMP Continue to MU BHA #1; casing scraper (8.5" bit, 9-5/8" casing scraper, 8.5" string mill, DC's, HWDP) from 200' to 744'. DECOMP RIH with 5" drill pipe picking up singles from 744' to 3424'. Tag obstruction in 9 5/8" casing at 3424'. PU - 120k, SO - 120k. DECOMP Attempt to SO through obstruction -unsuccessful. SO 10k, Ok overpull required to pull free. SO 15k to 30k, with 10k to 15k overpull required to pull free. Rotate and attempt to push obstruction -unsuccessful. RPM - 30, TO - 1.5k to 2.5k, SO - 5k. Bit appears to be bouncing on obstruction. 05:00 - 06:00 1.00 CLEAN P DECOMP Cut and slip drilling line. Service top drive. Inspect drawworks, crown, and brake. 06:00 - 07:00 1.00 CLEAN P DECOMP POH from 3424' to 744'. 07:00 - 08:00 1.00 CLEAN P DECOMP LD 9-5/8" casing scraper BHA (BHA #1) from 744'. 08:00 - 09:30 1.50 CLEAN P DECOMP PJSM. RU E-line unit. 09:30 - 11:30 2.00 CLEAN P DECOMP E-line: RIH with GR/CCL + four arm x-y caliper to 3960'. No problems passing through obstruction at 3424'. Log from 3960' to surface, including tight casing at 3424'. POH. Logged 8' of deformed casing from 3424' to 3432' with a minimum ID of 8.35". 11:30 - 12:00 0.50 CLEAN P DECOMP RD E-line unit. 12:00 - 14:00 2.00 CLEAN P DECOMP Change out lower and upper IBOP, and remove actuator for swaging operation. 14:00 - 16:00 2.00 CLEAN P DECOMP MU BHA #2; 8.52" swage„ burner sub, jars, 9 DC's, 15 HWDP to 755'. 16:00 - 17:00 1.00 CLEAN P DECOMP RIH from 755' to 3424'. PU - 117k, SO - 117k. 17:00 - 18:30 1.50 CLEAN P DECOMP Work swage from 3424' to 3429'. Slack down from 3429' to 3445', no drag. 18:30 - 19:30 ~ 1.00 CLEAN P 19:30 - 20:00 I 0.501 CLEAN I P 20:00 - 21:30 1.50 CLEAN P 21:30 - 22:30 1.00 CLEAN P 22:30 - 23:30 1.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 6/7/2009 00:00 - 00:30 ~ 0.50 ~ CLEAN ~ P 00:30 - 01:30 1.00 CLEAN P 01:30 - 02:00 0.50 CLEAN P PU - 117k, SO - 117k. DECOMP Continue to work swage from 3429' to 3424'. Slack-off and overpulls of -70k required to pass through obstruction. DECOMP Post jarring top drive, crown and derrick inspection. DECOMP POH from 3424' to 755'. DECOMP LD swage BHA (BHA #2) from 755'. DECOMP Change out lower and upper IBOP, and re-install actuator. DECOMP MU BHA #3, gauge mill (8.5" string mill, bumper sub, jars, DC's, HWDP) to 29'. DECOMP Continue to MU BHA #3, gauge mill (8.5" string mill, bumper sub, jars, DC's, HWDP) from 29' to 761'. DECOMP RIH from 761' to 3424'. PU - 110k, SO - 110k. DECOMP Tag obstruction on depth at 3424' - no go. SO 20k - no go. 10k overpull required to pull free. SO 30k - no go. 15k overpull required to pull free. Turn mill 45 degrees right, and SO 40k. 30k overpull required Pflntetl: 7/16/2009 4:S1:1S PM BP EXPLORATION Page 3 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABORS 7ES Rig Number: Date !From - To Hours ' Task Code NPT Phase ' Description of Operations 6/7/2009 01:30 - 02:00 0.50 CLEAN P DECOMP to pull free. Repeat with same result. 02:00 - 03:00 1.00 CLEAN P 03:00 - 04:30 1.50 CLEAN P 04:30 - 05:00 0.50 DHB P 05:00 - 06:30 1.50 DHB P 06:30 - 07:30 1.00 DHB P 07:30 - 08:30 1.00 DHB P 08:30 - 10:00 ~ 1.50 ~ WHSUR ~ P 10:00 - 11:30 1.50 WHSUR N 11:30 - 14:00 2.50 STWHIP P 14:00 - 16:30 16:30 - 17:00 ~~ 1~--- ~~ "~ 17:00 - 18:30 2.50 STWHIP P 0.50 STWHIP P 1.501 STWHIPI P 18:30 - 00: ~s ~~- arc, 6/8/2009 00:00 - 02:00 2.00 STW H I P ~ P 02:00 - 03:30 1.50 STWHIP P 03:30 - 04:00 0.50 STWHIP P 04:00 - 04:30 0.50 STWHIP P 04:30 - 05:30 I 1.001 STWHIPI P Pump surface to surface hi-vis sweep at max rate. DECOMP POH from 3424' to 761'. DECOMP LD gauge mill BHA (BHA #3) from 761'. Clean and clear rig floor. DECOMP RU to run 9-5/8" EZSV bridge plug (BHA #4). DECOMP RIH with EZSV bridge plug on 5" drill pipe. Set 9-5/8" EZSV plug at 3396'. PU - 100k, SO - 100k. DECOMP POH from 3396' to surface. LD EZSV running tool (BHA #4). DECOMP RU and pressure test 9-5/8" casing and EZSV to 3500 psi for 30 minutes -good test. Lost 0 psi in 30 minutes. RD pressure testing equipment. DECOMP PJSM. Pull 9-5/8" packoff and replace with new packoff. Test to 3800 psi -test failed. SFAL DECOMP Pull packoff, replace seals, and re-install. Test to 3800 psi - good test. WEXIT MU BHA #5, whipstock (9-5/8" whipstock anchor, slide, window mill, string mill, flex joint, string mill, HWDP, MWD, bumper sub, DC's) to 818'. WEXIT RIH from 818' to 3302'. WEXIT Orient whipstock at 41 degrees left of high side. Tag EZSV at 3396'. Set anchor with 20k slack-off. Shear bolt with 32k slack-off. TOW at 3374'. WEXIT Displace well from 8.5 ppg seawater to 9.5 ppg LSND milling fluid at 420 gpm, 620 psi. recovered thru midnight. PU - 120k, SO - 120k, ROT - 115k. WOB - 10k, RPM - 100, TO - 5k on / 3k off. 427 gpm C~ 660 psi WEXIT Continue to 9-5/8" mill window from 3383'. Finish milling at 3391'. PU - 120k, SO - 120k, ROT - 117k. WOB - 15k, RPM - 100, TO - 4k to 6k on / 3k off. 425 gpm (~ 750 psi TOW - 3374', BOW - 3391'. Metal recovered: 390 ounds. WEXIT Drill 21' of new formation from 3391' to 3412'. WEXIT Work the mill across the window. Window is smooth. WEXIT Circulate hi-vis super sweep at 425 gpm, 680 psi, 110 RPM. Metal recovered for milling operations: 470 pounds. WEXIT Pick u to 3379', and erform LOT. EMW of 13.04 ppg achieved with 620 psi at surface. 9-5/8" x 13-3/8" OA pressured up during test. Printed: 7/16/2009 4:51:13 PM BP EXPLORATION Operations Summary Report Page 4 of 18 ~ Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code ~ NPT ,'~ Phase - - , _ - ` 6/8/2009 05:30 - 06:30 1.00 STWHIP P WEXIT 06:30 - 08:30 2.00 STWHIP P WEXIT 08:30 - 09:30 I 1.001 BOPSUp P I I W EXIT 09:30 - 11:30 I 2.001 STWHIPI P I I WEXIT 11:30 - 14:30 3.00 STWHIP P WEXIT 14:30 - 16:00 1.50 STWHIP P WEXIT 16:00 - 00:00 I 8.001 DRILL I P I I INT1 6/9/2009 100:00 - 12:00 I 12.001 DRILL I P I I INT1 12:00 - 00:00 12.001 DRILL P INTi 6/10/2009 100:00 - 07:30 I 7.501 DRILL I P I I INT1 07:30 - 08:00 I 0.501 DRILL I P I I INT1 08:00 - 12:00 I 4.001 DRILL I P I I INTi Description of Operations POH from 3379' to 818'. LD whipstock BHA (BHA #5) from 818' to surface. Clean and clear rig floor. RU BOP jetting tool. Jet the BOP stack to clean metal shavings. Function all rams. RD BOP jetting tool. MU BHA #6. 8-1/2" drilling (8-1/2" MXL-1X bit, 1.5 degree motor, ARC, MWD, UBHO, stabilizers, DC's, float, jars, HWDP) to 630'. RIH picking up 5" drill pipe singles from 630' to 3369'. PJSM. While RU a-line gyro, obtain ECD baseline of 10.29 ppg with an ECD calculated of 9.96 ppg. Make two attempts to go thru window -unsuccessful. Orient 44 degrees left of high side, slide slick down thru window. Wash from 3395' to 3412'. Drill from 3412' to 3744' while taking gyro measurements every PU - 120k, SO - 115k, ROT - 110k. WOB - 15k to 30k, RPM - 60, TO - 4k on / 3k off. 555 gpm at 1400 psi on / 1327 psi off MW - 9.5 ppg. ECD measured - 10.54 ppg, ECD calc - 10.38 ppg• Drill ahead in 8 1/2" hole from 3744' to 3931' while taking gyro measurements every 30'. Continue drilling ahead from 3931' to 4310'. -WOB 20-25k, 555 gpm, 1590 psi on, 1380 psi off, 4.5k fUlbs torque on, 2.5k ft/Ibs torque off, PUW 130k, SOW 120k, ROT Wt 120k, 80 rpm -AST 1.6 hrs, ART 1.82 hrs, ADT 3.42 hrs, Bit 5.41 hrs -Slow pump rates taken and recorded -MW in and out 9.5 ppg Drill ahead in 8 1/2" hole from 4310' to 5295'. -WOB 15-30k, 555 gpm, 1690 psi on, 1522 psi off, 5k fUlbs torque on, 4k Wlbs torque off, PUW 150k, SOW 125k, ROT Wt 130k, 100 rpm -AST 4.30 hrs, ART 3.02 hrs, ADT 7.32 hrs, Bit 12.88 hrs -Slow pump rates taken and recorded -MW in and out 9.5 ppg Drill ahead in 8 1/2" hole from 5295' to 6013'. -WOB 25-27k, 555 gpm, 1840 psi on, 1670 psi off, 7k fUlbs torque on, 6.5k fUlbs torque off, PUW 162k, SOW 130k, ROT Wt 132k, 100 rpm -AST 2.28 hrs, ART 3.32 hrs, ADT 5.60 hrs, Bit 18.47 hrs -Slow pump rates taken and recorded -MW in and out 9.5 ppg Pump 25 bbl Hi-Vis sweep surface to surface at 555 gpm, 1720 psi, 100 rpm, 5.5k fUlbs torque. Sweep brought back significant amount of cuttings. MW in and out 9.5 ppg. Monitor well -Static. POH from 6013' to 5820' and encounter 50k overpull and swabbing; attempt to wipe tight spot 4x Printed: 7/16/2009 4:51:13 PM ~ ~ BP EXPLORATION Page 5 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To I, Hours Task '~ Code NPT ' Phase Description of Operations C 6/10/2009 08:00 - 12:00 4.00 DRILL P INT1 without success. PUW 165k, SOW 130k. Backream out of hole from 5820' to 3931' at 555 gpm, 1600 psi, 6-12k ft/Ibs torque, 125k ROT Wt. MW in and out 9.5 ppg. 12:00 - 14:00 2.00 DRILL P INT1 Continue backreaming from 3931' to 3450' at 545 gpm, 1240 psi, 100 rpm, 3k fUlbs torque. Orient BHA to 41 deg left and pull through window without circulation to 3369'. PUW 110k, SOW 110k. MW in and out 9.5 ppg. 14:00 - 16:00 2.00 DRILL P INT1 POH from 3369' to 630' 16:00 - 18:00 2.00 DRILL P INT1 Stand back HWDP, jars and DCs. LD MWD tools and bit. Bit grade: 4-3-WT-A-E-1 /8th-ER-BHA 18:00 - 20:30 2.50 DRILL P INT1 SS Powerdrive, Vortex motor, ARC6, stabilizer, MWD, stabilizer, DCs, stabilizer, DC, jars, HWDP, 5" DP, ghost reamer at 3295' 20:30 - 00:00 3.50 DRILL P INT1 RIH with BHA on 5" DP to 1143'; stand back DP in derrick. Continue to PU 5" DP while RIH to 2562'. Shallow hole test MWD at 1045' at 450 gpm, 1035 psi. 6/11/2009 00:00 - 00:30 0.50 DRILL P INTi RIH with 8 1/2" PDC bit, RSS Powerdrive and drilling BHA on 5" DP to 3325'. 00:30 - 02:00 1.50 DRILL P INT1 Cut and slip drilling line, service topdrive, inspect crown, grease sheaves, adjust drawworks brakes. 02:00 - 03:00 1.00 DRILL N DPRB INT1 Contin e RIH with BH on 5" DP to window at 3391'. Attempt several tries with no rotation, with rotation, with and without pumps to exit window N,~, o Go. Consult with SLB and town engineer. 03:00 - 04:30 1.50 DRILL N DPRB INT1 POH to change out BHA. 04:30 - 07:00 2.50 DRILL N DPRB INTi Stand back HWDP and DCs. Change out BHA: 8 1/2" DTX 619 PDC bit, 1.5deg motor, ARC6, MWD, stabilizer, DCs, stabilizer, DC, jars, 5" HWDP, ghost reamer at 3250' behind bit 07:00 - 11:00 4.00 DRILL N DPRB INT1 RIH with BHA singling in on 5" DP to window at 3386'. Orient motor to 43 deg left. 11:00 - 13:00 2.00 DRILL P INT1 Attempt to exit window, tag at 3386' with 10k. Pick string up, set back down and slide through window with no problems. Continue to RIH to 5922'. Wash down to 6013' at 550 gpm, 100 rpm, 5k ft/Ibs torque, PUW 155k, SOW 125k. No fill on bottom. 13:00 - 00:00 11.00 DRILL P INT1 D ' i 1 " h le fr m ',to 7654;,_ -WOB 10k, 555 gpm, 2100 psi on, 1760 psi off, 9k ft/Ibs torque on, 8k ft/Ibs torque off, PUW 180k, SOW 125k, ROT Wt 140k, 100 rpm -AST 1.15 hrs, ART 4.52 hrs, ADT 5.65 hrs, Bit 5.65 hrs -Slow pump rates taken and recorded -MW in and out 9.6 ppg 6/12/2009 00:00 - 06:30 6.50 DRILL P INTi Drill ahead in 8 1/2" hole from 7654' to 8661'. -WOB 15k, 580 gpm, 2350 psi on, 2130 psi off, 12.5k fUlbs torque on, 10k ft/Ibs torque off, PUW 198k, SOW 135k, ROT Wt 148k, 100 rpm -AST .37 hrs, ART 3.60 hrs, ADT 3.97 hrs, Bit 9.62 hrs -Slow pump rates taken and recorded -MW in and out 9.6 ppg 06:30 - 10:30 4.00 DRILL N DFAL INTi Loss of 500 si um ressure. Troubleshoot ressure loss• indications are washout in pipe. POH from 8661' to 7615'. Printed: 7/16/2009 4:51:13 PM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date From - To Hours Task i Code; NPT 6/12/2009 106:30 - 10:30 I 4.001 DRILL I N 10:30 - 11:00 I 0.501 DRILL I N 11:00 - 11:30 0.50 DRILL N 11:30 - 18:00 6.50 DRILL N 18:00 - 18:30 I 0.501 DRILL I N 18:30 - 00:00 I 5.501 DRILL I N 6/13/2009 100:00 - 01:00 I 1.001 DRILL I N 01:00 - 12:00 ( 11.00 ~ DRILL ~ P 12:00 - 00:00 I 12.001 DRILL I P INTi INT1 6/14/2009 100:00 - 05:30 5.50 ~ DRILL P INTi 05:30 - 06:30 ~ 1.00 ~ DRILL ~ P ~ ~ INT1 Page 6 of 18 Spud Date: 6/5/2009 End: 7/4/2009 Description of Operations Tight spots at 7794', 7742', 7681'. Backream when needed at 200 gpm, 500 psi, 45 rpm, 12-15k ft/Ibs torque, PUW 180k, SOW 125k, ROT Wt 145k. Attempt to circulate bottoms up to clean hole. Shut down circulation once; pump pressure fell to 1030 psi from initial pressure at 1310 psi and loss of MWD signal. Obtained 1/2 bottoms up before shutting down pumps. Repair hydraulics oiler chain on drawworks. Continue to POH to find washout. Intermittent swabbing with 50-100k overpull from 7580' to 5340'. Wipe tight areas and continue to POH to 4793' Washout found at 4793 ; LD joint, PU new joint. CBU at 550 gpm, 1575 psi. Estimate 25% increase in cuttings across shakers. RIH to 6570'. CBU at 550 gpm, 1860 psi ICP, 1640 psi FCP, 100 rpm, 8k fUlbs torque. ~ 30% increase in cuttings. -Continue to RIH to 7500'. CBU at 550 gpm, 1735 psi, 100 rpm, 10k fVlbs torque -Continue to RIH to 8567' and wash to 8661' at 330 gpm, 1150 psi. Pump 30 bbl Hi-Vis sweep surface-to-surface at 550 gpm, 1970 psi. -MW in and out 9.6 ppg Circulating 30 bbl Hi-Vis sweep around to surface. Approximately 30% increase in cuttings across shakers with sweep. Continue pumping additional BU at 580 gpm, 1980 psi, 100 rpm, 11 k ft/Ibs torque, ROT Wt 150k to ensure clean hole before drilling ahead; significant reduction of cuttings across shakers. -MW in and out 9.7 ppg before circulating sweep and BU. MW in and out 9.6 ppg after circulating in 200 bbls clean 9.5 ppg mud during circulation. Drill ahead in 8 1/2" hole from 8661' to 9981'. -WOB 20-25k, 580 gpm, 2670 psi on, 2260 psi off, 13.5k ft/Ibs torque on, 11.5k ft/Ibs torque off, PUW 222k, SOW 140k, ROT Wt 155k, 100 rpm -AST 1.08 hrs, ART 5.25 hrs, ADT 6.33 hrs, Bit 15.95 hrs -Slow pump rates taken and recorded -MW in and out 9.6 ppg Drill ahead in 8 1/2" hole from 9981' to 11,209'. -WOB 10-20k, 580 gpm, 2895 psi on, 2495 psi off, 16.5k ft/Ibs torque on, 14.5k ft/Ibs torque off, PUW 245k, SOW 143k, ROT Wt 165k, 100 rpm -AST 1.10 hrs, ART 4.97 hrs, ADT 6.07 hrs, Bit 22.07 hrs -Slow pump rates taken and recorded -MW in and out 9.7 ppg Drill ahead in 8 1/2" hole from 11,209' to 11,778'. -WOB 25k, 580 gpm, 2910 psi on, 2570 psi off, 19.5k fUlbs torque on, 14k fVlbs torque off, PUW 275k, SOW 150k, ROT Wt 175k, 100 rpm -MW in and out 9.7 ppg Circulate in 580 bbls of 11.1.. ooa spike fluid at 580 gpm, 2470 psi, 100 rpm, 18k fVlbs torque to weight up system from 9.7 ppg to 10.3 ppg before entering HRZ Start: 6/2/2009 Rig Release: 7/4/2009 Rig Number: Phase DFAL INTi DFAL INT1 RREP INT1 DFAL INTi DFAL INT1 DFAL INT1 DFAL IINTi F'flftt8tl: //ltb/LUU`J 4:51:13 YM ~ ~ BP EXPLORATION Page 7 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task 'i Code j NPT Phase Description of Operations 6/14/2009 06:30 - 10:00 3.50 DRILL P INTi Drill ahead in 8 1/2" hole from 11 778' to 12,076'. -WOB 15k, 525 gpm, 2560 psi on, 2350 psi off, 20.5k ft/Ibs torque on, 17k ft/Ibs torque off, PUW 285k, SOW 150k, ROT Wt 185k, 100 rpm -AST 2.73 hrs, ART 2.85 hrs, ADT 5.58 hrs, Bit 27.60 hrs -Slow pump rates taken and recorded -MW in and out 10.3 ppg 10:00 - 11:00 1.00 DRILL P INT1 Circulate bottoms up for geological samples at 525 gpm, 2325 psi, 100 rpm, 19k ft/Ibs torque, ROT Wt 185k. Geologist _, confirmed casin oint. 11:00 - 13:30 2.50 DRILL P INT1 Monitor well -Static. Short trip to 11,583'. RIH to TD. Circulate 30 bbl Hi-Vis sweep followed by BU at 550 gpm, 2440 psi, 100 rpm, 18k fUlbs torque. Monitor well -slight loss, MW in and out 10.3 ppg. 13:30 - 20:30 7.00 DRILL P INTi POH to 9 5/8" window at 3367'. Monitor well -static. LD ghost reamer. 20:30 - 22:00 1.50 DRILL P INTi Continue to POH to BHA. 22:00 - 23:30 1.50 DRILL P INT1 LD BHA. Bit grade: 4-4-WT-A-X-1/8th-CT-TD 23:30 - 00:00 0.50 BOPSU P LNR1 Chan a out u er variable rams to 7". Pull wear ring, install test plug. 6/15/2009 00:00 - 02:00 2.00 BOPSU P LNRi Complete installation of 7" rams. Test 7" rams with 7" test joint to 250 psi low, 3500 psi high. RD test equipment. 02:00 - 04:00 2.00 CASE P LNR1 i m t r 7" 26# L-80 TC-II liner 04:00 - 10:30 6.50 CASE P LNR1 RIH with 7" 26# L-80 BTC-M shoe track Qts 1-3). MU BTC-M to TC-II crossover. Fill pipe, test float -held. Continue to RIH with 7"26# L-80 TC-II casing to 3350'. MU liner to optimum make-up of 10,100 fUlbs torque. 10:30 - 11:30 1.00 CASE P LNR1 Stage pumps to 5 bpm and circulate 1 1/2x liner volume at 211 gpm, 1150 psi 11:30 - 20:00 8.50 CASE P LNRi Continue to RIH with 7" liner to 8810'. Total of 212 joints run;. ..~, centralizers on joints 1 and 2. 20:00 - 21:30 1.50 CASE P LNRi RD Franks tool, change out bales. MU 7"x9 5/8" liner hanger and ZXP liner top packer (11.69' long, 7 1/2" ID PBR). PUW 255k, SOW 135k. 21:30 - 00:00 2.50 CASE P LNR1 Continue to RIH with 7" liner on 5" DP to 12,055' 6/16/2009 00:00 - 00:30 0.50 CEMT P LNR1 MU cement head, wash down at 60 gpm, 780 psi. Tag TD at 12076' with 7" 26# L-80 TC-II liner. No fill noted. PU to 12,074'. P W ith pumps on. 00:30 - 03:30 3.00 CEMT P LNRi Stage pumps up to 5 bpm and circulate to condition mud for cement job at 210 gpm, 1230 psi ICP, 825 FCP 03:30 - 05:45 2.25 CEMT P LNR1 PJSM on cement job. Pump cement as per program. -Pump 10 bbls 13.0 ppg MudPush, pressure test lines to 4500 psi. -Pump 15 bbls more 13.0 pg Mudpush ~ 5 bpm followed by 35 bbls 15.8 ppg Class G cement (1.16 cu ft/sk, 169 sks) ~ 5 bpm -Drop dart, chase with 5 bbls water and displace with 388 bbl 10.3 ppg LSND from rig pumps -Plug bumped with 2900 psi. Set liner hanger and packer. Test oat - e cement Ines. -CIP at 0540. Full returns throughout job. 05:45 - 06:00 0.25 CEMT P LNR1 Pull running tool out of liner top packer. Circulate well above liner top packer with 40' reciprocation at 550 gpm, 485 psi. Printed: 7/16/2009 4:57:13 PM BP EXPLORATION Page 8 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours ~ Task Code I NPT Phase Description of Operations 6/16/2009 06:00 - 06:30 0.50 CEMT P LNR1 LD cement head 06:30 - 07:30 1.00 CEMT P LNR1 Cut and slip drilling line, service top drive, inspect drawworks and crown. 07:30 - 09:30 2.00 CEMT P LNR1 POH laying down 5" DP. LD liner hanger running tool. Visual confirmation that dog sub sheared. 09:30 - 17:30 8.00 DRILL P LNR1 RIH with stands of 5" DP and POH laying down 5" DP until all 5" is out of derrick. Pull wear ring. 17:30 - 21:30 4.00 BOPSU P LNR1 Change out saver sub to handle 4" DP. Change out grabber dies. Change out upper rams to 3 1/2"x6". 21:30 - 00:00 2.50 BOPSU P LNR1 RU BOP test equipment. Test BOP equipment with 4 1/2" and 2 7/8" test joints to 250 psi low, 3500 psi high, 2500 psi for annular. Test witnessed by AOGCC rep Bob Noble, Toolpusher Lenward Toussant and WSL Rob O'Neal. 6/17/2009 00:00 - 01:30 1.50 BOPSU P LNRi Test BOP equipment with 4 1/2" and 2 7/8" test joints to 250 psi low, 3500 psi high, 2500 psi for annular. Test witnessed by AOGCC rep Bob Noble, Toolpusher Lenward Toussant and WSL Rob O'Neal. 01:30 - 02:00 0.50 BOPSU P LNR1 RD BOP test equipment 02:00 - 03:00 1.00 CASE P LNR1 RU test equipment to pressure test 7" casing. Pressure test 03:00 - 03:30 0.50 DRILL P 03:30 - 07:00 3.50 DRILL P 07:00 - 09:30 2.50 DRILL P 09:30 - 11:30 2.00 DRILL P 11:30 - 20:30 I 9.001 DRILL I P 20:30 - 22:00 1.501 DRILL P 22:00 - 00:00 2.00 DRILL P 6/18/2009 100:00 - 01:00 1.00 DRILL I P 01:00 - 02:00 1.00 DRILL P 02:00 - 04:30 2.50 DRILL P 04:30 - 05:30 I 1.001 DRILL I P RD testing equipment. PROD1 Clear and clean rig floor. Prepare to RU mule shoe and single in 4" DP. PROD1 RIH singling in 4" DP to 4131'. PROD1 Stand back 4" DP in derrick. PROD1 8" drillin BHA :Hughes MX-R18DX, 1.5 deg Motor, MWD, ADN, CCV to 271'. PROD1 RIH with BHA while picking up 4" DP from pipe shed from 271' to 11914'. PRODi Wash down from 11914' tQ 11987'. Tag up and drill plums landing collar and cement from 11987' to 12064'. 230 gpm, 2230 psi, 60 rpm, 10k tq, ROT wt 135k. Found plugs on depth at 11987'. PRODi Pump 100 bbls water and 47 bbls steel tube pill. Displace the well to 8.5 ppg FloPro at 250 gpm with 1750 psi. PROD1 Finish drilling out shoe track and 20' new hole to 12098'. Pull back into the 7" shoe. -WOB 15k, 250 gpm, 1900 psi, 5k fUlbs torque, PUW 175k, SOW 135k, ROT Wt 142k, 60 rpm -MW in and out 8.5 ppg PROD1 Perform LOT at 12098' and = 8161' tvd. Achieve EMW of 14.3 ppg with a surface pressure of 2466 psi and 8.5ppg MW. PROD1 n 6 178" hole from 12098' to 12191' -WOB 20k, 250 gpm, 1920 psi on, 1780 psi off, 6k ft/Ibs torque on, 5k fUlbs torque off, PUW 178k, SOW 135k, ROT Wt 145k, 60 rpm -AST 0.0 hrs, ART 2.0 hrs, ADT 2.0 hrs, Bit 2.0 hrs -Slow pump rates taken and recorded -MW in and out 8.5 ppg PROD1 Monitor well after connection, well flowing. Shut in and monitor pressure: 270 psi SIDP, 350 psi SICP. Make notifications to BP Field Superintendant Alan Madsen, Printed: 7/16/2009 4:51:13 PM ~ ~ BP EXPLORATION Page 9 of 18 ~ Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABORS 7ES Rig Number: Date From - To Hours it Task Code I; NPT ~ Phase 'i Description of Operations 6/18/2009 104:30 - 05:30 1.00 DRILL I P I PROD1 AOGCC rep John Crisp, FS1 and DS 18 Operators, BP Safety 05:30 - 15:30 10.00 DRILL P PRODi Circulate kick out through choke x3 using drillers method at 3 bpm. -1st circulation: Held SIDDP of 275 psi plus 900 psi of Kill Rate Pressure (KRP). Shut choke in and monitor pressures, stable at SIDPP 390, SICP 390. -2nd circulation: Held SIDDP of 125 psi plus 900 psi of KRP. Shut choke in and monitor pressures, stable at SIDPP 470, SICP 470. Open well to choke manifold and monitor for 15 min. Flow increase of 5 bbls. Shut the well in and monitor pressures, stable at SIDPP 320, SICP 390. -3rd circulation: Final circulation done with no backpressure on choke. CBU at 3 BPM with ICP 770 and FCP 730. Monitor well. Pressures bled to 0 osi. Ooen rams - sliaht flow. 15:30 - 17:30 2.00 DRILL P PROD1 Drill ahead from 12191' to 12285'. -WOB 10-15k, 250 gpm, 2010 psi on, 1810 psi off, 8.5k ft/Ibs torque on, 5.5k ft/Ibs torque off, PUW 180k, SOW 135k, ROT Wt 145k, 80 rpm. -Contiunuously monitoring for gas cut mud returns, pit gains and losses. Gas cut mud found with bottoms up returns from drilling. No significant gas with bottoms up after drilling_ completely through the Shublik zone. Monitor well -slight flow. 17:30 - 18:30 1.00 DRILL P PROD1 Shut well in and record pressures for 30 minutes. Pressures rams and monitor well -slight flow. 18:30 - 19:30 1.00 DRILL P PROD1 Drill ahead from 12285' to 12375'. -WOB 20-25k, 250 gpm, 2010 psi on, 1805 psi off, 14k ft/Ibs torque on, 1 ik Wlbs torque off, PUW 200k, SOW 125k, ROT Wt 145k, 80 rpm -MW in and out 8.5 ppg 19:30 - 20:00 0.50 DRILL P PROD1 Circulate at 250 gpm with 1825 psi before making connection. Gas cut mud back to surface 30 bbls prior to bolt ms ~o. 6000. units max. Circulate additional 80 bbls until 4as units decrease to 700 units. 20:00 - 00:00 4.00 DRILL P PROD1 Drill production hole by sliding from 12375' to 12551'. WOB 20-25k, 250 gpm, 2010 psi on, 1805 psi off, PUW 200k, SOW 125k, ROT Wt 145k, 80 rpm -AST 2.67 hrs, ART 1.87 hrs, ADT 4.54 hrs, Bit 6.540 hrs -MW in and out 8.5 ppg Continue circulating bottoms up prior to connections. No increase in flow at bottoms up, no significant amounts of gas to surface. Max gas units 600. Flow back during connnections has decreased. Loss rate 8 BPH. Total loss for today 49 bbls. 6/19/2009 00:00 - 11:30 11.50 DRILL P PROD1 Drill production hole from 12551' to 13140'. WOB 20k, 250 gpm, 2260 psi on, 1850 psi off, 13k ft/Ibs torque on, 14.5k fUlbs torque off PUW 230k, SOW 110k, ROT Wt 145k, 40 rpm AST 5.6.0 hrs, ART 1.48 hrs, ADT 7.08 hrs, Bit 13.62 hrs MW in and out 8.5 ppg, Adding water 20 bph, loss rate 8 bph. Minimal amounts of gas back at bottoms up after connections: 100 to 300 units. Slight flow at connections. Printed: 7/16/2009 4:51:13 PM a BP EXPLORATION Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 7ES I Date 6/19/2009 From - To 00:00 - 11:30 Hours I 11.50 Task _ DRILL Code - P NPT 11:30 - 12:30 1.00 DRILL P 12:30 - 15:00 2.50 DRILL P 15:00 - 15:30 0.50 DRILL P 15:30 - 16:00 0.50 DRILL P 16:00 - 18:00 2.00 DRILL P 18:00 - 20:00 2.00 DRILL P 20:00 - 21:30 1.50 DRILL P 21:30 - 22:30 1.00 DRILL P 22:30 - 00:00 1.50 DRILL P 6/20/2009 00:00 - 00:30 0.50 DRILL P 00:30 - 02:30 2.00 DRILL P 02:30 - 03:00 0.50 DRILL P 03:00 - 11:30 8.50 DRILL P 11:30 - 14:00 2.50 DRILL P 14:00 - 15:30 1.50 DRILL P 15:30 - 18:30 3.00 WHSUR P 18:30 - 20:00 1.50 DRILL P 20:00 - 22:00 2.00 DRILL P 22:00 - 23:30 1.50 DRILL P 23:30 - 00:00 0.50 DRILL P 6/21/2009 00:00 - 02:00 2.00 DRILL P 02:00 - 03:00 1.00 DRILL P 03:00 - 04:30 I 1.501 DRILL I P 04:30 - 06:00 1.50 DRILL P 06:00 - 08:00 2.00 DRILL P 08:00 - 12:00 4.00 DRILL P Start: 6/2/2009 Rig Release: 7/4/2009 Rig Number: Page 10 of 18 ~ Spud Date: 6/5/2009 End: 7/4/2009 Phase Description of Operations PROD1 8:30-9:30 flow check the well :Gained 1 bbl after 2 min, gained additional 1 bbl after 13 min, gained additional 1 bbl after 40 min. Total of 3 bbls in 55 min. Well still slightly flowing. PROD1 CBU at 250 gpm with 1990 psi. PROD1 POH from 13140' to 12845'. Madd pass from 12845' to 12745' at 250 gpm, 1865 psi, 15k tq, 60 rpm. POH from 12745' to 12074'. 19 bbl gain while POH. PROD1 Monitor well for 30 min. Well flowing. Flow back 7.4 bbls. PROD1 RIH from 12074' to 13140'. No problems, no fill. PROD1 CBU at 250 gpm, 1935 psi, 40 rpms, 14.5k ft/Ibs. Returned 100 bbls of gas cut mud while circulating bottoms up. PROD1 Pump out from 13140' to 12072' at 250 gpm with 1865 psi. PROD1 CBU at 250 gpm with 1820 psi. No significant amount of gas cut mud to surface. PRODi Monitor well -well flowing. Flowed back 6.5 bbls in 30 min. PROD1 Circulate while weighting up from 8.6 ppg to 8.8 ppg. Fluid loss while circulating 11 bph. Total fluid loss for day 113 bbls. PROD1 Monitor well -well flowing. Flowed back 2.5 bbls in 30 min. PROD1 Circulatin to weight up from 8.8 to 9.0 at 250 gpm with 1900 psi. Loss rate while circulating 29 bph. PROD1 Monitor well for 30 min, no gain. Fluid level dropped 1 ft. PROD1 Pump out from 12074" to 4561' at 2 to 4 bpm. Every 10 stds attempt to pull on elevators. Unable to pull on elevators due to bin . PROD1 Monitor well -static. POH from 4561' to top of 7" liner at 3187' on elevators with proper displacement. Monitor well for 15 min - slight loss. Continue POH from 3187' to 272' with proper displacement. PROD1 Monitor well -slight loss. PJSM and LD BHA. Clean and clear rig floor. PROD1 Rig up BOP test equipment.~Test upper pipe rams with 4" test jts, choke manifold to 250 psi low and 3500 psi high. Rig down test equipment. Test witnessed by WSL Mike Dinger, Tool pusher Chris Weaver. Witness of test waived by AOGCC inspector John Crisp. PROD1 PU BHA : Hycalog MSX513M bit, Rotorary Steerable, MWD, ADN with source, CCV. Total length 265' PROD1 RIH with 6 1/8" BHA from 265' to 980' and shallow test MWD. Continue RIH to 5968' fill pipe every 3000'. PROD1 CBU at 250 gpm with 1175 psi. Loss rate 27 bph. PROD1 Monitor well -slight loss. RIH from 5968' to 7419'. Total loss f 1 0 bbls. PRODi RIH with 6 1/8" PDC bit and drilling BHA on 4" DP to 12074'. PROD1 Cut and slip drilling line, service top drive, inspect drawworks, brakes and derrick. PROD1 Pump 50 bbl Steel Lube sweep and displace the well to 8.6 ppg FloPro before going into open hole.~100 units of aas at bottoms up. Monitor well -slight flow. PROD1 RIH from 12074' to 13140', no problems. PROD1 CBU at 255 gpm with 1822 psi. Fluid lost 26 bbls. PROD1 Drill from 13140' to 13576'. WOB 10k, 250 gpm, 1875 psi on, 1763 psi off, 13k fUlbs torque Printed: 7/16/2009 4:51:13 PM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 7ES Date '~ From - To Hours ' Task ..Code NPT _' __. ._ 6/21/2009 08:00 - 12:00 I 4.00 DRILL P 12:00 - 13:30 1.50 DRILL N DFAL PROD1 13:30 - 15:30 2.00 DRILL N DFAL PROD1 15:30 - 17:30 2.00 DRILL (N DFAL PROD1 17:30 - 00:00 6.501 DRILL l N DFAL PROD1 6/22/2009 00:00 - 01:30 1.50 DRILL N DFAL PROD1 01:30 - 02:30 1.00 DRILL N DFAL PROD1 02:30 - 04:30 2.00 DRILL N DFAL PROD1 04:30 - 06:00 1.50 DRILL N DFAL PROD1 06:00 - 07:00 1.00 DRILL N DFAL PRODi 07:00 - 09:00 2.00 DRILL N DFAL PRODi 09:00 - 10:30 1.50 DRILL N DFAL PROD1 10:30 - 12:00 1.50 DRILL N DFAL PROD1 12:00 - 00:00 12.00 DRILL P PROD1 6/23/2009 100:00 - 13:00 13.00 DRILL P PROD1 13:00 - 16:00 I 3.001 DRILL I P PRODi 16:00 - 21:00 5.001 DRILL P PROD1 Start: 6/2/2009 Rig Release: 7/4/2009 Rig Number: Page 11 of 18 ~ Spud Date: 6/5/2009 End: 7/4/2009 Description of Operations Phase on, 11 k ft/Ibs torque off, PUW 195k, SOW 130k, ROT Wt 145k, 140 rpm MW in and out 8.6 ppg Fluid lost 88 bbls. CBU at 250 gpm with 1780 psi. POH due to MWD failure. Pump out from 13576' to 11999' at 126 gpm with 765 psi. 5 overpull at 13410', 13361', and 13254'. Work tight spots. Displace the well to 9.0 ppg at 252 gpm with 1490 psi. Monitor well -slight loss. Pump out of the hole from 11999' to 5218' at 126 gpm with 700 psi. During this interval, made several attempts to pull on elevators. Pumped out to incorrect displacement. At 5218' monitor well -slight loss, pull on elevators to 4744'. Hole taking correct proper displacement. Pump dry job. Fluid lost 56 bbls._Total loss for today 170 bbls. Continue POH from 4648' to 265' standing back 4" DP. PJSM with Schlumberger on handling nuclear source. LD BHA. Inspect bit, bit grade: 0-1-WT-A-X-I-NO-DTF. Make up BHA: Hvcalog MSX513M bit (same bit), new RSS Power Drive, new MWD, ADN with nuclear source, CCV. BHA length 264'. RIH with 6 1/8" PDC bit and BHA on 4" DP from 264' to 6000'. Shallow hole test MWD at 1200'. CBU at 250 psi with 1230 psi. Lost 30 bbls. Continue RIH from 6000' to 12072'. Displace well to 8.6 ppg FloPro at 250 gpm with 1748 psi. Lost 93 bbls from 0700 to 1030. Conitnue RIH from 12072' to 13576' PUW 195k, SOW 125k; taking surveys every 100'. Drill from 13576' to 14703'. WOB 10k, 260 gpm, 2120 psi on, 2075 psi off, 16k ft/Ibs torque on, 13k ft/Ibs torque off, PUW 200k, SOW 125k, ROT Wt 147k, 140 rpm CBU after drilling every 2 stands. 2000-4000 units of gas on bottoms ups. Total loss today 398 bbls. Drill from 14703' to 15918'. -WOB 10k, 275 gpm, 2420 psi on, 2350 psi off, 15.5k ft/Ibs torque on, 14k ft/Ibs torque off, PUW 210k, SOW 115k, ROT Wt 145k, 140 rpm -ART .93 hrs, ADT hrs, Bit 13.36 hrs -Slow pump rates taken and recorded -MW in 8.7 ppg, MW out 8.7 ppg -Background gas at 560 units -CBU after drilling every 2 stands Circulate bottoms up at 2850 gpm, 2385 psi, 140 rpm, 14k ft/Ibs torque. Background gas of 270 units at bottoms up. No increase of cuttings across shakers at bottoms up. Monitor well for 1 hr -static. POH from 15,918' to 15,745', pupming and pulling. Over pull to 25K. Began backreaming at 250 gpm, 1980 psi, 60 rpm, 9k ft/Ibs torque, ROT Wt 145k. Sudden loss of 700 psi and low PROD1 Printed: 7/16/2009 4:51:13 PM ~ • BP EXPLORATION Operations Summary Report Page 12 of 18 Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase ~', Description of Operations 6/23/2009 ~ 16:00 - 21:00 ~ 5.00 ~ DRILL ~ P ~ ~ PROD1 21:00 - 23:00 2.001 DRILL P PROD1 23:00 - 00:00 1.001 DRILL ~ P ~ ~ PROD1 6/24/2009 ~ 00:00 - 02:30 ~ 2.50 ~ DRILL ~ P ~ ~ PROD1 02:30 - 10:30 8.001 DRILL P PROD1 10:30 - 13:30 3.00 DRILL N DFAL PROD1 13:30 - 14:30 I 1.001 FISH I N I DFAL I PROD1 14:30 - 19:30 5.00 FISH N DFAL PROD1 19:30 - 21:00 1.501 FISH N DFAL PROD1 21:00 - 21:30 ~ 0.50 ~ FISH ~ N ~ DFAL ~ PROD1 21:30 - 00:00 2.501 FISH N ~ DFAL ~ PROD1 16/25/2009 00:00 - 10:00 ~ 10.001 FISH ~ N ~ DFAL ~ PROD1 of data from MW D tool. Check surface equipment, pits and IBOP. PUW 200k, SOW 120k. Suspect washout or CCV shift to open position. Continue to POH at 125 gpm, 890 psi to 11998'. -Background gas at 45-50 units while pumping and pulling out of hole from 1630 to 2300 hrs. -20-50 bbls/hr losses encountered while drilling ahead from_ 14703' to 15918' , -Total of 660 bbls lost to formation during this drilling and circulation period Monitor well at shoe for 2 hrs. Initial flow at 2.2 bbls in 10 min; slowed to 1.1 bbls in 20 min; .2 bbls in 40 min; average of 1 1/2 bbl/hr gain in pit volume. Flow never came to complete stop. Displace from 8.7 ppq to 9.0 ppq Flo-Pro at shoe at 125 gpm, ICP 650 psi. Displace from 8.7 ppg to 9.0 ppg Flo-Pro at 125 gpm, 480 psi. Background gas peaked at 1721 units at bottoms up and then went down to 20 units with continued circulation. Pump out of hole from 11988' to 5000' at 125 gpm, 448 psi. Background gas steady at 20 units during pumping out. Monitor well for 30 minutes at 5000 ;loss rate 18 bbls/hr. POH on elevators from 5000' to 3187' (top of 7" liner). Monitor well for 30 min; loss rate 18 bbls/hr. Continue POH from 3187' to 265'. LD HWDP, iars. BHA left in hole; pin broken on 15' lead DC. 189' of BHA left in hole: CCV circ sub and ball catcher, 3-NM flex DCs, ADN4 (SN 2281), Impulse MWD (SN 296), PD Flex sub, Receiver (SN CU-942), 6 1/8" PDC bit (SN 1218473). Top of fish estimated at 15556' md. Clear and clean rig floor. Consult with town, call out Baker Fishing. Wait on fishing tools. MU fishing assembly: 4 3/4" grapple overshot, bumper sub, oil jar, 7 jts 4" HWDP, intensifier jar, pump out sub. PUW 30k, SOW 30k. RIH with fishing BHA on 4" DP to 11988'. PUW 185k, SOW 125k. Circulate bottoms up at 250 gpm, 900 psi. Background gas at 6885 units with bottoms up; dropped to 10 units at end of circulation. Monitor well after circulation and during maintenance - 5.5 bbl loss in 30 min with no increase or decrease in units of gas. -MW in and out 9.0 ppg PJSM on cut and slip drilling line. Decision made to not cut and slip at this time due to high wind (gusting to 25 mph). Service topdrive, inspect drawworks, adjust brake, and inspect crown. RIH with fishing BHA on 4" DP to 14400'. Took 25 k at 14200'; PUW 200k, SOW 125k. Wash down and rotate from 14200' to 14400' at 260 gpm, 1290 psi, 40 rpm, 7-9k fUlbs torque. -18 bbls/hr average lost to well during trip into hole from surface to 14400 ;averaged 35-40 bbls/hr losses during wash and ream from 14200' to 14400'. Wash down and rotate from 14400' to 15560' at 225 gpm, 1300 Nnntea: mtiizuua o:oia~ rnn • ~ BP EXPLORATION Page 13 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To I! Hours Task Code NPT Phase I Description of Operations 6/25/2009 00:00 - 10:00 10.00 FISH N DFAL PROD1 psi, 40 rpm, 6-10k ft/Ibs torque, PUW 215k, SOW 120k, ROT Wt 140k. 45-50 bbls/hr lost during this hole section. 10:00 - 10:30 0.50 FISH N DFAL PROD1 A em t to en a e fish with and without rotation. No o. 10:30 - 11:00 0.50 FISH N DFAL PROD1 Monitor well for 30 minutes. Losing 18 bbls/hr. 11:00 - 12:30 1.50 FISH N DFAL PROD1 Pump Hi-Vis sweep around to clean above fish at 300 gpm, 1614 psi ICP, 1860 psi FCP, 30 rpm, 7.5k ft/Ibs torque, PUW 210k, SOW 120k, ROT Wt 145k. Sweep increased returns approximately 25% over shakers. Losses 15 bbls/hr during circulation. 12:30 - 18:00 5.50 FISH N DFAL PRODi Ba kream from 15548' to 11984' at 350 gpm, 1890 psi, 60 rpm, 7-9k fUlbs torque. Losses 52 bbls/hr for first 15 stands. Reduce rate to 300 gpm, 1360 psi; loss rate dropped to 22 bbls/hr. 18:00 - 18:30 0.50 FISH N DFAL PROD1 Monitor well at shoe for 30 minutes. Losses 15 bbls/hr. 18:30 - 00:00 5.50 FISH N DFAL PROD1 Pump out of hole from 11984' to 6544' at 250 gpm, 890 psi. Losses 12-15 bbls/hr during this interval. -Total losses to formation for day 1091 bbls „ 6/26/2009 00:00 - 03:30 3.50 FISH N DFAL PROD1 POH from 6544' to 195'. Losses 13 bbls/hr during this interval. 03:30 - 04:30 1.00 FISH N DFAL PROD1 LD fishing BHA. Inspect overshot assembly: cut lip guide and spiral grapple control missing grapple still in place. 04:30 - 05:00 0.50 FISH N DFAL PROD1 Clear and clean rig floor. Consult with town and Baker Fishing on plan forward. 05:00 - 06:00 1.00 FISH N DFAL PROD1 PJSM on cut and slip drilling line. Cut and slip 129' of drilling line. Inspect topdrive, drawworks and crown. 06:00 - 07:30 1.50 FISH N DFAL PROD1 Mobilize fishing tools to floor. MU burning shoe fishing BHA: Burning shoe (6" ODx4 3/4" ID), drive bushing, float, bumper sub, oil jar, pump out sub, 13 jts HWDP 07:30 - 12:00 4.50 FISH N DFAL PROD1 RIH with fishing BHA on 4" DP to 12074'. 12:00 - 13:00 1.00 FISH N DFAL PROD1 Circulate bottoms up at 300 gpm, 1080 psi. Monitor well - slight losses. 13:00 - 22:00 9.00 FISH N DFAL PROD1 RIH from 12074' to 13850'. Tag up with 20k down weight, PUW 45k over. Wash and rotate down from 13850' to 15560' at 250 gpm, 1200 psi, 25-50 rpm, 5.5-7.5k ft/Ibs torque, PUW 185k, SOW 120k, ROT Wt 150k. Tag fish at 15,560'. 22:00 - 00:00 2.00 FISH N DFAL PRODi Work string to get over fish with burning shoe at 15560', Work fish from 15560' to 15563' at 250 gpm, 1220 psi increase to 1380 psi when washing over fish, 60 rpm, 6-10k ft/Ibs torque, ROT Wt 150k, PUW 185k, SOW 120k -Losses 40-50 bbls/hr pumping during this period -Total lost to formation for 24 hour eriod - 944 bbls; losses 15 bbls/hr while not purring 6/27/2009 00:00 - 01:00 1.00 FISH N DFAL PRODi Continue to work over fish with burning shoe from 15,560' to 15,563' at 250 gpm, 1200 psi increasing to 1380 psi when washing over with burn shoe, 60 rpm, 6-10k ft/Ibs torque, ROT Wt 150k, PUW 185k, SOW 120k. Losses 50 bph during work on fish. 01:00 - 03:30 2.50 FISH N DFAL PROD1 Pump 30 bbl Hi-Vis sweep around at 300 gpm, 1400 psi. Losses 50 bbls/hr with circulation. Monitor well before POH - slight losses. 03:30 - 08:30 5.00 FISH N DFAL PROD1 Pump out of hole from 15,510' to 7" shoe at 12,074' at 250 gpm, 1100 psi, 50 rpm, PUW 200k, SOW 120k, ROT Wt 150k. Losses 45-50 bph while pumping out. Monitor well for 30 rrmtea: inoizuua n:oi:i~rrvi i BP EXPLORATION Page 14 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date ;From - To Hours I'~ Task Code NPT Phase Description of Operations 6/27/2009 03:30 - 08:30 5.00 FISH N DFAL PROD1 minutes -static losses 15 bph. 08:30 - 13:00 4.50 FISH N DFAL PRODi POH from 12,074' to 417' on elevators without pumps. Losses 15-20 bph. 13:00 - 14:00 1.00 FISH N DFAL PROD1 Stand back BHA, inspect burnshoe mill. Burnshoe cracked on d two distinct wear patterns inside top of drive sub indicatin that the fish was all the wa in. Consult with ODE and Anchorage team; decide to run overshot fishing assembly. Contact Baker Fishing for tool. 14:00 - 16:00 2.00 FISH N DFAL PROD1 Mobilize equipment to floor, MU 5 3/4" overshot with 4 3/4" grapple, circulation control sub, bumper sub, oil jar, 13 joints 4" HWDP, intensifier jar, pump out sub 16:00 - 20:30 4.50 FISH N DFAL PROD1 RIH with overshot fishin BHA on 4" DP to 7" shoe at 12,074'. Losses 20 bph while RIH. 20:30 - 21:30 1.00 FISH N DFAL PROD1 Cut and slip 61' of drilling line. Inspect drawworks, brake and crown, service topdrive. Circulate bottoms up at 280 gpm, 1000 psi. Monitor well -slight losses. 21:30 - 23:00 1.50 FISH N DFAL PROD1 Continue to RIH with no problems from 12,074' to 15,538'. 23:00 - 23:30 0.50 FISH N DFAL PROD1 Wash down from 15,538' to 15,558' with 240 gpm, 1215 psi, 25 rpm, 7k ft/Ibs torque, ROT Wt 145k to clear top of fish;,. Tag at 15,560'. PUW 190k, SOW 118k;aWork overshot over toa of fis rif fi h en a e .Establish circulation through fish at 195 gpm, 1525 psi. Losses 35 bph. 23:30 - 00:00 0.50 FISH N DFAL PROD1 Jar and work fish. Jar u on fish tripping jars at 300k, working up to 400k. Jar down with 75-90k with no success. Pumping at 190 gpm, 1450-1540 psi. Intermittent MWD signal. Losses 46 bph during jarring operation. -Total losses for day 782 bbls 6/28/2009 00:00 - 11:00 11.00 FISH N DFAL PROD1 Jar and work fish. PUW 325-400k, 100-200 gpm, 890-1600 psi. Losses 47-50 bbls/hr during jarring operation. 11:00 - 13:30 2.50 FISH N DFAL PROD1 Displace well from 9.0 ppg to 8.6 ppg Flo-Pro at 200 gpm, ICP 1650 psi, FCP 1550 psi. Losses 40-50 bph. 13:30 - 22:00 8.50 FISH N DFAL PROD1 Pump 30 bbls LVT (mineral oil); spot 15 bbls outside around fish. Jar and work fish up to 425k and bump down with no pumps. Fish moved 12' up on third jar. Periodically pump 1-2 bbls until all of LVT is outside pipe. Static losses 15-20 bph. 22:00 - 00:00 2.00 FISH N DFAL PROD1 Continue to jar and work fish up to 425k and bump down with different parameters. Vary circulation rate 100 gpm to 235 gpm, 770-2030 psi. PUW 210k, SOW 120k. Losses 45 bph. -Total daily losses to well 675 bbls 6/29/2009 00:00 - 01:00 1.00 FISH N DFAL PROD1 Jar and work fish, raising circulation rate from 235 gpm to 260 gpm, 2030-2600 psi. PUW 210k, SOW 120k. Apply torque to string, PU and SO to see if fish will rotate. Attempt several, times. No Go. Losses 50 bph. 01:00 - 02:30 1.50 FISH N DFAL PROD1 Work strin to release overshot ra le from fish. Gra le ressure drop from 1970 psi to 1330 psi to confirm release. Top of fish at 15,548'. Static losses 15 bph. 02:30 - 03:00 0.50 DRILL N DFAL PROD1 Monitor well for 30 minutes. Inspect topdrive, drawworks, brakes. Static losses 15 bph. 03:00 - 06:30 3.50 FISH N DFAL PROD1 Pump out of hole from 15,548' to 12,074' at 250 gpm, 985 psi. PUW 210k, SOW 120k. Losses 45-50 bph. 06:30 - 08:30 2.00 FISH N DFAL PROD1 Displace well from 8.6 ppg to 9.0 ppg at 250 gpm, 930 psi. Losses during displacement 45-50 bph. 08:30 - 14:30 6.00 FISH N DFAL PROD1 POH on elevators from 12074' to 11019'; losses 24 bph. Printetl: //1 fi/LUUy 4:51:1:1 YM • BP EXPLORATION Page 15 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To ~I Hours Task ', Code ~! NPT ~! Phase Description of Operations 6/29/2009 08:30 - 14:30 6.00 FISH N DFAL PROD1 Monitor well for 30 minutes- static losses 15 bph. Continue to POH to 430'. 14:30 - 16:00 ~ 1.50 ~ FISH N ~ DFAL ~ PROD1 16:00 - 18:30 I 2.501 BOPSUR P 18:30 - 23:00 I 4.501 BOPSUR P 23:00 - 00:00 I 1.001 BOPSUR P 6/30/2009 00:00 - 01:30 1.50 ~ CASE ~ P 01:30 - 06:00 I 4.501 CASE I P 06:00 - 11:00 5.00 CASE P 11:00 - 12:30 1.50 CASE P 12:30 - 15:30 I 3.001 CASE I P 15:30 - 16:00 0.50 CEMT P 16:00 - 18:30 2.50 CEMT P LD BHA. Inspect overshot grapple assembly. Grapples missing; debris from cut lip guide missing off of first overshot BHA stuck inside against top of overshot bowl. -189.23' of 6 1/8" drillin BHA left in hole: CCV circulation sub, 3 jts NM Flex DC, ADN4 (SN 2281), Impulse MWD (SN 296), PD Flex sub, Receiver (SN RCV-56604), Power Drive RSS (SN PD-56667-942), 6 1/8" Hycalog PDC bit MSX513M-A1B (SN 121843) PROD1 Clear and clean rig floor to prep for BOP test. Mobilize, RU BOP test equipment. Remove wear bushing. Replace gasket on test plug. PROD1 Test BOP a ui ment with 4 1/2" and 2 7/8" test joints to 250 psi low, 3500 psi high, 2500 psi for Annular. Test witnessed by AOGCC rep Chuck Scheve, Toolpusher Biff Perry and WSL Rob O'Neal. PRODi RD BOP test equipment, blow down lines, install wear bushing. Clear and clean rig floor. Mobilize liner running equipment to rig floor. -Total losses for day 530 bbls RUNPRD Mobilize liner running equipment to rig floor. RU liner running equipment. RUNPRD MU shoe tract for 4-1/2" production liner. Baker lock shoe tract; total length of shoe tract 129'. Check float -held. RIH with 4-1/2" 12.6# L-80 IBT-M liner. Average MU torque 3400k ft/Ibs. MU Baker Flex Lock liner hanger, ZXPN liner top packer with HRD running tool and cossover to 4" DP. Total of 86 joints, 162 centralizers (one each on jts 1-4, two each on jts 5-83) and 79 stop rings Qts 5-83). RUNPRD RIH liner on 4" DP to 7" shoe at 12 074'. RUNPRD Circulate bottoms up while staging pumps to 5 bpm. ICP 430 PU - 170k, SO - 125k. RUNPRD RIH from 12,074' to 15,527'. PU - 195k, SO - 120k. RUNPRD MU liner cement head. RUNPRD Wash to top of fish. Tag fish at 15,548' at 2.3 BPM 640 psi. Stage up to 4 BPM 920 psi and to 5 BPM 1126 psi. Circulate one annular volume. PJSM for cement job while circulating. 360 bbls of FloPro lost to well while RIH with 4-1/2" liner. 18:30 - 20:00 1.50 CEMT P RUNPRD Cement as per plan. Displace cement with 8.6 ppg mud. Slow pump to 3 BPM, bump plug with 3100 psi and set liner hanger. Set 63K down to confirm liner hager set. Pressure up to 4100 pis to release HRD running tool. Set down 20K to complete release of running tool. Bleed off pressure and check floats. Printetl: 7/16/2009 4:51:13 PM i ~ BP EXPLORATION Page 16 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To ~ Hours Task I Coded `NPT ~ Phase Description of Operations - _ _- -_ -- 6/30/2009 18:30 - 20:00 1.50 CEMT P RUNPRD Pick up 4.5' to release dogs, set down 65K to set ZXPN packer. Clear indication on surface of ZXPN setting. Repeat with rotation. 20:00 - 21:00 I 1.001 CEMT I P 21:00 - 21:30 0.50 CEMT P 21:30 - 23:00 1.50 CEMT P 23:00 - 00:00 1.00 CEMT P 7/1/2009 00:00 - 02:30 2.50 CEMT P 02:30 - 05:00 2.50 CEMT P 05:00 - 05:30 0.50 CEMT P 05:30 - 06:30 1.00 CEMT P 06:30 - 07:30 1.00 PERFO C 07:30 - 09:30 2.00 PERFO C 09:30 - 12:30 3.00 PERFO C 12:30 - 17:30 ~ 5.00 PERFOB~ C 17:30 - 18:00 I 0.501 PERFOBI C 18:00 - 19:00 I 1.001 PERFOBI C 19:00 - 20:00 1.00 PERFO~ C 20:00 - 00:00 4.00 PERFO C Stages: -4.9 bbls of 12.0 ppg MudPush, test lines to 4500 psi. -27.0 additional bbls of 12.0 ppg MudPush. -92.1 bbls of 15.8 ppg Class G cement w/ GasBlock (1.17 cuft/sk, 442 sks) -175 bbls of 8.6 ppg FloPro displacement Cement in place at 19:42 hrs. Liner top at 11,903' and shoe at 15,546x. Full returns throughout cement iob. RUNPRD Circulate out excess cement from top of liner at 512 gpm, 2538 psi. 20 bbls of cement and 31.9 bbls of MudPush recovered at surface. RUNPRD RD liner cementing equipment. RUNPRD Pump 40 bbl hi-vis spacer, 35 bbls fresh water spacer, and displace 8.6 ppg FloPro to 8.5 ppg seawater at 514 gpm, 2915 psi. RUNPRD POH from 11,903'to 10,680'. RUNPRD POH with 4" drillpipe and 4-1/2" liner running tools from 10,680' to 3714'. RUNPRD POH from 3714' to 40', laying down drill pipe singles. RUNPRD LD liner running tools, dog sub shear confirmed. Clean and clear rig floor. RUNPRD RU & test 4-1/2" liner to 3500 psi -good test. Lost 0 psi in 30 minutes. Bleed down and RD pressure testing equipment. OTHCMP RU to run 2-7/8" Fox i e and 2-7/8" TCP uns. PJSM. OTHCMP RIH 2-7/8" TCP guns assembly to 1600'. OTHCMP Change out handling equipment and RIH with 2-7/8" Fox pipe and TCP guns to 3640' from 1600'. Fox pipe torqued to 1910 ft-Ibs using double stack power tongs. OTHCMP RIH from 3640' to 15416' on 4" drillpipe. Tag landing collar at 15416' with 7k SO. PU - 185k, SO - 125k. OTHCMP Set TCP guns on depth and fire. Good indication of detonation on surface along with an immediate loss of 2 bbl. Perf intervals: 13,850' - 14,400': 550' 2906PJ 14,500' - 14,977': 477' 2906PJ 14,977' - 15,100': 123' 2906PJ OMEGA 15,150' - 15,400': 250' 2906PJ OMEGA All guns have 60 degree phasing, 6 spf. OTHCMP POH from 15400' to 13785'. Lose an additional 12 bbls while POH. OTHCMP Circulate bottoms u at 383 m 3026 si. No as or oil in returns. OTHCMP POH from 13785' to 9461' laying down drill pipe. rnn~ea: m orzuua as is i a rm i • BP EXPLORATION Page 17 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code I NPT ' Phase ~ Description of Operations I i 7/1/2009 20:00 - 00:00 4.00 PERFO C OTHCMP Monitor well at 2300 -static. 17 bbls of total losses since perforating. 7/2/2009 00:00 - 03:30 3.50 PERFO C OTHCMP POH 2-7/8" TCP gun assembly from 9461' to 3640' laying down drill pipe. 03:30 - 04:00 0.50 PERFO C OTHCMP RIH from 3640' to 5453' on drill pipe stands. 04:00 - 05:00 1.00 PERFO C OTHCMP POH from 5453' to 3640' laying down drill pipe. 05:00 - 06:00 1.00 PERFO C OTHCMP Cut and slip drilling line. Service top drive. 06:00 - 10:00 4.00 PERFO C OTHCMP Change out handling equipment for 2-7/8" Fox pipe. POH from 3640' to 1600' laying down 2-7/8" Fox pipe. 10:00 - 13:00 3.00 PERFO C OTHCMP PJSM. Change out handling equipment for 2-7/8" TCP guns. POH from 1600' to surface laying down 2-7/8" TCP gun assembly. Verifie all n fir ~ II 13:00 - 14:00 1.00 PERFO C OTHCMP LD 2-7/8" gun equipment and handling tools. Clean and clear rig floor. 14:00 - 16:00 2.00 BUNCO RUNCMP RU to run 4-172" 12.6# 13CR-80 VamTOP com letion. 16:00 - 00:00 8.00 BUNCO P RUNCMP RIH with 4-1/2" completion to 5068'. Average MU torque - 4440 ft-Ibs. 7/3/2009 00:00 - 07:30 7.50 BUNCO RUNCMP RIH with 4-1/2", 12.6#, 13CR-80, Vam Top completion from 5068' to 11914'. Tag no-go at 11914' with 7k SO. PU - 137k, SO - 100k. Average MU torque - 4440 ft-Ibs. 07:30 - 09:30 2.00 BUNCO P RUNCMP Space out 4-1/2" completion and land tubing hanger. Run in lock-down screws. Bottom of WLEG ~ 11907'; Top of XN nipple ~ 11894'. Top of X nipple #1 C~ 11821'. To of acker ~ 11788'. Top of X nipple #2 ~ 11757'. Top of GLM #1 ~ 11637'. Top of GLM #2 ~ 7738'. Top of GLM #3 @ 3720'. Top of X nipple #3 ~ 2180'. 09:30 - 13:00 3.50 BUNCO P RUNCMP Reverse circulate 179 bbls of clean seawater, 150 bbls of corrosion inhibited seawater, and 180 bbls of clean seawater at 3 bpm, 220 psi. 13:00 - 13:30 0.50 BUNCO RUNCMP Dro ball and roller rod ressure u tubin to 3500 si and set.. acker. 13:30 - 15:00 1.50 BUNCO P RUNCMP Test tubin to 3500 si for 30 minutes - ood test. 1st 15 min. lost 20 si 2nd 15 min -lost 0 si. Bleed tubin to 1500 si . and pressure annulus to 3500 psi for 30 minutes - aoodlest._ Lost 0 si in 30 minutes. Bleed annulus then tubing to zero psi. Pressure up on annulus to 3500 psi to shear DCK valve in GLM #3. Pump 2 bbls each way to confirm shear. 15:00 - 16:00 1.00 BUNCO RUNCMP Install TWC with dry rod. Test from below to 1000 psi for 5 minutes -good test. 16:00 - 17:30 1.50 BOPSU P RUNCMP ND BOPE. rriniea: nioicvva v:oi:ianw BP EXPLORATION Page 18 of 18 Operations Summary Report Legal Well Name: 18-29 Common Well Name: 18-29 Spud Date: 6/5/2009 Event Name: REENTER+COMPLETE Start: 6/2/2009 End: 7/4/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/4/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task I Code NPT ~ Phase Description of Operations P RUNCMP NU 4-1/16" tree and adapter flange. 7/3/2009 17:30 - 19:00 1.50 WHSUR _ - - - -- - 19:00 - 20:00 1.00 WHSUR P RUNCMP Test adapter flange void to 5000 psi for 30 minutes -good test. 20:00 - 20:30 0.501 WHSUR P 20:30 - 22:30 2.00 WHSUR ~ P 22:30 - 23:00 I 0.501 WHSUR I P 23:00 - 00:00 1.00 WHSUR P Bleed down adapter flange. Test tree with diesel to 5000 psi - good test. Bleed down tree. RUNCMP RU Drill Site Maintenance lubricator. Pull TWC. RD Drill Ste' RUNCMP RU Little Red Services -Hot Oil. Reverse circulate 151 bbls of diesel freez~rotect and allow to U-tube. Well freeze protected to 2200'. RUNCMP R Drill Site Maintenance lubricator. Install BPV and test from below to 1000 osi for 10 minutes. RD Drill Site Maintenance and Little Red Services. RUNCMP Secure tree and clean up cellar. Rig released from well at 23:59. rnnteo: intiizuua v:oi:~arm by DS18-29C Su Report Date: 23-Jun-09 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - EOA Structure I Slot: DS-18 / 18-29 Well: 18-29 Borehole: 18-29C UWIIAPI#: 500292231603 Survey Name /Date: 18-29C I June 23, 2009 Tort 1 AHD 1 DDI 1 ERD ratio: 403.056° / 10469.50 ft / 6.887 / 1.203 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaNLong: N 7017 46.819, W 148 26 51.640 Location Grid NIE YIX: N 5960392.230 ftUS, E 691687.700 ftUS Grid Convergence Angle: +1.46147282° Grid Scale Factor: 0.99994174 Resort Schlumberger Vertical Section Azimuth: 225.860° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 44.10 ft relative to MSL Sea Bed 1 Ground Level Elevation: 15.90 ft relative to MSL Magnetic Declination: 22.788° Total Field Strength: 57719.644 nT Magnetic Dip: 80.941 ° Declination Date: June 09, 2009 Magnetic Declination Model: BGGM 2008 North Reference: True North Total Corr Mag North •> True North: +22.788° Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft k de 1100 ft ftUS itUS Nrolectea-up u. uu u.uu U. UV -44. 1 V v. uu u. uv v. uV u.~u u. vu ~. vv v.w ~avwaL. Lo WRP 28. 20 0.00 0. 00 -15. 90 28. 20 0. 00 0. 00 0.00 0. 00 0. 00 0.00 5960392. 23 MWD 464. 20 0.38 277. 96 420. 10 464. 20 0. 89 1. 45 1.45 0. 20 -1. 43 0.09 5960392 .39 SPERRY 12/27/92 972. 74 0.67 253. 14 928. 62 972. 72 4. 57 6. 04 5.96 -0. 43 -5. 95 0.07 5960391 .65 1473. 74 0.30 153. 54 1429. 60 1473. 70 7. 57 9. 44 8.53 -2. 45 -8. 17 0.16 5960389 .57 1946. 03 0.79 147. 13 1901. 87 1945. 97 8. 58 13. 93 8.59 -6. 29 -5. 85 0.10 5960385 .79 2453. 09 0.74 141. 61 2408. 88 2452. 98 9. 59 20. 70 11.95 -11. 80 -1. 92 0.02 5960380 .39 2649. 99 0.26 111 .23 2605. 78 2649. 88 9. 53 22. 38 12.97 -12. 95 -0. 71 0.27 5960379 .26 2839. 53 3.70 232 .47 2795. 19 2839. 29 15. 43 28. 36 17.61 -16. 84 -5. 16 2.03 5960375 .27 3029. 67 5.48 230 .14 2984. 71 3028. 81 30. 58 43. 58 31.39 -26. 39 -17. 00 0.94 5960365 .41 Tie-In Survey 3221. 11 8.19 227 .67 3174. 77 3218 .87 53. 33 66. 35 53.66 -41. 44 -34 .10 1.42 5960349 .94 GYD GC SS 3374. 00 10.60 225 .58 3325. 60 3369 .70 78. 28 91. 30 78.48 -58. 61 -52 .19 1.59 5960332 .31 3391. 00 12.19 219 .05 3342. 27 3386 .37 81. 62 94. 66 81.84 -61. 10 -54 .44 12.04 5960329 .76 3403 .00 13.99 217 .38 3353. 96 3398 .06 84. 31 97. 38 84.55 -63. 24 -56 .12 15.33 5960327 .58 3433 .00 15.82 217 .22 3382. 95 3427 .05 91. 94 105. 09 92.25 -69. 38 -60 .80 6.10 5960321 .33 3465 .00 17.39 215 .45 3413. 61 3457 .71 100. 96 114. 24 101.36 -76. 75 -66 .21 5.15 5960313 .82 3496 .00 17.47 214 .76 3443. 19 3487 .29 110. 08 123 .52 110.60 -84. 34 -71 .55 0.71 5960306 .09 3528 .00 17.20 221 .48 3473. 74 3517 .84 119. 51 133 .05 120.11 -91. 83 -77 .42 6.31 5960298 .46 3560 .00 17.66 224 .76 3504. 27 3548 .37 129. 09 142 .63 129.68 -98. 83 -83 .97 3.39 5960291 .30 3592 .00 17.93 224 .65 3534. 74 3578 .84 138. 86 152 .41 139.44 -105. 78 -90 .85 0.85 5960284 .18 3624 .00 17.66 224 .65 3565. 21 3609 .31 148. 64 162 .19 149.19 -112. 73 -97 .72 0.84 5960277 .05 3655 .00 18.67 223 .30 3594. 66 3638 .76 158. 30 171 .85 158.85 -119. 69 -104 .43 3.53 5960269 .92 3684 .00 20.01 217 .43 3622. 03 3666 .13 167. 85 181 .45 168.44 -127. 01 -110 .63 8.14 5960262 .45 VAIVV/.IV IY /V 1/ 7V.V IJ YV I1V LV VI.V7V 691687.70 N 70 17 46.819 W 148 26 51.640 691686.26 N 70 17 46.821 W 148 26 51.682 691681.77 N 70 17 46.815 W 148 26 51.814 691679.60 N 70 17 46.795 W 148 26 51.879 691682.01 N 70 17 46.757 W 148 26 51.811 691686.08 N 70 17 46.703 W 148 26 51.696 691687.32 N 70 17 46.692 W 148 26 51.661 691682.97 N 70 17 46.654 W 148 26 51.791 691671.38 N 70 17 46.560 W 148 26 52.136 691654.67 N 70 17 46.412 W 148 26 52.634 691637.02 N 70 17 46.243 W 148 26 ~2 691634.84 N 70 17 46.218 W 148 26 7 691633.21 N 70 17 46.197 W 148 26 53.276 691628.70 N 70 17 46.137 W 148 26 53.412 691623.48 N 70 17 46.065 W 148 26 53.570 691618.33 N 70 17 45.990 W 148 26 53.726 691612.65 N 70 17 45.916 W 148 26 53.897 691606.28 N 70 17 45.847 W 148 26 54.088 691599.58 N 70 17 45.779 W 148 26 54.289 691592.89 N 70 17 45.711 W 148 26 54.489 691586.36 N 70 17 45.642 W 148 26 54.684 691580.35 N 70 17 45.570 W 148 26 54.865 SurveyEditor Ver SP 2.1 Bld( users) 18-29\18-29\18-29C\18-29C Generated 7/28/2009 10:48 AM Page 1 of 7 Comments Measured Inclination Azimuth Sub•Sea TVD ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Tnre Section Departure True North True North ft de de 8 k ft R R ft K de 1100 ft kUS ftUS I AA AI Y/\ AY A A07 \A/ A AO ~1C LG !\LY s/io.uv Lu.su cla.aa 30.7L.U/ JOyO.I/ I/Q./J I~L.V/ I/.7.YJ -IJV.00 -11/.LI I.~V :l.~VVL"JJ.YY V.71J/Y.VV IY /V 1/ YJ.YVJ YY ITV LV VJ.VJ/ 3748.00 21.40 212.20 3681.97 3726.07 189.87 203.86 190.74 -145.29 -123.58 5.34 5960243.84 691567.88 N 70 17 45.390 W 148 26 55.242 3780.00 22.19 206.32 3711.69 3755.79 201.24 215.73 202.39 -155.65 -129.37 7.25 5960233.34 691562.35 N 70 17 45.289 W 148 26 55.411 3811.00 22.51 203.32 3740.36 3784.46 212.24 227.52 213.80 -166.35 -134.31 3.82 5960222.52 691557.68 N 70 17 45.183 W 148 26 55.555 3842.00 23.75 201.84 3768.87 3812.97 223.42 239.69 225.51 -177.59 -138.99 4.42 5960211.16 691553.30 N 70 17 45.073 W 148 26 55.691 MWD+IFR+MS 3899.23 25.62 197.86 3820.87 3864.97 244.87 263.59 248.31 -200.07 -147.07 4.37 5960188.49 691545.79 N 70 17 44.852 W 148 26 55.927 3961.85 27.20 198.31 3876.95 3921.05 269.52 291.44 774.90 -226.55 -155.72 2.54 5960161.80 691537.82 N 70 17 44.591 W 148 26 56.179 4057.32 27.23 194.57 3961.86 4005.96 307.53 335.09 316.68 -268.40 -168.07 1.79 5960119.64 691526.54 N 70 17 44.180 W 148 26 56.539 ~ 4152.60 27.11 187.15 4046.65 4090.75 343.11 378.55 357.52 -311.05 -176.26 3.56 5960076.80 691519.44 N 70 17 43.760 W 148 26 56.778 4257.91 25.45 178.55 4141.11 4185.21 377.19 425.10 399.66 -357.50 -178.67 3.94 5960030.31 691518.22 N 70 17 43.303 W 148 26 56.848 4339.65 25.29 167.65 4215.01 4259.11 398.31 460.04 429.20 -392.13 -174.49 5.71 5959995.80 691523.28 N 70 17 42.963 W 148 26 56.726 4434.54 25.53 154.29 4300.79 4344.89 415.46 500.60 459.61 -430.39 -161.27 6.04 5959957.89 691537.47 N 70 17 42.587 W 148 26 1 4529.61 25.99 144.14 4386.45 4430.55 424.95 541.83 486.38 -465.75 -140.17 4.66 5959923.09 691559.46 N 70 17 42.239 W 148 26 6 9'71 4623.82 26.28 135.79 4471.06 4515.16 427.89 583.27 510.23 -497.44 -113.53 3.91 5959892.09 691586.90 N 70 17 41.927 W 148 26 54.949 4718.34 29.02 128.09 4554.80 4598.90 424.77 627.08 532.77 -526.59 -80.88 4.76 5959863.78 691620.28 N 70 17 41.640 W 148 26 53.998 4812.54 32.58 123.45 4635.72 4679.82 416.22 675.29 556.25 -554.68 -41.71 4.54 5959836.70 691660.15 N 70 17 41.364 W 148 26 52.856 4908.85 34.73 120.93 4715.88 4759.98 403.58 728.65 583.09 -583.08 3.46 2.66 5959809.46 691706.03 N 70 17 41.085 W 148 26 51.540 5004.32 39.23 115.63 4792.15 4836.25 386.12 786.04 612.53 -610.14 54.05 5.77 5959783.71 691757.29 N 70 17 40.819 W 148 26 50.065 5098.76 42.18 111.82 4863.74 4907.84 362.87 847.61 644.38 -634.85 110.43 4.08 5959760.44 691814.28 N 70 17 40.576 W 148 26 48.422 5192.87 44.92 108.55 4931.95 4976.05 334.75 912.44 679.13 -657.17 171.28 3.77 5959739.68 691875.67 N 70 17 40.356 W 148 26 46.648 5287.57 47.33 105.55 4997.59 5041.69 301.83 980.69 717.27 -677.15 236.54 3.42 5959721.38 691941.42 N 70 17 40.160 W 148 26 44.747 5381.75 49.88 102.00 5059.88 5103.98 264.28 1051.32 758.05 -693.92 305.14 3.91 5959706.36 692010.42 N 70 17 39.995 W 148 26 42.747 5476.14 52.03 99.50 5119.34 5163.44 222.10 1124.62 801.81 -707.57 377.15 3.07 5959694.55 692082.75 N 70 17 39.860 W 148 26 40.648 5571.20 55.66 96.39 5175.42 5219.52 174.92 1201.36 849.14 -718.13 453.15 4.64 5959685.94 692158.99 N 70 17 39.757 W 148 26 38.434 5666.68 58.83 94.53 5227.07 5271.17 122.87 1281.64 900.48 -725.74 533.07 3.70 5959680.36 692239.07 N 70 17 39.682 W 148 26 36.104 5760.81 61.87 91.33 5273.64 5317.74 67.14 1363.43 954.28 -729.89 614.74 4.38 5959678.30 692320.82 N 70 17 39.641 W 148 26 33.724 5855.56 66.18 88.51 5315.14 5359.24 5.93 1448.59 1011.11 -729.73 699.89 5.28 5959680.63 692405.93 N 70 17 39.642 W 148 26 31.242 5949.12 66.75 88.57 5352.50 5396.60 -57.13 1534.37 1070.77 -727.55 785.64 0.61 5959685.00 692491.59 N 70 17 39.664 W 148 26 28.743 6047.63 66.16 88.43 5391.85 5435.95 -123.56 1624.67 1137.15 -725.18 875.91 0.61 5959689.67 692581.77 N 70 17 39.687 W 148 26 26.112 6141.64 65.60 89.74 5430.27 5474.37 -186.09 1710.48 1203.65 -723.81 961.70 1.40 5959693.23 692667.49 N 70 17 39.700 W 148 26 ~2 6236.62 67.16 91.39 5468.33 5512.43 -247.93 1797.49 1274.74 -724.67 1048.71 2.29 5959694.58 692754.49 N 70 17 39.692 W 148 26 6 6331.14 67.51 91.69 5504.75 5548.85 -308.86 1884.72 1348.64 -727.02 1135.90 0.47 5959694.46 692841.71 N 70 17 39.668 W 148 26 18.535 6426.13 67.38 92.14 5541.18 5585.28 -369.74 1972.44 1424.77 -729.95 1223.58 0.46 5959693.77 692929.42 N 70 17 39.639 W 148 26 15.979 6519.13 66.91 89.48 5577.31 5621.41 -430.38 2058.14 1499.59 -731.16 1309.26 2.68 5959694.74 693015.10 N 70 17 39.627 W 148 26 13.482 6613.47 66.54 89.09 5614.59 5658.69 -493.32 2144.80 1575.31 -730.08 1395.91 0.55 5959698.03 693101.69 N 70 17 39.638 W 148 26 10.957 6707.58 65.79 88.98 5652.62 5696.72 -556.10 2230.88 1651.42 -728.63 1481.98 0.80 5959701.67 693187.70 N 70 17 39.652 W 148 26 8.448 6801.63 65.86 89.39 5691.13 5735.23 -618.52 7316.68 1728.31 -727.41 1567.78 0.40 5959705.08 693273.42 N 70 17 39.664 W 148 26 5.948 6895.37 66.64 90.83. 5728.89 5772.99 -679.97 2402.48 1806.57 -727.58 1653.57 1.63 5959707.10 693359.19 N 70 17 39.662 W 148 26 3.447 6990.51 67.17 89.56 5766.21 5810.31 -742.57 2490.00 1887.11 -727.88 1741.09 1.35 5959709.04 693446.68 N 70 17 39.659 W 148 26 0.897 7084.30 67.41 90.34 5802.42 5846.52 -804.71 2576.52 1967.19 -727.80 1827.60 0.81 5959711.32 693533.16 N 70 17 39.659 W 148 25 58.375 7179.30 66.14 89.72 5839.88 5883.98 -867.33 2663.81 2048.57 -727.85 1914.90 1.47 5959713.50 693620.43 N 70 17 39.659 W 148 25 55.831 SurveyEditor Ver SP 2.1 Bld( users) 18-29\18-29\18-29C\18-29C Generated 7/28/2009 10:48 AM Page 2 of 7 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftU5 7Z74.Z2 66.45 tfy.tf3 btf /tf.U4 6`JZY.l4 -yYy.y3 Z/OU./3 ClLy.yl -/G/.OI GVU 1.81 U.J9 aaaai Io.va oyJrui.JU rv iv li Ja.ooc vv IYO LJ AJ.L.`7O 7369.13 67.33 89.86 5915.29 5959.39 -992.74 2838.02 2212.08 -727.27 2089.11 0.93 5959718.52 693794.55 N 70 17 39.664 W 148 25 50.754 7463.60 65.33 89.76 5953.22 5997.32 -1055.03 2924.54 2293.87 -726.99 2175.62 2.12 5959721.01 693881.03 N 70 17 39.666 W 148 25 48.232 7559.75 66.13 89.86 5992.74 6036.84 -1118.14 3012.19 2377.08 -726.70 2263.27 0.84 5959723.53 693968.64 N 70 17 39.669 W 148 25 45.678 7653.96 66.64 90.06 6030.48 6074.58 -1180.12 3098.51 2459.39 -726.64 2349.59 0.58 5959725.80 694054.92 N 70 17 39.669 W 148 25 43.162 7747.99 66.98 89.08 6067.51 6111.61 -1242.60 3184.94 2541.90 -725.99 2436.02 1.02 5959728.65 694141.30 N 70 17 39.675 W 148 25 40.643 7843.33 67.12 88.46 6104.68 6148.78 -1306.90 3272.73 2625.62 -724.10 2523.80 0.62 5959732.77 694228.99 N 70 17 39.694 W 148 25 38.085 7938.30 67.05 88.54 6141.66 6185.76 -1371.25 3360.21 2709.17 -721.81 2611.24 0.11 5959737.29 694316.34 N 70 17 39.716 W 148 25 35.536 8032.83 67.51 88.93 6178.17 6222.27 -1435.15 3447.40 2792.79 -719.89 2698.41 0.62 5959741.44 694403.43 N 70 17 39.735 W 148 25 32.995 8127.29 66.77 89.52 6214.87 6258.97 -1498.43 3534.44 2876.67 -718.71 2785.45 0.97 5959744.84 694490.40 N 70 17 39.746 W 148 25 30.459 8222.17 64.91 90.88 6253.70 6297.80 -1560.34 3621.01 2960.64 -719.00 2872.01 2.36 5959746.75 694576.94 N 70 17 39.743 W 148 25 27.936 8316.00 65.61 91.59 6292.97 6337.07 -1620.20 3706.23 3043.79 -720.84 2957.20 1.01 5959747.08 694662.15 N 70 17 39.724 W 148 25 8410.26 66.36 90.49 6331.33 6375.43 -1680.90 3792.33 3127.85 -722.40 3043.29 1.33 5959747.72 694748.24 N 70 17 39.709 W 148 25 ~4 8503.54 66.65 89.67 6368.52 6412.62 -1742.20 3877.87 3211.17 -722.52 3128.83 0.86 5959749.78 694833.75 N 70 17 39.707 W 148 25 20.451 8598.12 67.14 90.95 6405.63 6449.73 -1804.30 3964.86 3296.10 -722.99 3215.82 1.35 5959751.53 694920.72 N 70 17 39.702 W 148 25 17.916 8693.83 67.82 90.55 6442.29 6486.39 -1866.94 4053.28 3382.65 -724.15 3304.23 0.81 5959752.63 695009.12 N 70 17 39.690 W 148 25 15.339 8788.30 68.14 87.67 6477.72 6521.82 -1930.72 4140.85 3467.94 -722.79 3391.78 2.85 5959756.22 695096.61 N 70 17 39.703 W 148 25 12.787 8882.44 68.08 87.56 6512.82 6556.92 -1995.89 4228.20 3552.61 -719.15 3479.06 0.13 5959762.08 695183.76 N 70 17 39.739 W 148 25 10.244 8977.49 67.68 87.22 6548.61 6592.71 -2061.80 4316.26 3638.00 -715.14 3567.02 0.54 5959768.33 695271.59 N 70 17 39.778 W 148 25 7.680 9070.91 67.11 86.44 6584.52 6628.62 -2126.92 4402.50 3721.56 -710.38 3653.13 0.98 5959775.29 695357.54 N 70 17 39.824 W 148 25 5.170 9163.68 66.78 85.68 6620.85 6664.95 -2192.12 4487.86 3804.10 -704.51 3738.29 0.83 5959783.33 695442.52 N 70 17 39.881 W 148 25 2.688 9257.11 66.15 86.18 6658.15 6702.25 -2257.67 4573.52 3887.00 -698.43 3823.73 0.83 5959791.59 695527.77 N 70 17 39.941 W 148 25 0.198 9351.46 67.13 83.49 6695.57 6739.67 -2325.00 4660.13 3970.51 -690.63 3909.98 2.82 5959801.59 695613.79 N 70 17 40.017 W 148 24 57.684 9446.35 68.10 83.13 6731.71 6775.81 -2394.66 4747.87 4054.62 -680.40 3997.13 1.08 5959814.03 695700.64 N 70 17 40.117 W 148 24 55.144 9539.73 67.60 82.57 6766.91 6811.01 -2463.74 4834.36 4137.49 -669.64 4082.94 0.77 5959826.98 695786.15 N 70 17 40.223 W 148 24 52.643 9633.03 68.31 84.89 6801.94 6846.04 -2531.99 4920.83 4220.85 -660.20 4168.89 2.43 5959838.60 695871.82 N 70 17 40.315 W 148 24 50.137 9727.63 67.98 83.71 6837.15 6881.25 -2600.76 5008.64 4305.83 -651.48 4256.26 1.21 5959849.55 695958.93 N 70 17 40.400 W 148 24 47.591 9823.28 68.27 86.38 6872.80 6916.90 -2669.55 5097.40 4392.12 -643.82 4344.68 2.61 5959859.46 696047.13 N 70 17 40.475 W 148 24 45.014 9917.78 67.82 85.64 6908.13 6952.23 -2736.55 5185.04 4477.76 -637.72 4432.11 0.87 5959867.79 696134.37 N 70 17 40.535 W 148 24 42.465 10012.22 67.26 86.85 6944.21 6988.31 -2803.02 5272.32 4563.18 -632.00 4519.20 1.32 5959875.73 696221.28 N 70 17 40.590 W 148 24 ~7 10107.02 66.45 87.49 6981.47 7025.57 -2868.50 5359.49 4648.83 -627.70 4606.26 1.06 5959882.25 696308.20 N 70 17 40.632 W 148 24 0 10200.93 66.03 86.36 7019.31 7063.41 -2933.30 5445.44 4733.28 -623.09 4692.09 1.19 5959889.05 696393.87 N 70 17 40.677 W 148 24 34.888 10295.53 66.71 88.51 7057.23 7101.33 -2998.13 5532.10 4818.61 -619.21 4778.66 2.20 5959895.13 696480.31 N 70 17 40.715 W 148 24 32.365 10389.77 66.05 87.29 7094.99 7139.09 -3062.25 5618.45 4903.80 -616.05 4864.95 1.38 5959900.49 696566.48 N 70 17 40.745 W 148 24 29.850 10483.41 67.29 86.95 7132.07 7176.17 -3126.89 5704.43 4988.47 -611.73 4950.82 1.37 5959907.00 696652.21 N 70 17 40.787 W 148 24 27.347 10578.52 66.52 86.78 7169.38 7213.48 -3192.91 5791.92 5074.60 -606.95 5038.18 0.83 5959914.01 696739.41 N 70 17 40.833 W 148 24 24.801 10674.46 65.54 87.00 7208.36 7252.46 -3259.04 5879.58 5160.96 -602.19 5125.71 1.04 5959920.99 696826.79 N 70 17 40.880 W 148 24 22.250 10770.10 65.00 85.13 7248.37 7292.47 -3325.38 5966.45 5246.36 -596.23 5212.37 1.86 5959929.16 696913.27 N 70 17 40.938 W 148 24 19.724 10863.93 64.32 84.82 7288.53 7332.63 -3391.18 6051.25 5329.47 -588.81 5296.85 0.78 5959938.74 696997.52 N 70 17 41.010 W 148 24 17.262 10957.92 63.66 85.81 7329.75 7373.85 -3456.40 6135.72 5412.40 -581.90 5381.03 1.18 5959947.78 697081.50 N 70 17 41.077 W 148 24 14.808 11052.73 61.91 85.50 7373.10 7417.20 -3521.18 6220.03 5495.32 -575.52 5465.10 1.87 5959956.31 697165.37 N 70 17 41.140 W 148 24 12.358 SurveyEditor Ver SP 2.1 Bld( users) 18-29\18-29\18-29C\18-29C Generated 7/28/2009 10:48 AM Page 3 of 7 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth TNe Section Departure True North True North ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS 11145.83 59.08 85.57 7418.95 7463.05 -3583.54 6301.05 5575.01 -569.21 5545.87 3.04 5959964.68 697245.95 N 70 17 41 .201 W 148 24 10.003 11241.02 56.32 87.00 7469.81 7513.91 -3644.79 6381.50 5654.35 -563.98 5626.15 3.17 5959971.95 697326.07 N 70 17 41 .252 W 148 24 7.663 11336.61 52.89 87.75 7525.17 7569.27 -3703.13 6459.41 5731.44 -560.40 5703.98 3.64 5959977.51 697403.77 N 70 17 41 .287 W 148 24 5.395 11431.50 47.80 89.37 7585.71 7629.81. -3756.83 6532.44 5803.92 -558.53 5776.98 5.52 5959981.25 697476.70 N 70 17 41 .304 W 148 24 3.267 11526.67 42.43 87.70 7652.85 7696.95 -3806.35 6599.84 5870.83 -556.85 5844.36 5.78 5959984.64 697544.01 N 70 17 41 .320 W 148 24 1.303 11620.81 36.58 87.32 7725.45 7769.55 -3851.07 6659.70 5930.13 -554.26 5904.17 6.22 5959988.75 697603.73 N 70 17 41 .345 W 148 23 59.560 11714.27 32.13 86.93 7802.59 7846.69 -3890.70 6712.43 5982.32 -551.63 5956.83 4.77 5959992.73 697656.30 N 70 17 41 .371 W 148 23 58.025 11809.60 28.95 87.07 7884.68 7928.78 -3927.18 6760.87 6030.25 -549.09 6005.20 3.34 5959996.50 697704.59 N 70 17 41 .396 W 148 23 56.616 11903.41 28.90 88.59 7966.79 8010.89 -3960.91 6806.24 6075.24 -547.37 6050.53 0.79 5959999.37 697749.86 N 70 17 41 .412 W 148 23 55.294 11999.04 30.19 91.37 8049.99 8094.09 -3994.74 6853.38 6122.20 -547.38 6097.68 1.97 5960000.57 697796.99 N 70 17 41 .412 W 148 23 53.920 12013.17 30.47 90.92 8062.19 8106.29 -3999.76 6860.52 6129.31 -547.52 6104.81 2.55 5960000.61 697804.12 N 70 17 41 .410 W 148 23 53.712 12053.72 30.09 90.48 8097.20 8141.30 -4014.25 6880.97 6149.70 -547.77 6125.26 1.09 5960000.88 697824.56 N 70 17 41 .408 W 148 23 ~6 12145.78 29.99. 89.48 8176.90 8221.00 -4047.34 6927.05 6195.60 -547.76 6171.34 0.55 5960002.07 697870.63 N 70 17 41 .407 W 148 23 3 12237.50 29.13 89.27 8256.68 8300.78 -4080.15 6972.30 6240.63 -547.27 6216.59 0.94 5960003.72 697915.85 N 70 17 41 .412 W 148 23 50.455 12328.31 28.76 87.26 8336.15 8380.25 -4112.59 7016.24 6284.27 -545.94 6260.51 1.15 5960006.16 697959.72 N 70 17 41 .424 W 148 23 49.174 12390.70 29.00 89.07 8390.78 8434.88 -4134.88 7046.38 6314.19 -544.98 6290.62 1.45 5960007.89 697989.80 N 70 17 41 .434 W 148 23 48.297 12421.67 32.02 90.22 8417.46 8461.56 -4146.22 7062.10 6329.84 -544.89 6306.34 9.93 5960008.39 698005.51 N 70 17 41 .434 W 148 23 47.838 12453.50 34.47 92.31 8444.08 8488.18 -4158.46 7079.54 6347.25 -545.28 6323.79 8.50 5960008.44 698022.95 N 70 17 41 .430 W 148 23 47.330 12484.48 37.66 94.95 8469.12 8513.22 -4170.70 7097.78 6365.48 -546.45 6341.98 11.45 5960007.73 698041.17 N 70 17 41 .419 W 148 23 46.800 12512.09 40.92 95.89 8490.48 8534.58 -4182.04 7115.26 6382.96 -548.11 6359.38 12.00 5960006.52 698058.61 N 70 17 41 .402 W 148 23 46.293 12546.12 44.52 93.98 8515.48 8559.58 -41.97.17 7138.34 6406.04 -550.08 6382.38 11.24 5960005.13 698081.65 N 70 17 41 .383 W 148 23 45.623 12576.13 47.54 93.49 8536.31 8580.41 -4211.66 7159.94 6427.63 -551.48 6403.93 10.13 5960004.28 698103.22 N 70 17 41 .369 W 148 23 44.995 12607.48 51.07 93.80 8556.75 8600.85 -4227.62 7183.70 6451.39 -553.00 6427.65 11.28 5960003.37 698126.97 N 70 17 41 ,354 W 148 23 44.303 12639.34 55.13 94.60 8575.88 8619.98 -4244.55 7209.17 6476.86 -554.87. 6453.05 12.90 5960002.15 698152.41 N 70 17 41 .335 W 148 23 43.563 12669.66 58.37 94.49 8592.50 8636.60 -4261.29 7234.53 6502.21 -556.88 6478.32 10.69 5960000.79 698177.73 N 70 17 41 .315 W 148 23 42.826 12700.44 62.11 92.94 8607.78 8651.88 -4279.22 7261.24 6528.92 -558.60 6504.98 12.91 5959999.74 698204.42 N 70 17 41 .298 W 148 23 42.049 7" @ 12074'md 12731.27 65.96 91.06 8621.27 8665.37 -4298.43 7288.95 6556.60 -559.56 6532.68 13.64 5959999.49 698232.13 N 70 17 41 .288 W 148 23 41.242 12762.81 69.44 91.22 8633.24 8677.34 -4318.96 7318.13 6585.71 -560.14 6561.85 11.04 5959999.65 698261.30 N 70 17 41 282 W 148 23 40.392 12794.68 73.87 90.72 8643.27 8687.37 -4340.30 7348.37 6615.88 -560.65 6592.08 13.98 5959999.91 698291.54 N 70 17 41 .277 W 148 23 39.511 12825.46 77.76 87.64 8650.81 8694.91 -4362.01 7378.21 6645.57 -560.22 6621.91 15.93 5960001.11 698321.35 N 70 17 41 .281 W 148 23 ~1 12854.70 81.42 87.31 8656.09 8700.19 -4383.51 7406.96 6674.09 -558.95 6650.64 12.57 5960003.11 698350.03 N 70 17 41 .293 W 148 23 37.804 12885.63 85.70 88.24 8659.56 8703.66 -4406.37 7437.69 6704.58 -557.76 6681.34 14.16 5960005.08 698380.69 N 70 17 41 .305 W 148 23 36.909 12917.96 89.74 88.42 8660.85 8704.95 -4430.19 7469.99 6736.68 -556.82 6713.63 12.51 5960006.85 698412.94 N 70 17 41 .314 W 148 23 35.968 12948.92 92.14 89.76 8660.34 8704.44 -4452.75 7500.94 6767.48 -556.33 6744.58 8.88 5960008.13 698443.86 N 70 17 41 .318 W 148 23 35.066 12980.51 92.66 90.55 8659.02 8703.12 -4475.34 7532.50 6798.94 -556.41 6776.14 2.99 5960008.85 698475.42 N 70 17 41 .317 W 148 23 34.146 13010.82 93.66 91.15 8657.35 8701.45 -4496.74 7562.77 6829.14 -556.86 6806.40 3.85 5960009.17 698505.68 N 70 17 41 .312 W 148 23 33.264 13042.11 91.25 89.69 8656.01 8700.11 -4519.01 7594.03 6860.31 -557.09 6837.66 9.00 5960009.74 698536.93 N 70 17 41 .310 W 148 23 32.353 13073.66 90.26 90.23 8655.59 8699.69 -4541.67 7625.57 6891.75 -557.07 6869..20 3.57 5960010.56 698568.46 N 70 17 41 .310 W 148 23 31.434 13094.72 90.43 90.31 8655.46 8699.56 -4556.71 7646.63 6912.75 -557.17 6890.26 0.89 5960011.00 698589.52 N 70 17 41 .309 W 148 23 30.820 13102.86 90.00 89.64 8655.43 8699.53 -4562.56 7654.77 6920.87 -557.16 6898.40 9.78 5960011.21 698597.65 N 70 17 41 .309 W 148 23 30.583 SurveyEditor Ver SP 2.1 Bld( users) 18-29\18-29\18-29C\18-29C Generated 7/28/2009 10:48 AM Page 4 of 7 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS 1;31ti/.t35 13198.11 13229.01 13261.37 13290.89 13322.25 13353.14 13382.79 13414.10 13446.29 13477.36 13507.22 13538.34 13568.00 13599.61 13630.30 13660.22 13691.59 13723.47 13753.80 13784.78 13816.59 13847.32 13878.41 13909.63 13940.17 13969.87 14001.11 14031.51 14074.26 14094.71 14124.28 14154.74 14186.24 14217.67 14249.61 14281.24 14312.97 14344.98 14377.29 14409.05 au.1 a 91.27 91.20 91.10 90.45 90.27 90.24 90.82 90.79 90.89 90.89 90.41 90.13 89.52 90.07 89.89 89.21 88.59 88.76 89.07 89.11 89.04 89.28 89.65 90.37 89.36 89.96 90.03 89.76 90.17 90.61 91.61 91.33 90.79 90.27 90.24 89.96 90.24 91.06 90.92 90.48 tst:. i i 87.84 86.84 85.90 84.99 84.01 83.06 82.85 82.63 82.41 83.49 84.54 85.62 87.80 89.59 90.39 92.70 92.29 92.41 91.96 90.93 89.11 88.00 88.04 89.00 87.47 86.65 85.70 85.08 82.72 83.29 82.83 81.81 81.81 81.21 83.00 83.73 83.24 83.73 83.66 83.73 if655.J5 8654.98 8654.31 8653.67 8653.27 8653.07 8652.93 8652.66 8652.22 8651.75 8651.26 8650.92 8650.78 8650.87 8650.98 8650.99 8651.23 8651.83 8652.57 8653.14 8653.63 8654.15 8654.60 8654.89 8654.88 8654.95 8655.13 8655.13 8655.19 8655.21 8655.08 8654.50 8653.72 8653.14 8652.85 8652.71 8652.65 8652.59 8652.23 8651.67 8651.29 iSbyy RS -4vua.a< 8699.08 -4632.15 8698.41 -4655.29 8697.77 -4679.89 8697.37 -4702.64 8697.17 -4727.13 8697.03 -4751.58 8696.76 -4775.23 8696.32 -4800.27 8695.85 -4826.09 8695.36 -4850.87 8695.02 -4874.35 8694.88 -4898.46 8694.97 -4920.89 8695.08 -4944.07 8695.09 -4966.10 8695.33 -4987.00 8695.93 -5008.53 8696.67 -5030.48 8697.24 -5051.42 8697.73 -5073.10 8698.25 -5095.91 8698.70 -5118.49 8698.99 -5141.54 8698.98 -5164.50 8699.05 -5187.06 8699.23 -5209.40 8699.23 -5233.23 8699.29 -5256.67 8699.31 -5290.34 8699.18 -5306.64 8698.60 -5330.19 8697.82 -5354.68 8697.24 -5380.17 8696.95 -5405.71 8696.81 -5431.47 8696.75 -5456.56 8696.69 -5481.69 8696.33 -5507.04 8695.77 -5532.56 8695.39 -5557.64 ina.iv 7750.02 7780.91 7813.27 7842.78 7874.14 7905.03 7934.68 7965.99 7998.17 8029.24 8059.10 8090.22 8119.88 8151.49 8182.18 8212.10 8243.46 8275.33 8305.66 8336.63 8368.44 8399.17 8430.25 8461.47 8492.01 8521.71 8552.95 8583.35 8626.10 8646.55 8676.12 8706.57 8738.06 8769.49 8801.43 8833.06 8864.79 8896.80 8929.10 8960.86 oyav.v r 7015.64 7046.29 7078.32 7107.48 7138.37 7168.71 7197.77 7228.45 7259.96 7290.44 7319.83 7350.57 7379.98 7411.45 7442.07 7471.96 7503.31 7535.17 7565.48 7596.42 7628.15 7658.74 7689.67 7720.75 7751.14 7780.63 7811.60 7841.67 7883.79 7903.88 7932.94 7962.80 7993.63 8024.37 8055.68 8086.82 8118.08 8149.61 8181.46 8212.77 -vvv.Lo -555.37 -553.93 -551.88 -549.54 -546.53 -543.06 -539.42 -535.46 -531.27 -527.46 -524.35 -521.68 -519.98 -519.26 -519.25 -520.06 -521.42 -522.73 -523.89 -524.67 -524.68 -523.90 -522.83 -522.02 -521.08 -519.56 -517.47 -515.03 -510.49 -508.00 -504.43 -500.36 -495.87 -491.23 -486.84 -483.19 -479.59 -475.96 -472.41 -468.92 oyva~o 6993.63 7024.49 7056.78 7086.20 7117.41 7148.11 7177.53 7208.59 7240.50 7271.33 7301.03 7332.03 7361.64 7393.24 7423.93 7453.84 7485.17 7517.01 7547.32 7578.28 7610.09 7640.80 7671.87 7703.08 7733.61 7763.27 7794.44 7824.74 7867.24 7887.54 7916.89 7947.06 7978.24 8009.32 8040.96 8072.37 8103.90 8135.70 8167.81 8199.38 i av v5ouu 1 J. r / 4.84 5960015.44 3.24 5960017.66 2.92 5960020.53 3.79 5960023.62 3.18 5960027.42 3.08 5960031.68 2.08 5960036.07 0.71 5960040.82 0.75 5960045.82 3.48 5960050.42 3.87 5960054.28 3.59 5960057.74 7.63 5960060.20 5.92 5960061.73 2.67 5960062.51 8.05 5960062.47 2.37 5960061.90 0.65 5960061.41 1.80 5960061.03 3.33 5960061.04 5.72 5960061.84 3.70 5960063.39 1.20 5960065.26 3.84 5960066.86 6.00 5960068.58 3.42 5960070.86 3.05 5960073.74 2.22 5960076.95 5.60 5960082.58 3.52 5960085.58 3.72 5960089.90 3.47 5960094.74 1.71 5960100.02 2.53 5960105.45 5.60 5960110.64 2.47 5960115.10 1.78 5960119.50 2.98 5960123.94 0.48 5960128.31 1.40 5960132.60 0.70VVL.:1.7 IV /V 1! YI.JI/ VY IYV GJ LV.VV.7 698692.80 N 70 17 41.325 W 148 23 27.808 698723.61 N 70 17 41.339 W 148 23 26.908 698755.83 N 70 17 41.359 W 148 23 25.967 698785.18 N 70 17 41.382 W 148 23 25.109 698816.31 N 70 17 41.411 W 148 23 24.199 698846.90 N 70 17 41.445 W 148 23 23.305 698876.22 N 70 17 41.481 W 148 23 22.447 698907.16 N 70 17 41.519 W 148 23 21.542 698938.96 N 70 17 41.560 W 148 23 20.612 698969.68 N 70 17 41.597 W 148 23 19.713 698999.28 N 70 17 41.628 W 148 237 699030.21 N 70 17 41.654 W 148 23 4 699059.76 N 70 17 41.670 W 148 23 1 699091.33 N 70 17 41.677 W 148 23 16.160 699122.01 N 70 17 41.677 W 148 23 15.265 699151.92 N 70 17 41.668 W 148 23 14.394 699183.28 N 70 17 41.655 W 148 23 13.480 699215.15 N 70 17 41.641 W 148 23 12.552 699245.47 N 70 17 41.630 W 148 23 11.669 699276.44 N 70 17 41.622 W 148 23 10.767 699308.23 N 70 17 41.621 W 148 23 9.840 699338.92 N 70 17 41.629 W 148 23 8.944 699369.95 N 70 17 41.639 W 148 23 8.039 699401.13 N 70 17 41.647 W 148 23 7.129 699431.61 N 70 17 41.655 W 148 23 6.239 699461.22 N 70 17 41.670 W 148 23 5.375 699492.33 N 70 17 41.690 W 148 23 4.466 699522.56 N 70 17 41.714 W 148 23 3.583 699564.93 N 70 17 41.758 W 148 23 2.344 ~ 699585.15 N 70 17 41.783 W 148 2 3 699614.40 N 70 17 41.817 W 148 23 0.897 699644.46 N 70 17 41.857 W 148 23 0.018 699675.51 N 70 17 41.901 W 148 22 59.109 699706.46 N 70 17 41.946 W 148 22 58.203 699737.97 N 70 17 41.989 W 148 22 57.281 699769.29 N 70 17 42.025 W 148 22 56.365 699800.71 N 70 17 42.060 W 148 22 55.446 699832.40 N 70 17 42.095 W 148 22 54.519 699864.41 N 70 17 42.130 W 148 22 53.583 699895.87 N 70 17 42.164 W 148 22 52.663 SurveyEditor Ver SP 2.1 Bld( users) 18-29\18-29\18-29C\18-29C Generated 7/28/2009 10:48 AM Page 5 of 7 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Ttie Section Departure True North True North ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS -14441.UU `.7V.LV 84.00 00.71.IV 00.7:7.GV -:7:lVC./Y O.~aG.VI VGYY.JV -TVJ.Va VLJ 1. 'v ~.~v.v~ ---c~. c ~~ ~v ~~ ~c.~vv •• ~~~cr-v~.~v~ 14473.23 90.55 85.73 8650.88 8694.98 -5607.62 9025.04 8276.24 -463.00 8263.28 3.44 5960140.15 699959.60 N 70 17 42.221 W 148 22 50.800 14504.96 90.62 88.93 8650.56 8694.66 -5631.39 9056.77 8307.80 -461.52 8294.97 10.09 5960142.43 699991.24 N 70 17 42235 W 148 22 49.876 14536.72 89.65 88.71 8650.49 8694.59 -5654.63 9088.53 8339.46 -460.87 8326.72 3.13 5960143.90 700022.96 N 70 17 42.241 W 148 22 48.951 14568.80 88.83 87.26 8650.91 8695.01 -5678.42 9120.60 8371.41 -459.74 8358.78 5.19 5960145.84 700054.98 N 70 17 42.252 W 148 22 48.017 14600.20 88.32 85.91 8651.69 8695.79 -5702.21 9151.99 8402.59 -457.87 8390.11 4.59 5960148.51 700086.25 N 70 17 42.270 W 148 22 47.103 14631.69 88.32 87.88 8652.62 8696.72 -5725.95 9183.47 8433.88 -456.17 8421.54 6.25 5960151.02 700117.63 N 70 17 42.287 W 148 22 46.187 14664.43 88.94 86.51 8653.40 8697.50 -5750.53 9216.20 8466.44 -454.56 8454.23 4.59 5960153.45 700150.26 N 70 17 42.302 W 148 22 45.234 14696.59 89.69 84.29 8653.78 8697.88 -5775.33 9248.36 8498.31 -451.99 8486.28 7.29 5960156.85 700182.24 N 70 17 42.327 W 148 22 44.300 14728.03 90.58 84.39 8653.71 8697.81 -5799.94 9279.80 8529.39 -448.88 8517.57 2.85 5960160.74 700213.43 N 70 17 42.357 W 148 22 43.388 14760.42 90.58 83.84 8653.38 8697.48 -5825.37 9312.18 8561.39 -445.56 8549.78 1.70 5960164.88 700245.55 N 70 17 42.389 W 148 22 42.449 14792.32 90.55 86.13 8653.07 8697.17 -5850.12 9344.08 8592.97 -442.78 8581.56 7.18 5960168.48 700277.24 N 70 17 42.417 W 148 22 3 14823.84 89.96 87.09 8652.93 8697.03 -5873.99 9375.60 8624.30 -440.91 8613.02 3.57 5960171.15 700308.65 N 70 17 42.435 W 148 22 6 14855.72 89.69 88.58 8653.02 8697.12 -5897.69 9407.48 8656.05 -439.71 8644.88 4.75 5960173.16 700340.46 N 70 17 42.446 W 148 22 7 14887.66 89.34 88.44 8653.29 8697.39 -5921.19 9439.42 8687.90 -438.88 8676.81 1.18 5960174.81 700372.35 N 70 17 42.454 W 148 22 38.747 14919.26 90.34 89.06 8653.38 8697.48 -5944.34 9471.02 8719.42 -438.19 8708.40 3.72 5960176.30 700403.92 N 70 17 42.460 W 148 22 37.826 14951.53 90.34 88.54 8653.19 8697.29 -5967.96 9503.29 8751.60 -437.51 8740.66 1.61 5960177.80 700436.15 N 70 17 42.467 W 148 22 36.885 14983.51 88.73 84.69 8653.45 8697.55 -5992.18 9535.27 8783.39 -435.62 8772.58 13.05 5960180.50 700468.00 N 70 17 42.485 W 148 22 35.955 15015.45 87.85 82.61 8654.40 8698.50 -6017.41 9567.19 8814.90 -432.09 8804.31 7.07 5960184.84 700499.63 N 70 17 42.519 W 148 22 35.030 15047.65 88.73 83.98 8655.36 8699.46 -6042.96 9599.38 8846.65 -428.34 8836.27 5.06 5960189.41 700531.49 N 70 17 42.556 W 148 22 34.099 15078.76 89.59 85.97 8655.82 8699.92 -6067.10 9630.49 8877.46 -425.61 8867.25 6.97 5960192.93 700562.39 N 70 17 42.582 W 148 22 33.195 15110.78 89.48 85.48 8656.08 8700.18 -6091.67 9662.50 8909.24 -423.22 8899.18 1.57 5960196.13 700594.25 N 70 17 42.605 W 148 22 32.265 15143.07 89.52 85.92 8656.36 8700.46 -6116.47 9694.79 8941.29 -420.80 8931.38 1.37 5960199.37 700626.37 N 70 17 42.629 W 148 22 31.326 15174.63 91.23 85.81 8656.16 8700.26 -6140.64 9726.35 8972.62 -418.53 8962.86 5.43 5960202.44 700657.78 N 70 17 42.651 W 148 22 30.409 15206.29 92.23 84.56 8655.20 8699.30 -6165.12 9758.00 9004.00 -415.87 8994.39 5.05 5960205.90 700689.23 N 70 17 42.676 W 148 22 29.490 15238.82 91.27 83.35 8654.21 8698.31 -6190.71 9790.51 9036.14 -412.45 9026.72 4.75 5960210.15 700721.46 N 70 17 42.710 W 148 22 28.547 15269.18 90.00 80.27 8653.87 8697.97 -6215.28 9820.87 9065.96 -408.12 9056.77 10.97 5960215.24 700751.39 N 70 17 42.752 W 148 22 27.671 15301.50 88.45 78.86 8654.31 8698.41 -6242.16 9853.18 9097.45 -402.27 9088.55 6.48 5960221.90 700783.00 N 70 17 42.809 W 148 22 26.745 15333.06 88.22 76.85 8655.22 8699.32 -6268.92 9884.73 9127.97 -395.63 9119.39 6.41 5960229.32 700813.66 N 70 17 42.874 W 148 22 25.846 15365.01 89.11 75.57 8655.97 8700.07 -6296.48 9916.67 9158.63 -388.02 9150.41 4.88 5960237.72 700844.48 N 70 17 42.948 W 148 22 ~1 15396.26 89.00 73.34 8656.48 8700.58 -6323.91 9947.92 9188.36 -379.65 9180.51 7.14 5960246.86 700874.35 N 70 17 43.030 W 148 22 ~4 15428.09 88.63 74.22 8657.14 8701.24 -6352.03 9979.74 9218.52 -370.76 9211.07 3.00 5960256.53. 700904.67 N 70 17 43.117 W 148 22 23.173 15459.43 87.40 73.40 8658.23 8702.33 -6379.70 10011.06 9248.23 -362.03 9241.14 4.72 5960266.02 700934.51 N 70 17 43.203 W 148 22 22.296 15490.94 87.80 72.27 8659.55 8703.65 -6407.75 10042.54 9277.93 -352.74 9271.22 3.80 5960276.08 700964.34 N 70 17 43.294 W 148 22 21.419 15523.72 88.63 71.64 8660.57 8704.67 -6437.18 10075.31 9308.68 -342.59 9302.37 3.18 5960287.02 700995.23 N 70 17 43.393 W 148 22 20.510 15555.27 89.52 69.60 8661.08 8705.18 -6465.82 10106.85 9338.04 -332.12 9332.13 7.05 5960298.24 701024.70 N 70 17 43.496 W 148 22 19.643 15587.36 90.20 68.26 8661.16 8705.26 -6495.34 10138.94 9367.56 -320.58 9362.08 4.68 5960310.53 701054.34 N 70 17 43.609 W 148 22 18.770 15619.62 90.41 66.98 8660.98 8705.08 -6525.30 10171.20 9396.96 -308.30 9391.90 4.02 5960323.57 701083.85 N 70 17 43.730 W 148 22 17.900 15651.05 90.03 66.68 8660.86 8704.96 -6554.65 10202.63 9425.45 -295.93 9420.80 1.54 5960336.67 701112.41 N 70 17 43.851 W 148 22 17.057 15682.34 89.72 66.49 8660.93 8705.03 -6583.92 10233.92 9453.76 -283.50 9449.51 1.16 5960349.83 701140.80 N 70 17 43.973 W 148 22 16.220 15714.60 88.56 66.38 8661.42 8705.52 -6614.12 10266.18 9482.94 -270.60 9479.08 3.61 5960363.48 701170.02 N 70 17 44.099 W 148 22 15.358 SurveyEditor Ver SP 2.1 Bld( users) 18-29\18-29\18-29C\18-29C Generated 7/28/2009 10:48 AM Page 6 of 7 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS 15/4b./5 if`J.325 bbAb ifOOl.yy 8/UO.V`J -0044.LV IULyOAG yaIL.V4 -LO/.l/ 7~uo.aa LAI aaovo//.vv 15777.50 90.00 65.78 8662.16 8706.26 -6673.04 10329.07 9539.83 -245.35 9536.68 3.24 5960390.19 15809.41 90.96 65.07 8661.89 8705.99 -6703.11 10360.98 9568.51 -232.08 9565.70 3.74 5960404.20 15839.23 91.37 65.04 8661.29 8705.39 -6731.26 10390.79 9595.24 -219.50 9592.73 1.38 5960417.46 15870.28 92.33 64.76 8660.28 8704.38 -6760.60 10421.83 9623.04 -206.34 9620.83 3.22 5960431.33 Last Survey 15880.84 92.50 64.99 8659.84 8703.94 -6770.57 10432.38 9632.50 -201.86 9630.38 2.71 5960436.05 TD (Projected) 15918.00 92.50 64.99 8658.22 8702.32 -6805.65 10469.50 9665.82 -186.16 9664.03 0.00 5960452.60 Survey Type: Definitive Survey NOTES: MWD - (MWD -Standard -- Measurement While Drilling with no (or no known) special corrections. The model allows for the fact that axial \ interference may marginally exceed the upper limit specified when the well is near horizontal east/west. ) GYD GC SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Descriation: Northing (YI fftUSl Easting IX) fftUSl Surface : 3805 FSL 86 FEL S24 T11 N R14E UM 5960392.23 691687.70 BHL : 3613 FSL 658 FEL S20 T11 N R15E UM 5960452.60 701352.75 /V 11.7.7.IV IV /V 1/ YY.LL'J VV IYV LG IY.Y.7V 701226.96 N 70 17 44.347 W 148 22 13.678 701255.63 N 70 17 44.477 W 148 22 12.832 701282.33 N 70 17 44.600 W 148 22 12.043 701310.08 N 70 17 44.729 W 148 22 11.224 701319.52 N 70 17 44.773 W 148 22 10.945 701352.75 N 70 17 44.927 W 148 22 9.964 S • SurveyEditor Ver SP 2.1 Bld( users) 18-29\18-29\18-29C\18-29C Generated 7!28/2009 10:48 AM Page 7 of 7 TREE _ WELLHEAlJ = FMC ACTUATOR = KB. ELEV = 44.1 - BF. ELEV = -- - 18.9 KOP - 3374 Max Angle = 94' @ 130`e 1 Datu m MD = 1 ~ ~&=; Datum ND = 86uu' ~c KOP /Tow 3374' Minimum ID = 3.725" @ 11,857' 4-1 /2" XN NIPPLE NOTES: **CHROMETBG** 90° @ 13103' & -70° I -~ ~ ~ @ 1~ 2181' 4-1/2" X-NIP, ID = 3.813" 3189' 9-5/8" x 7" ZXP LT PKR W/LNR HGR & 12' PBR, ID = 6.29" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3 3720 3700 20 KBG DOME BK 16 07/07/09 2 7738 6108 67 KBG SO BK 20 07/07/09 1 11637 7783 36 KBG DMY BK 0 07/03/09 ~ ¢sv H 3396' 13-3/8" CSG, 72#, BTC, N-80, ID = 12.347" 3704' 9-5/8" CSG, 47#, L-80, ID = 8.681" H 8,000' 11757' H4-1/2" X-NIP, ID = 3.813" 11788' 7" x 4-1/2" BKR S-3 PKR, ID = 3.87" 4-1/2"Tubing, 12.6#, 13CRVAMTOP, ID=3.958" 7" CSG, 26#, L-80, BTGM, ID = 6.276" 11822' 4-1/2" X-NIP, ID = 3.813" 11894' 4-1/2" XN-NIP, ID = 3.725" 11907' 12076' ~ 11903' 7" x 5-1/2" HRD ZXP LT PKR W/LNR HGR & 12' PBR, ID = 4.20" 11907' WLEG PERFORATION SUMMARY REF LOG: MWD ANGLE AT TOP PERF: 89° @ 13850' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.88 6 13850 - 14400 O 07/01 /09 2.88 6 14500 - 14977 O 07/01 /09 2.88 6 14977 - 15100 O 07/01 /09 2.88 6 15150 - 15400 O 07/01 /09 ~ PBTD H 15416' ~ ,_~,~;~~ ~} 4-1/2" Liner, 12.6#, L-80, ID = 3.958" 15546' I~,I~ ~ ` Top of fish LIH BHAw/ RA Source 15548' ~ TD 15918' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/28/92 ORIGINAL COMPLETION 05109/93 SIDETRACKNVORKOVER 07/04/09 N7ES SIDETRACK (18-29C) 07/05/09 /SV DRLG HO CORRECTIONS 07/15/09 ACB/SV GLV C/O (07/07/09) ' I 1 I N 1 1 PRUDHOE BAY UNfT WELL: 18-29C PERMIT No: 209055 API No: 50-029-22316-03-00 3805 FSL 86 FEL S24 T11 N R14E RP Fvnln rafinn lAlaclc al 18-29C Lost BHA • Maunder, Thomas E (©OA) Page 1 of 2 From: Maunder, Thomas E (DOA) Sent:: Tuesday,. July 07, 2009 3:33 PM To; 'Ciolkosz, Ryan R' Gc; Hobbs, Greg S (ANC); Ryan.Daniel~bp.corn; Tirpack, Robert. B Subject: RE: 18-29C (209-055) Lost BHA l~yart, et air l appreciate your response to my qua ~. Vi/hiie it does appear that the sourcQ was successfully isolated, the failure to notify the Corrrrrrission is surprising especially since another source herd been recently lost end the necessary communications had been accomplished. Hopefully, establishing the SOP should prevent recurten Cat a failure to notify the Ccrnmission. V~hi9e SP, as the r~perator, has the ultimate respr3nsibility mere it alse~ appropriate that your source vendor(s) also conspicuously include a note in their documentation that the Commission is to be notified when it becorries necessary tt3 abandon a nuclear source of any kind (FL or IWWd): We will be back in contact regarding this rrrattor. Cail or rt~essage with any questions. Tt~rt~ ~Aaunaer, Rl` A CO From: Ciolkosz, Ryan R [mailto:Ryan.Ciolkosz@bp.com] S~n# Tuesday, 3uty 07, 2009 3:.20 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Ryan.Qaniel@bp.com; Tirpack, Robert B Subject: 18-29C Lost BMA Torn, First and tdrerr~et, we apolcygi~e for ~e lank csf eommunications with your ice which is explained in #~ t~lc~w. Greg Mobbs and l worked together on answering your questions. This err°-ail is ~ ft~ilow up Greg's phone call to you on July ~~~' regarding your goestions. 1. UNhen did the BWA be~rrte stuck UVe lost ~QQ psi at 1~:~1~ Jun ~~° 9 ~11~h~~d' lVlD) and suspected a shout in a ztrill ape.: P H Arad nd the SHA missing at 10,0 June 24 2009. Attempted to fish with tvershot and could not get over ftsh with overshot, POOH and overshot was lost in hole. tiles with burn ght~ and dressed off fish. RlH again with o of end engaged fish at 23:00 June 27~' 21309. ;4ttempted ~ pipe and far without success. "Tate was truly stuck after it moved only 121# in the first 12 haute ctf jarring on `tt: Another ~4 hours of jarring was completed without any movement. . ~Utaen was fishing ando Dish was abandon, at 1;00 June 29~ 2013 ~. When was'the t~RC's approval obtained to abandon thse source in the well? NlC's apprava! was received by by at 11 ~4Q Jane 26th 2009 as part of contingency planning for what we viewed a remote possibility of abandortir~ the ash.. 4. When was the liner cerriented~ ~~ ~~ 8/7/2Q09 18-29C Lost BHA ~ • Page 2 of 2 la~~r'was cet~aented at '~~.:~ :t~aate ~~~' ~ 5. vtmy w~t~ the ramml~>al~rl l~~t ~~tacted';r l~alhile we always strive tca be transparetat watts the a~r~ ~ ai difficulties, the us rata tlae fistat~ag operations, and the anticipated success of retrieval frn8'Ya the duction section did not higl~lipht a strung need for a call when the BHA was I©st. Whe>~ the flgh was eragag~d eta tha 27~' of June at 2~d~(I hours, it itaitially r»65tred 9~ feet in the first thirteen hours of jarring. Ira the ensuing 24 hour, the fish did nat move. After ttae thirty six hours of jaa~r~g witfiout retrieval, t#ae ~a°ttaa~aa'a oaf ~rtyandonra~erat tael~w a cernent~d ling was e I off ttae NRC. As this contingency ~cecuted on Monday afternoon, the 29th of ,lun+e~ tlt~s t`o~~ ~t~l execution of it, given the low antici~at~d Inl#tal need far it, allowed cur call to your tt3 g~ lost in the operations. We sincerely apalogl~e for thl~ oversight. To assure this does not happ~ra Ir- the future, we will pture source abandonrt~nt in an 5~~ ~P ~+lastca'~rilling erail Wells for what VYe remains a rare operatian.. ~iease c~rll or message with any questions er eoorrart~~nt~. Ryan Colkosz 'CiPB Rotary Operations Drilling Eiagineer $P Exploration Alaska office: (907)564-5977 Cell; (907}306-626 ~~~~~0 8/7/2009 ~~ 18-29C BHA lost in hole • Maunder, Thot,°nas E (DE}A) From: Maunder, Thomas E (DOA) Sent:. Wednesday, July 01, 2009 4:51 PM To: 'Ciolkosz, Ryan R' Cc: Hobbs, Greg S (ANC)„ Tirpack, Robert. B Subject: RE; 113-29C (209-055) BHA lost in hole Cmportance: High Page 1 of 2 Ryan, The Gorttrriission should btu rtt~t-fied in ADY~ING~ when a nuclear source 1®st and it is determined t>3 seal the stnurce in ~e last wellboro. ~ontac#it~g ~e CdR~ sregarding tf~ lost se,urce is appn3pnate however, while the ultima#e plug(s) will likely be at a minimum according to the NRC's requiremen#s. the At~~~C is the authorizing authority for plugging any well in Alaska. if I recall corteCtly, a nuclear source was lost in anr~her well not long ago and the Commission was contacted, apprised of the eituatitan and consulted with regard to plugging according to NI~C requirements. It seems appropria#~ that t3R'~ and xhlumberger's pa~toC~s fCar handling lit sources needs #o be moditred to conspicuously Mete that the ,4,fl~GC must be no#ihed in 1D~'!1 E when it i~ determined that a nuclear source will be erne d in a Mast h+asle sectitrra. With regard to this particuhtr event, i have st3ma question: l~ When did the 1~#-lA tcome stu ~. When was fishing abanda~ned? ~. When was the NRC's approval o5t~-ined to abandorg the source in the well? ~. When was the liner cemented? ~. Why was the Cort9rrmission not contacted' Call or message with any questions. Please be aware thai the Ocmmissi+~n may pursue an enfcarcement action in This matter. Tom Maunder, PE RC3aC From.: Ciolkosz, Ryan R [mailto:Ryan.CiolkoszC~bp.com] Sent: Wednesday, July 01, 20Q9 4:21 PM To Maunder, Thomas E (DOA) Subject: 18-29C BHA Cost in hole Tom, l wanted to inf©rm you that. white pulling out of the production hale on 18-29C we stuck ttae 6 1/8" BHA in ttTE production hole. The BHA contained a nuclear source. The. NRC was contacted by Schlumberger and the t3HA has been abandoned per the NRC's requirements. The top of the fish is located at 15,54$' with the original TD at 15,91$'. A fully cemented 4.5" Liner with a120' shoe track was run and cemented on top of the fish. Let me know if you have any questions.. Thank you, Ryan. Ciolkas APB Rotary C~peratians Drilling Engineer 13P Exploration Alaska ~~~~ ~~b< 8/7/2009 Page 1 of 1 Maunder, Thomas E (DQA) From: Crisp, John M (DQA) Sent: Thursday,. June 18, 2E?09 5:.31 AM To: pOA AQGCC Prudhoe Bay Cc; Aubert, Winton. G (DC}A); Maunder, Thomas E (~~A) Subject: Well Control Nabors 7ES PBU 18-296 Mike l?tnger BPXA pritt Site Leader called this morning ~ 0444 hrs.. They took a kick while drilling praductton hole. Bob Noble was out last night to witness BOP test on this Rig. Mika indicated that ADGCC Field inspector was his second contact & they were still monitoring pressures. I requested a mail notification with particulars of depths & pressures ~ their first opportunity. ~C~`~ ~~~~ ~C'" gi~i~ao9 18-29C ~ ~ Page 1 of 1 Maunder, Thomas E (DOAj From: Maunder, Thomas E (DOA) Sent: Wednesday, June 17, 2009 1:06 PM To: 'Ciolkosz, Ryan R' Cc: Hobbs, Greg S (ANC) Subject: RE: 18-29C (209-055) Ryan, It would appear that substituting a premium connection for higher cement can provide the external isolation you desire. If there are issues with shallower zones (i.e. cretaceous), then a higher cement top may still be desirable. When changes such as this are planned, they should be communicated PRIOR to accomplishing rather than after. Tom Maunder, PE AOGCC From: Ciolkosz, Ryan R [mailto:Ryan.Ciolkosz@bp.com] Sent: Wednesday, June 17, 2009 12:47 PM To: Maunder, Thomas E (DOA) Subject: 18-29C Tom, I wanted to let you know that we changed the design for the intermediate casing string and cement on 18-29C being drilled by Nabors 7es. Originally planned for a higher cement top, the modeling indicated that we would not be able to pump cement this high. The cement was intended to create a barrier for the BTC-M connection. Instead, we ran premium TCII thread connections for the entire casing run, then pumped a 1000' slurry of class 'G' cement at the 7" casing shoe. There are no zones in the intermediate section that the AOGCC requires us to cover with cement. Please let me know if you have any questions. Thanks, Ryan Ciolkosz GPB Rotary Operations Drilling Engineer BP Exploration Alaska Office: (907)564-5977 Cell: (907)306-5626 6/17/2009 ~ , t ;`c k~ SARAH PALIN, GOVERNOR k t ~ ~ ~~ ~ 1~ ~~r ~ 1~T ~r ~ t1Lta51~A OIIJ ~ ~ xrF 333 W. 7th AVENUE, SUITE 100 COATSI'iRQA~I'IOI1T COMIIIISSIOI~T `d ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-29C BP Exploration (Alaska) Inc. Permit No: 209-055 Surface Location: 3805' FSL, 86' FEL, SEC. 24, T11N, R14E, UM Bottomhole Location: 3595' FSL, 4643' FWL, SEC. 20, T11N, R15E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to redrill 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). Sincerely, ;~'~.~~- Cath Faerster Commissioner DATED this ~ day of May, 2009 cc: Department of Fish 8w Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA -~S/~~~ - J~ ~,~~ ~ASKA OIL AND GAS CONSERVATION (~'IMISSION X s'a~ E,~~~ ~ 5 ~.~fl~ ~~U~ PERMIT TO DRILL !~ 20 AAC 25.005 };;~~:~ ~~~ ~ xas Cans. 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 pro8 ^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 18-29C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 15792' TVD 8699' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028307 & 028321 Oil Pool FEL, SEC. 24, T11 N, R14E, UM 3805 FSL, 86 Top of Productive Horizon: T11N R15E UM 3262' FSL 1869' FWL SEC. 20 8. Land Use Permit: 13. Approximate Spud Date: June 1, 2009 , , , , , Total Depth: 3595' FSL, 4643' FWL, SEC. 20, T11N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 33,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-691688 y-5960392 Zone-ASP4 10. KB Elevation Plan (Height above GL): 44.4 feet 15. Distance to Nearest Well Within Pool: 620' 16. Deviated Wells: Kickoff Depth: 3750,E feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3347 Surface: 2477 1 in Pro m: ifi n T- Settin h- Bo m n i of n' .f. r s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1 /2" 7" 26# L-80 BTC-M 8424' 00' 3590' 12024' 173' 1241 cu ft LiteCrete 99 cu ft Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1918' 11874' 8067' 13792' 8699' 275 c ft Class' ' -1/8" 4-1/ " 12.6# - 0 IBT-M 2 1 8 1579 ' m nt I Li 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations)' Total Depth MD (ft): 10852' Total Depth TVD (ft): Plugs (measured): 8771' 8890' Effective Depth MD (ft): 10810' Effective Depth TVD (ft): 8769' Junk (measured): None Casing Length Size Cement Volume MD' TVD Conductor /Structural 11 2 0 I I 1 11 ' Surface 3704' 13-3/8" 2706 cu ft CS III 460 cu ft Cla s'G' 3704' 690' Intermediate 8 9-5/8" 2218 cu ft Clas 'G' 80 7304' Pr i n Liner 1512' 7" 37 cu ft Class'G' 7 0' - 9 72' 71 ' - 8605' Liner 216' 4-1/2" 135 u ft Class'G' 9171' - 9387' 8414' - 8619' Lin r 19 2-3/ " 4 LARC ' - 1 2' 1 ' - 770' Perforation Depth MD (ft): 9700' - 10799' Perforation Depth TVD (ft): 8738' - 8769' 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. I hereby certify that the foregoing is true and correct. Contact Ryan Ciolkosz, 564-5977 Printed Name Robe Tirpack Title Engineering Team Leader Prepared By NameMumber: Si nature ~ ~ Phone 564-4166 Date ~ ~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ~~s API Number: 50-029-22316-03-00 Permit Approval See cover letter for Da z o l> other r uiremen Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ,_,/ Q Sam les Re 'd: ~~~ S~ ~d`~``~ ~ `~~ p q ^ Yes L1a No Mud Log Req'd: ^ Yes I]d No a54QQ'\ r~\t~~'r"~v ~V.~t~v`t~c ~c;S~ HzS Measures: ~Y\e(s~ ^\ No \ Directional Survey Req'd: Yes ^ No Other: '1~~CSa_S'<+'~S 'rG.~S ~c.r a~ ~4La-~.~~ S ~~~~~ 7 \,A )~~ ) APPROVED BY THE COMMISSION Date S-~ ' ~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate Well Name: 18-29C Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Producer Surface Location: As-Built X=691687 Y=5960392 3805' FSL, 86' FEL, T11 N, R14E, Sec. 24 Target Locations: X=698612 Y=5960028 Z=8699 Sag Tgt 1 3261' FSL, 3410' FEL, T11 N, R15E, Sec. 20 Bottom Hole Location: X =701375' Y =5960435' Z=8699' 3595' FSL, 637' FEL, T11 N, R15E, Sec. 20 Dou Stoner Geolo ist 564-5652 Nathan Sin an we Prod. En ineer 564-5062 R an Ciolkosz Drillin En ineer 564-5977 API NUMBER: TBD Ri Nabors 7ES Estimated Start Date: 06/01 /2009 Operating Days to complete: 31.25 MD: 15792 TVD: 8699' RT/GL: 28.5'/15.9' RTE: 44.4' Well Design: Ivishack Zone 1 Producer 4'/i" tba. 12.6# 13-CR-80.7" x 4 ~/x" packer. 4'h" L-80 12.6# Solid/Slotted Liner Ob'ective: Horizontal Producer in Ivishack Zone 1 Directional Plan: Version: Schlumber er P4 KOP: 3750' MD, build 4/100 Maximum Hole An le: 90.0° Close Approach Wells: L2-08A, 460' Ctr to Ctr Distance at 15,792' MD 18-03, 66' Ctr to Ctr Distance at 4,404' MD 18-25, 405' Ctr to Ctr Distance at 12,459' MD Nearest well within Pool: 620' to 11-30 Distance to Nearest Property 33000' to Unit Boundary N Line• 18-29C Permit Application Page 1 Surface and Anti-collision: Surface Shut in Wells: LPC-02 is a high pressure injector that requires shut-in prior to the rig moving on to 18-29C. Close Approach Shut-in Wells: L2-08A and 18-25 will be shut-in before drilling by. 18-03 will be shut-in and have a tubing tail plug set before the rig moves on site. Legging Prearam: Intermediate Interval Drilling, MWD: GR/Directional Open Hole: None Cased Hole: GR Pre-Ri for Tie-in Lo Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density, Open Hole: None Cased Hole: None Mud Program: Whipstock Milling Mud Properties Density Plastic Y nt d API Fluid MBT (ppg) Viscosity lb/1 Oft ( ) Loss pH c mis/30min 9.2 - 9.9 15-22 30-40 6 -8 9.0 - 9.5 < 20 A 1M• Intr~rmpdiatp Hnlp~ I SNn Mud Density Plastic Yield Po nt API Fluid MBT Interval (ppg) Viscosity (Ib/100ft) Loss pH c mis/30min 3750 - 11537 9.2 - 9.9 12 -18 18 -24 < 6.0 9.0 - 10 < 20 11537 -12024 10.8 16-20 25 - 30 < 6.0 9 - 10 < 20 F 1/R" Praduction Holey Flo-Pro Mud Interval Density Plastic Viscosity Ylb/1d00ftnt ( ) API Fluid Loss pH MBT (ppg) c ml/30 min Production 8.5 -8.6 8 - 15 24 - 30 6 -8 9 - 9.5 < 6 Casina/Tubina Prearam: Hole Size Csg/ Tb O.D. Type Wt/ Ft Grade Connection Length Top MD/TVD Btm MD/TVD RTE 8 1/2" 7" Solid Liner 26 L-80 BTC-M 8424' 3600'/3590' 12024'/8173' 6 1/8" 4 1/2" Solid 12.6 L-80 IBT-M 1918' 11874' / 8067' 13792' / 8699' 61/8" 4'/z" Slotted 12.6 L-80 IBT-M 2000' 13792'/8699 15792'/8699' Tubin 4'h" 12.6 13CR-80 VamTo 11870' GL 11870' / 8064' Comments: I rroaucUOn Hole: tsonzai caner tsona ~emenieaiaiottea liner wmr~o~ wiCx~ernai ~.asniy Packer 18-29C Permit Application Page 2 Integrit Testin Test Point Depth Test Type 9 5/8" Surface Casin 20' - 50' from window LOT Test Point Depth Test Type 7" Intermediate Casin 20' - 50' from intermediate shoe LOT Cement Calculations: Casin Size Intermediate - 7" 26 ppf L-80 BTC-M -Sin le Sta e Basis Tail: Open hole volume + 30% excess TOC at 500' above 7" shoe. Lead: Open hole volume + 30% excess TOC is 4000' MD Wash None 3 acer 50 bbls of MudPush II wei hted to 10.9 Lead 221 bbls 421 sks 11.0 LiteCRETE 2.95 ft /sN Tail 17.7 bbls 85 sks 15.8 Class G -1.17 cuft/sk Temp BHST ~ 168° F Casin Size Production Casin - 4 1/2" 12.6 f L-80 IBT-M - Bonzai Basis Tail: 1768' + 40% excess + 150' liner lap + 200' MD above liner. TOC at TOL. Bottom of cement at top of Slotted liner. Wash None 3 acer 30 bbls of MudPush II wei hted to 12.0 Tail 49 bbls 234 sks 15.8 Class G w/I. Temq BHST =182° F - 1.17 18-29C Permit Application Page 3 • Formation To s(TVDss) and Estim ated Pore Pressures Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Formation (TVDss) eet) (Yes/No) (Psi) BPRF No SV4 -3136 No SV3 -3598 No SV2 -3811 No SV 1 -4210 No UG4 -4703 No UG3 -4910 No UGl -5473 No WS2 -6068 No WSl -6270 No CM3 -6517 No CM2 -6949 No CM1' -7538 No THRZ -7926 No BHRZ -8125 No LCU/TJA -8125 No TSGR -8129 20 Yes TSHA -8163 20 Yes TSAD -8218 20 Yes TCGL -8321 20 Yes BCGL -8386 20 Yes 23SB -8443 20 Yes 22TS -8476 20 Yes 21TS -8522 20 Yes TZ1B -8572 20 Yes TDF -8616 20 Yes 3300 BSAD -8662 20 No 18-29C Permit Application Page 4 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 3500 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: 3347 psi ~ 8699' TVD, 7.4 ppg EMW (at Top of Ivishack Zone 1, 12981' MD) • Maximum surface pressure: 2477 psi C~ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: • Annular Preventer • Rams • Planned completion fluid: 250 / 2500 psi 250 / 3500 psi 8.6 ppg seawater / 6.8 ppg diesel Kick Tolerance l Integrity Teisting Summary Table Casing and Interval Casing Test Pressure Maximum Influx Volume Mud Weight Exp Pore Press LOT / FIT 95/$" Surface 3500 psi 53 BBLS 10.0 9.8 LOT Casing (assuming 12.5ppg EMV LOT 7" Production 3500 psi Infinite 8.5 7.4 LOT Casing (assuming at least 9.Oppg EMV LOT Disposal: • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. 18-29C Permit Application Page 5 1&29C -Drill and Complete Procedure Summary Current Well Conditions 1. Open Perfs from 9,700' -10,799' MD. PBTD - 10,810' MD 2. Currently shut-in due to low oil rate 3. MITOA passed to 2000 psi (03/31/2009) 4. CMIT-TxIA passes to 3000psi (03/30/2009) 5. MITIA Failed (12/05/2009). LDL showed Tubing Leak C~3 6560' MD Pre Riq Operations S 1 Drift tubin to 8890' and Pull TTP. E 2 Run GR/CCL from 8750 to Surface. Send to ODE and DS 18 Geolo ist. F 3 Lay in at least 10 bbls of cement from PBTD at 10,810' MD to 8,612' MD in the 2-3/8" liner with 15.8 ppg Class G cement. The TOC must be a minimum of 9600' MD to comply with AOGCC regulations. Volume of 2-3/8"from 10,810' to 8,911': 0.00386 bpf, 1899' = 7.4 bbls and volume of 3'/z tubing from 8,911 to 8,612:.0087 bpf, 299' _ 2.6 bbls. This plug is for zonal isolation. Freeze protect tubing with diesel to 2200' TVD. SBHP: 3326 si SBHT: 182 °F S 4 WOC. Drift to TOC. O 5 CMIT-TxIA to 2,500 psi. Pressure tests are required for competent barrier for rig o erations. If test fails, contact ODE. E 6 Jet cut tubin at 4200' MD. O 7 CMIT-TxIA to 2,500 psi. Pressure tests are required for competent barrier for rig o erations. If test fails, contact ODE. Freeze Protect as necessa O 8 Bleed casin and annulus ressures to zero. O 9 Function tubing and casing LDS. Repair/replace as required. Perform PPPOT-IC to 3500 si and PPPOT-T to 5000 si. S 10 Set TTP in 18-03. This is required for Anti-collision risk mitigation. Due to Pad restrictions and Potential Sim-ops, this may have to be done pre-rig. In either case, it should be timed to minimize the im act on 18-03 roduction. S 11 Shut-in LPC-02 and Test BHP with ressure bomb. Send test results to ODE. O 12 Set a BPV. Remove well house and flow line. Level ad as necessa Riq Operations 1. Move in. Rig up Nabors rig 7ES. 2. Pressure test OA to 2,000 psi and IA to 2500psi. (Begin Monitoring OA) 3. RU lubricator and Pull BPV.. 4. Circulate out Freeze Protect and displace with seawater. 5. Install BPV and test to 1000psi. 6. Nipple down tree. Install blanking plug. Nipple up BOPE. 7. Test BOPE to 3500 psi high, 250 psi low. Pull BPV and blanking plug. 8. Screw in landing joint. Unseat and pull 4 1 /2" tubing hanger to floor. 9. Lay down landing joint and hanger. 10. Pull 3-1/2"" x 4-1/2" tbg to cut at 4200' MD. Spool up control line. Count bands and clamps. 11. Test Lower BOP rams. 12. Clean casing with 9-5/8" casing scraper to cut. Circulate well, surface to surface. 13. RU E-line. Run EZSV with GR/CCL to 3760' MD. 14. Test 9-5/8" casing above E to 3 psi. ~t' ~b~ 15. Change out 9 5/8 pack-off and Spool. 16. NU BOP and Test Breaks. 17. PU and RIH with whipstock. 18. Orient and set WS at 3750' MD. 19. Displace to 9.2-9.9 ppg LSND millin fluid. 20. Mill window. Pump a sweep. Sri 20 , pe orm T~(50FrL~win ow mi ing assem y. 21. PU 8-1/2" drilling BHA (GR/Dir). RIH. ~tS 18-29C Permit Application Page 6 22. Drill to TD, increasing mud weight to 10.8 ppg prior to entering the HRZ. (Pick up 5" DP as necessary. 23. At TD, Circulate sweep and BU as necessary. Do wiper to previous casing shoe. POH and LD BHA. ~ `~~~J.`\~~~ ct.S~~SC~-MS 24. Rig up liner running equipment. Run 7 6# L-80 liner. ` ~~ ~,/~~ 25. Circulate bottoms up at the window. Continue into TD. fd- 26. Circulate hole prior to cement. 27. Cement liner in place. Set liner hanger/packer. 28. Circulate out contaminated mud and cement. POH. LD running tool. 29. Test 7" liner to 3500 psi for 30 minutes. Chart same. 30. PU build 6 1/8" Build BHA (GR/Resistivity/Neutron-Density). RIH 31. Drill cement and float equipment. Displace well to Flo-Pro drilling fluid. 32. Drill 20' of formation. Perform LOT. 33. Drill to soft landing in Zone1 A. Circulate BU. POOH 34. PU lateral 6 1/8" BHA (GR/Resistivity/Neutron-Density). RIH. 35. Drill horizontal section to TD. 36. Circulate sweep and BU as necessary. POOH, LD BHA. Pull Wear Bushing 37. Run and Cement 4-1/2" IBT-M Bonzai Completion with Inner String according to RP. 38. RU to run tubing. 39. Run 4-1/2" 13CR-80 completion. 40. Space out and land tubing. 41. Reverse in corrosion inhibited brine 42. Drop Ball and Rod. Set packer. Individually test the tubing and annulus to 3500 psi for 30 minutes. 43. Shear valve and Confirm circulation. 44. Install TWC valve and Pressure test to 1000psi. Nipple down the BOPE. Nipple up the tree and test to 5000psi. 45. Pull TWC valve. Freeze protect the well to 2200' TVD. Install BPV. 46. RDMO. Release rig. Post Rig Operations 1. Pull BPV 2. Pull the ball and rod / RHC plug. 3. Install gas lift valves 4. Re-install well house and instrumentation. 18-29C Permit Application Page 7 ~ ~ Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE Well Control /Reservoir Pressures: A. Cretaceous Produced Water Injection Over-Pressure. Expect over pressure from the produced water injection in the UGNU Cretaceous sands. Expect 9.8 ppg EMW. LPC 02 Injector must be shut-in prior to the rig moving on the well. B. The Sag River in this fault block is expected to be under-pressured at 7.4ppg EMW. This pressure is estimated based on offset well pressures. II. Stuck Pipe A. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ/Kingak shale give problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. B. Monitor cuttings closely and adjust mud weight accordingly to avoid destabilization. C. We do not expect stuck pipe if the hole is kept adequately clean. III. Lost Circulation: A. Loss Circulation is common on DS 18 in the production hole. If losses occur follow the loss circulation tree outlines in the MI Swaco program and swap to seawater if necessary. IV. Kick Tolerance /Integrity Testing: A. The 9 5/8" casing is cemented to surface. Casing will be tested to 3500 psi before drilling out. A LOT will be performed after drilling 20-50' of new formation after milling out the 9 5/8" casing. B. The 7" liner will be cemented to 4000'. A LOT will be performed after drilling 20-50' of new formation after drilling out 7" casing shoe Kick Tolerance / Integrity Testing Summary Table Casing and Interval Casing Test Pressure Maximum Influx Volume Mud Weight Exp Pore Press LOT / FIT 95/8" Surface 3500 psi 53 BBLS 10 9.8 LOT Casing (assuming 12.5ppg EMV FIT 7" Production 3500 psi Infinite 8.5 7.4 LOT Casing (assuming at least 8.8ppg EMV FIT 18-29C Permit Application Page 8 • i V. Hydrogen Sulfide A. DS 18 is not an H2S site. H2S ranges are typically <20ppm. Standard H2S precautions will be followed at all times. Personal Monitors will be worn at all times. H2S Summa Table Well Na e H S Level m Date of ea in #1 Closest SHL Well H2S Level 18-OlA 10 m 10/15/2007 #2 Closest SHL Well H2S Level 18-19 14 m 5/7/1999 #1 Closest BHL Well H2S Level 18-03B 20 m 11/28/2008 #2 Closest BHL Well H2S Level 18-24B 6 m 12/2/2008 Max. Recorded H2S on Pad/Facilit 18-03B 20 m 11/28/2008 VI. Faults A. No fault crossings are expected in this well. However, unexpected fault crossings are always possible. VII. Anti-Collision Issues A. L2-08A and 18-25 must be shut-in prior to drilling by. 18-03 will be shut in with a Tubing tail plug before the rig moves on site. CONSULT THE DS 18 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 18-29C Permit Application Page 9 WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 51.0' BF. ELEV - 20.0' KOP = 3300' Max Angle = 93 @10385' Datum MD = WA Datum TV D = 8800' SS 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 3012' 13-3/8" CSG, 68#, L-80, ID = 12.415" ~ 3704' Minimum ID =1.941" @ 8911' 2-3/8" LINER TOP TOP OF BKR TIEBACK SLV, ID = 7.500" 7$60' 9-5/8" X 7" BKR H PACKER, ID = 6.180" 7$6$' 9-5/8" X 7" BKR HYFLO HGR ID = 6.380" 7872' 9-5/8" CSG, 47#, NT-80, ID = 8.681" 8000' Tubing Tail Rug 8890' TOP OF 2-3/8" LNR, ID = 1.941" 8911' 3-1/2" TBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992" ~ 9004' TOP OF BKR TIEBACK SLV, ID = 5.250" 9171' 7" X 4-1/2" BKR H PACKER, ID = 3.950" 9179' 7" X 4-1/2" BKR HYFLO HGR, ID = 3.950" 9183' 7" LNR, 29#, L-80, ID = 6.184" PERFORATION SUMMARY REF LOG: SWS MEMORY CNL/GR OF 09/02/98 ANGLE AT TOP PERF: 89 @ 9700' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9700 - 10140 O 09/03/98 1-11/16" 4 10300 - 10799 O 09/03/98 4-1/2" LNR, 12.6#, L-80, ID = 3.958" I~ 9670' 18-29 B SAFETY NOTES: W ELL ANGLE > 70° @ 9528' 8 > 0° 2 9787'. 2193' I~ 4-1/2" CA-TRCF-4A TRSSSV, ID = 3.812" 3012' I~ 4-1/2" X 3-1/2" XO, ID = 2.992" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3448 3442 11 MMG DMY RK 0 12/03/08 2 5866 5545 34 MMG DMY RK 0 12/03/08 3 7749 7096 34 MMG DMY RK 0 09/10/98 4 7838 7170 34 MMG DMY RK 0 12/03/08 9-5/8" CSG MILLOUT WINDOW / 8000' - 8050' (SECTbN MILL) 8890' 3-1/2" PARKER SWS NIP, ID = 2.813" 8906' 2.70" BKR DEPLOYMENT SLV, ID = 1.969" 8938' 7" X 3-1/2" TNV HBBP PKR, ID = 4.00" 8972' 3-1/2" PARKER SWS NIP, ID = 2.813" 8990' 3-1 /2" PARKER SWN NIP MILLED TO 2.80" 9003' 3-1/2" WLEG, ID = 3.00" 4-1/2" LNR MILLOUT WINDOW 9387' - 9392' (OFF CMT R_UG) PBTD I~ 10810' 2-3/8" LNR, 4.6#, L-80, .0039 bpf, ID = 1.941" ~-I 10832' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/28/92 ORIGINAL COMPLETION 05/09/93 RIG SIDETRACK (18-29A) 09/04/98 CTD SIDETRACK (18-29B) 01/28/02 CH/KAK CORRECTIONS 09/13/03 CMO/TLP DATUM MD CORRECTION 12/12/08 SEW/SV GLV GO (12/03/08) PRUDHOE BAY UNff WELL: 18-29B PERMff No: 1980690 AR No: 50-029-22316-02 SEC 24, T11 N, R14E, 3805' NSL & 86' WEL BP F3cploration (Alaska) WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 51.0' BF. ELEV = 20.0' KOP = 3300' Max Angle = 93 @ 10385' Datum MD = N/A Datum TV D = 8800' SS ~ 18-296 Pre-R~ II ro17T °" ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 13-3/8" CSG, 68#, L-80, ID = 12.415" ~--~ 3704' Minimum ID =1.941" @ 8911' 2-3/8" LINER TOP TOP OF BKR TIEBACK SLV, ID = 7.500" 7860' 9-5/8" X 7" BKR H PACKER, ID = 6.180" 7868' 9-5/8" X 7" BKR HYFLO HGR, ID = 6.380" 7872' 9-5/8" CSG, 47#, NT-80, ID = 8.681" 8000' Estimated TOC 15.8 Gass G 8612' TOP OF 2-3/8" LNR, ID = 1.941" 8911' 3-1/2" TBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992" ~ 9004' TOP OF BKR TIEBACK SLV , ID = 5.250" 7" X 4-1/2" BKR H PACKER, ID = 3.950" 9171' 9179' 7" X 4-1/2" BKR HYFLO HGR, ID = 3.950" 9183' 7" LNR, 29#, L-80, ID = 6.184" 9372' PERFORATION SUMMARY REF LOG: SWS MEMORY CNL/GR OF 09/02/98 ANGLE AT TOP PERF: 89 @ 9700' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9700 - 10140 O 09/03/98 1-11/16" 4 10300 - 10799 O 09!03/98 ~ 4-1/2" LNR, 12.6#, L-80, ID = 3.958" ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3448 3442 11 MMG DMY RK 0 12/03/08 2 5866 5545 34 MMG DMY RK 0 12/03/08 3 7749 7096 34 MMG DMY RK 0 09/10/98 4 7838 7170 34 MMG DMY RK 0 12/03/08 8890' -~ 3-1/2" PARKER SWS NIP, ID = 2.813" ' " " BKR DEPLOYMENT SLV, ID = 1.969 $906 2.70 1/2" TNV HBBP PKR ID = 4 00" ' 7" X 3 , . - 8938 1/2" PARKER SWS NIP ID = 2 813" 8972' 3 , . - 1/2" PARKER SWN NIP MILLED TO 2 80" 8990' 3 . - 9003' 3-1/2" WLEG, ID = 3.00" Sq~IYrDI@VIBLq~[~E>70P a~8J 90'2978T. 4-1 /2" CA-TRCF-4A TRSSSV, ID = 3.812" 3012' (~ 4-1/2" X 3-1/2" XO, ID = 2.992" ^4200 i~ Tubing Jet Cut 4-112" LNR MILLOUT WINDOW 9387' - 9392' (OFF CMT PLUG) s I PBTD I 2-3/8" LNR, 4.6#, L-80, .0039 bpf, ID = 1.941" ~~ 10832' DATE REV BY COMMENTS DATE REV BY COMMEMS 12/28/92 ORIGINAL COMPLETION 04/29/09 RRC P&A/Tubing Cut 05/09/93 RIG SIDETRACK (18-29A) 09/04/98 CTD SIDETRACK (18-29B) 01/28/02 CH/KAK CORRECTIONS 09/13/03 CMO/TLP DATUM MD CORRECTION 12/12/08 SEW/SV GLV C/0 (12/03/08) PRUDHOE BAY UNIT WELL: 18-29B PERMff No: 1980690 API No: 50-029-22316-02 SEC 24, T11 N, R14E, 3805' NSL & 86' WEL BP Exploration (Alaska) TREE= McEVOY GEN 3 WELLHEAD `- FMC ACTUATOR = BAKER C KB. ELEV = 51' BF. ELEV = 20' KOP = 3750' Max Angle = 90 @ 12769' Datum MD = 9442' Datum TV D = 8800' SS ~ 13-3/8" CSG, 72#, BTC, P ~ p o s e d 18 ~~ 9 SAFETY NOTES: Well @ 90 deg. 2,200' 4-1/2" X-NIP, ID = 3.813" 3,590' Liner tie Back 3,600' 9-5/8" x 7" Baker Liner Packer ID = 12.347" 3704' GAS LIFT MANDRELS 03-32 KOP 3,750' ¢SV 3,760' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3559' 3550' MMG 2 7490' 6112' MMG 1 11200 7782' MMG 9-5/8" CSG, 47#, L-80, ID = 8.681" 8,000' Minimum ID = 3.725" @ 11,857' 4-1 /2" XN NIPPLE 11792' H4-1/2" X-NIP, ID = 3.813" 11812' ~--~7" x 4-1/2" Packer 11836' H4-1/2" X-NIP, ID = 3.813" i 11857' 4-1/2" XN-NIP, ID = 3.725" 4-1/2" Tubing, 12.6#, 13CR VAMTOP, ID = 3.958" ~--I 11870' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" Liner, 12.6#, L-80, ID = 3.958" 15,792' I I I I I I I I I I J DATE REV BY COMMENTS DATE REV BY COMMENTS 12/28/92 ORIGINAL COMPLETION 04/08/09 RRC Rig ST 05/09/93 SIDETRACK/WORKOVER 09/04/98 CORRECTIONS 01/28/02 CMO/TLP PERF CORRECTION 09/13/03 CMO/TLP GLV C/O 12/12/08 SEW/SV GLV CORRECTIONS I 11,868' /LEG 11,874' Flexlock Hanger/HRD ZXP Packer 12,024' 7" CSG, 26#, BTGM, ID = 6.276" 13792' Baker ECP PRUDHOE BAY UNff WELL: 18-29C PERMff No: API No: 3805 FSL 86 FEL S24 T11 N R14E BP Exploration (Alaska) by DS18-29C (P41 Proposal gchlumberger Report Date: April 22, 2009 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - EOA Structure 1 Slot: Well: DS-18118-29 ~~ I i~ 18-29 Borehole: ~' Plan 18-29C ~~'a UWIIAPI#: 500292231603 Survey Name 1 Date: 18-29C (P4) /April 22, 2009 Tort 1 AHD 1 DDI 1 ERD ratio: 191.551 ° 110436.56 ft 16.560 11.200 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.29633871, W 148.44767791 Location Grid NIE VIX: N 5960392.230 ftUS, E 691687.700 ftUS Grid Convergence Angle: +1.46147282° Vertical Section Azimuth: 90.580° Vertical Section Origin: TVD Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table TVD Reference Elevation: 44.40 ft relative to MSL Sea Bed 1 Ground Level Elevation: 15.90 ft relative to MSL Magnetic Declination: 22.855° Total Field Strength: 57714.613 nT Magnetic Dip: 80.940° Declination Date: April 22, 2009 Magnetic Declination Model: BGGM 2008 North Reference: True North Total Corr Mag North -> True North: +22.855° Local Coordinates Referenced To: Well Head i Measured Azimuth Vertical NS EW Mag 1 Grav Directional Comments Inclination Sub-Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty R de de ft H ft ft ft de de 1100 ft Index ftUS ftUS I ie-In purvey SV3 13-3/8" Csg Top Whipstock Base Whipstock Crv 4/100 3bbU ./3 lb.b3 ZZ4A8 3b`J4. Z1 3b38. b~1 -`Jb .OL -lU4Ab -`J/.0`J 3.lbK V.VV 3654. 68 16.60 224.59 3598. 00 3642. 40 -97. 61 -105.36 -98.68 3.14R 1.65 3697 .50 17.30 224.72 3638. 96 3683. 36 -106 .29 -114.24 -107.45 3.03R 1.65 3700 .00 17.34 224.73 3641. 35 3685. 75 -106 .81 -114.77 -107.97 3.02R 1.65 3750 .00 18.17 224.87 3688. 96 3733. 36 -117 .44 -125.59 -118.72 65.00E 1.65 3766 .00 19. 06 219. 53 3704.13 3748. 53 3779 .00 19. 06 219. 53 3716.42 3760. 82 3800 .00 19. 22 217. 02 3736.26 3780. 66 3850 .00 19. 74 211. 23 3783.40 3827. 80 3900 .00 20. 44 205. 77 3830.36 3874. 76 3950.00 21.30 200.69 3877.08 3921.48 Crv 4/100 3979.00 21.86 197.93 3904.05 3948.45 SV2 3986.49 21.96 197.18 3911.00 3955.40 4000.00 22.16 195.84 3923.52 3967.92 4050.00 22.98 191.08 3969.70 4014.10 4100.00 23.93 186.66 4015.57 4059.97 4150.00 25.00 182.58 4061.08 4105.48 Crv 4/100 4179.00 25.66 180.36 4087.30 4131.70 4200.00 25.52 178.44 4106.24 4150.64 4250.00 25.29 173.81 4151.40 4195.80 4300.00 25.20 169.12 4196.63 4241.03 SV1 4314.77 25.20 167.74 4210.00 4254.40 -120.83 -129.37 -122.14 --- 12.00 -123.49 -132.65 -124.84 80 .00E 0.00 -127.70 -138.05 -129.11 77 .63E 4.00 -136.90 -151.84 -138.44 72 .16E 4.00 -144.92 -166.93 -146.61 67 .04E 4.00 -151.76 -183.29 -153.62 62 .29E 4.00 -155.18 -193.35 -157.14 70 .00E 4.00 -155.99 -196.01 -157.99 69. 30E 4.00 -157.39 -200.88 -159.43 68 .06E 4.00 -161.65 -219.53 -163.88 63 .67E 4.00 3.48 b`JOVL8O.C1 3.49 5960284.39 3.54 5960275.29 3.54 5960274.75 3.59 5960263.66 3.64 5960259.79 3.65 5960256.45 3.68 5960250.94 3.75 5960236.91 3.82 5960221.63 3.88 5960205.10 3.92 5960194.95 3.92 5960192.26 3.94 5960187.36 4.00 5960168.61 -164 .50 -239.18 -166.93 59.61 L 4.00 4.05 5960148.89 -165 .94 -259 .81 -168.58 55 .89E 4.00 4.10 5960128.22 -166 .13 -272 .21 -168.89 100 .52E 4.00 4.13 5960115.82 -165 .94 -281 .28 -168.80 98 .80E 4.00 4.15 5960106.76 -164 .28 -302 .66 -167.35 94 .61 L 4.00 4.20 5960085.42 -160 .91 -323 .74 -164.19 90 .37E 4.00 4.24 5960064.43 -159. 58 -329. 90 -162.93 89. 12E 4.00 4.26 5960058.30 O`Jlb`JL.DL IV /V.L`JOUb3U0 VV -148.4404/U44 691591.75 N 70.29605086 W 148.44847684 691583.20 N 70.29602661 W 148.44854788 691582.69 N 70.29602516 W 148.44855212 691572.23 N 70.29599561 W 148.44863911 691568.91 N 70.29598527 W 148.44866682 691566.29 N 70.29597633 W 148.44868870 691562.16 N 70.29596156 W 148.321 691553.19 N 70.29592388 W 148. 878 691545.40 N 70.29588267 W 148. 496 691538.81 N 70.29583798 W 148.44892167 691535.55 N 70.29581049 W 148.44895019 691534.77 N 70.29580321 W 148.44895702 691533.46 N 70.29578992 W 148.44896869 691529.48 N 70.29573897 W 148.44900472 691526.93 N 70.29568529 W 148.44902943 691525.81 N 70.29562894 W 148.44904279 691525.81 N 70.29559506 W 148.44904533 691526.14 N 70.29557028 W 148.44904456 691528.13 N 70.29551185 W 148.44903286 691531.83 N 70.29545428 W 148.44900726 691533.24 N 70.29543745 W 148.44899705 WeIlDesign Ver SP 2.1 Bld(users) 18-29\18-29\Plan 18-29C\18-29C (P4) Generated 4/22/2009 11:19 AM Page 1 of 4 Measured Azimuth Vertical NS EW Mag 1 Grav Directional Comments Inclination Subsea TVD TVD DLS Northing Easting Latitude Longitude Depth Tru® Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftU3 ftUS 435U.UU ZS.Yb 164.43 4Z41.t5/ 4Y15b.Z/ -155.153 -344.4/ -15y.3Z i5b."13L 4.UU 4.Z`J 5y6VV43.if3 4400.00 25.47 159.79 4287.05 4331.45 -149.04 -364.84 -152.74 81.93E 4.00 4.33 5960023.64 4450.00 25.82 155.24 4332.13 4376.53 -140.56 -384.82 -144.47 77.83E 4.00 4.37 5960003.87 UG4 UG3 4500. 00 26.31 150. 82 4377.05 4421 .45 -130.40 -404.39 -134 .50 73 .87E 4550. 00 26.93 146. 58 4421.75 4466 .15 -118 .57 -423.51 -122 .86 70 .07E 4600. 00 27.67 142. 53 4466.18 4510 .58 -105 .08 -442.18 -109 .56 66 .47E 4650. 00 28.52 138. 69 4510.29 4554 .69 -89 .95 -460.36 -94 .61 63 .08E 4700. 00 29.48 135. 06 4554.03 4598 .43 -73 .20 -478.04 -78 .04 59 .91 L 4750. 00 30.53 131. 65 4597.33 4641 .73 -54 .84 -495.19 -59 .86 56 .96E 4800. 00 31.66 128. 46 4640.15 4684 .55 -34 .91 -511.79 -40 .10 54 .22E 4850. 00 32.86 125. 47 4682.43 4726 .83 -13 .43 -527.83 -18 .77 51 .69E 4874. 57 33.48 124. 07 4703.00 4747. 40 -2. 30 -535.49 -7. 73 50. 52E 4900. 00 34.13 122. 67 4724.13 4768 .53 9 .59 -543.27 4 .09 49 .36E 4950. 00 35.47 120. 05 4765.19 4809 .59 34 .11 -558.11 28 .46 47 .21 L 5000. 00 36.85 117. 61 4805.56 4849 .96 60 .09 -572.32 54 .30 45 .23E 5050. 00 38.28 115. 31 4845.19 4889 .59 87 .52 -585.89 81 .59 43 .42E 5100. 00 39.75 113. 16 4884.04 4928 .44 116 .35 -598.81 110 .29 41 .75E 5134. 02 40.78 111. 78 4910.00 4954. 40 136. 75 -607.21 130. 61 40. 69E 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.41 5959984.57 4.44 5959965.75 4.48 5959947.43 4.51 5959929.63 4.55 5959912.38 4.58 5959895.70 4.61 5959879.61 4.64 5959864.13 4.66 5959856.75 4.68 5959849.27 4.71 5959835.06 4.74 5959821.51 4.77 5959808.64 4.80 5959796.47 4.82 5959788.59 by15J/.Z3 N /V.Zy53y/64 VV 1415.4415yb/C1 691544.32 N 70.29534199 W 148.44891454 691553.10 N 70.29528741 W 148.44884753 691563.56 N 70.29523396 W 148.44876686 691575.69 N 70.29518170 W 148.44867262 691589.46 N 70.29513071 W 148.44856493 691604.86 N 70.29508103 W 148.44844392 691621.88 N 70.29503274 W 148.973 691640.49 N 70.29498589 W 148.44816254 691660.67 N 70.29494053 W 148.44800252 691682.40 N 70.29489673 W 148.44782987 691693.63 N 70.29487579 W 148.44774045 691705.64 N 70.29485454 W 148.44764479 691730.38 N 70.29481400 W 148.44744751 691756.58 N 70.29477517 W 148.44723828 691784.20 N 70.29473809 W 148.44701734 691813.22 N 70.29470282 W 148.44678497 691833.75 N 70.29467986 W 148.44662047 5150. 00 41.26 111.14 4922.06 4966.46 146 .55 -611 .04 140. 37 40 .21 L 4.00 4.83 5959785 .00 691843.60 N 70. 29466938 W 148.44654145 5200. 00 42.81 109.24 4959.19 5003. 59 178 .09 -622 .59 171. 79 38 .80E 4.00 4.86 5959774 .26 691875.31 N 70. 29463783 W 148.44628707 5250. 00 44.38 107.45 4995.41 5039 .81 210 .92 -633 .44 204. 52 37 .50E 4.00 4.89 5959764 .25 691908.29 N 70. 29460820 W 148.44602215 5300. 00 45.98 105.76 5030.65 5075 .05 245 .01 -643 .57 238. 50 36 .31 L 4.00 4.91 5959754 .99 691942.52 N 70. 29458053 W 148.44574701 5350. 00 47.60 104.16 5064.88 5109 .28 280 .31 -652 .97 273. 71 35 .21 L 4.00 4.94 5959746 .50 691977.96 N 70. 29455485 W 148.44546198 5400.00 49.25 5450.00 50.91 5500.00 52.59 5550.00 54.29 5600.00 56.00 End Crv UG1 WS2 WS1 Crv 4/100 5650.00 5700.00 5750.00 5800.00 5850.00 5865.10 6160.04 7580.75 8063.07 8206.88 57.72 59.45 61.19 62.95 64.71 65.24 65.24 65.24 65.24 65.24 8250.00 8300.00 65.23 65.24 WeIlDesign Ver SP 2.1 Bld( users ) 102.63 5098. 06 5142.46 316.78 -661.62 310.09 34 .20E 4.00 4.97 5959738.77 692014. 55 N 70. 29453119 W 148.44516742 101.19 5130. 15 5174.55 354.37 -669.53 347.61 33 .27E 4.00 5.00 5959731.82 692052. 26 N 70. 29450958 W 148 367 99.80 5161. 10 5205.50 393.05 -676.68 386.22 32 .42E 4.00 5.02 5959725.66 692091. 03 N 70. . 29449005 W 148. 112 98.48 5190. 89 5235.29 432.76 -683.05 425.87 31 .63E 4.00 5.05 5959720.30 692130. 83 N 70. 29447263 W 148. 013 97.22 5219. 46 5263.86 473.46 -688.65 466.51 30 .91 L 4.00 5.08 5959715.74 692171. 59 N 70. 29445732 W 148.44390111 96.00 5246. 80 5291.20 515.09 -693.47 508.10 30 .24E 4.00 5.10 5959711.98 692213. 29 N 70. 29444416 W 148.44356444 94.84 5272. 86 5317.26 557.61 -697.50 550.57 29 .63E 4.00 5.13 5959709.04 692255. 85 N 70. 29443315 W 148.44322055 93.71 5297. 62 5342.02 600.95 -700.73 593.89 29 .07E 4.00 5.15 5959706.92 692299. 23 N 70. 29442431 W 148.44286986 92.62 5321. 03 5365.43 645.08 -703.16 638.00 28 .56E 4.00 5.18 5959705.61 692343. 39 N 70. 29441766 W 148.44251278 91.56 5343. 09 5387.49 689.94 -704.79 682.84 28 .10E 4.00 5.20 5959705.12 692388. 25 N 70. 29441319 W 148.44214975 ~~ 91.25 5349 .47 5393.87 703.62 -705.13 696.51 -- 4.00 5.21 5959705.14 692401. 93 N 70. 29441227 W 148.44203905 91.25 5473. 00 5517.40 971.43 -710.95 964.29 --- 0.00 5.30 5959706.15 692669. 75 N 70. 29439629 W 148.43987122 91.25 6068. 00 6112.40 2261.46 -738.98 2254.09 --- 0.00 5.59 5959711.02 693959. 77 N 70. 29431894 W 148.42942926 91.25 6270. 00 6314.40 2699.41 -748.50 2691.97 --- 0.00 5.66 5959712.67 694397. 73 N 70. 29429255 W 148.42588427 91.25 6330 .22 6374.62 2829.99 -751.34 2822.53 90 .90E 0.00 5.68 5959713.16 694528. 30 N 70. 29428466 W 148.42482737 89.35 6348 .29 6392.69 2869.14 -751.54 2861.68 90 .11 L 4.00 5.70 5959713.96 694567. 44 N 70. 29428407 W 148.42451038 87.14 6369 .24 6413.64 2914.50 -750.15 2907.06 89 .18E 4.00 5.71 5959716.51 694612. 77 N 70. 29428782 W 148.42414303 18-29\18-29\Plan 18-29C\18-29C (P4) Generated 4/22/2009 11:19 AM Page 2 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS CIIU li1V OJVJ.G.7 0.7.G4 O/.UU OJ/U.OU 041.7.VU Ly 1 /.44 -/.7U.UU L`J 1 V.UU -- Crv 4/100 9003.25 65.24 87.00 6663.77 6708.17 3551.85 -716.73 3544.78 98.20E End Crv 9042.97 65.02 85.26 6680.48 6724.88 3587.78 -714.30 3580.74 --- CM2 9678.90 65.02 85.26 6949.00 6993.40 4161.76 -666.72 4155.23 --- CM1 11073.82 65.02 85.26 7538.00 7582.40 5420.79 -562.34 5415.38 -- Drp 4/100 11114.77 65.02 85.26 7555.29 7599.69 5457.75 -559.27 5452.37 170.35R 11150.00 63.63 85.53 7570.55 7614.95 5489.38 -556.72 5484.02 170.24R 11200.00 61.66 85.91 7593.52 7637.92 5533.62 -553.41 5528.31 170.06R 11250.00 59.69 86.31 7618.01 7662.41 5577.08 -550.45 5571.80 169.87R 11300.00 57.73 86.73 7643.97 7688.37 5619.70 -547.86 5614.44 169.65R 11350.00 55.76 87.16 7671.39 7715.79 5661.43 -545.63 5656.19 169.41 R 11400.00 53.79 87.62 7700.23 7744.63 5702.21 -543.77 5696.99 169.15R 11450.00 51.83 88.10 7730.45 7774.85 5741.99 -542.28 5736.80 168.86R 11500.00 49.87 88.60 7762.02 7806.42 5780.74 -541.16 5775.55 168.54R 11550.00 47.91 89.14 7794.89 7839.29 5818.39 -540.42 5813.22 168.19R 11600.00 45.95 89.71 7829.03 7873.43 5854.91 -540.04 5849.74 167.80R End Crv 11624.43 45.00 90.00 7846.16 7890.56 5872.32 -540.00 5867.16 -- THRZ 11737.34 45.00 90.00 7926.00 7970.40 5952.16 -540.00 5947.00 --- BHRZ / TJA 12018.77 45.00 90.00 B 125.00 8169.40 6151.15 -540.00 6146.00 --- TSAG 12024.41 45.00 90.00 8128.99 8173.39 6155.14 -540.00 6149.99 --- 12024.43 45.00 90.00 8129.00 8173.40 6155.15 -540.00 6150.00 --- 7" Csg 12024.44 45.00 90.00 8129.01 8173.41 6155.16 -540.00 6150.01 --- TSHU 12072.51 45.00 90.00 8163.00 8207.40 6189.15 -540.00 6184.00 --- TSAD 12150.29 45.00 90.00 8218.00 8262.40 6244.15 -540.00 6239.00 --- TCGL 12295.96 45.00 90.00 8321.00 8365.40 6347.14 -540.00 6342.00 --- BCGL 12387.88 45.00 90.00 8386.00 8430.40 6412.14 -540.00 6407.00 --- Crv 10/100 12529.43 45.00 90.00 8486.09 8530.49 6512.22 -540.00 6507.09 HS 12550.00 47.06 90.00 8500.37 8544.77 6527.03 -540.00 6521.89 HS 7218 12594.83 51.54 90.00 8529.60 8574.00 6561.00 -540.00 6555.87 HS 12600.00 52.06 90.00 8532.80 8577.20 6565.06 -540.00 6559.93 HS 12650.00 57.06 90.00 8561.78 8606.18 6605.78 -540.00 6600.66 HS 12661.56 58.21 90.00 8567.97 8612.37 6615.54 -540.00 6610.42 --- 12663.64 58.21 90.00 8569.06 8613.46 6617.31 -540.00 6612.19 HS TDF 12668.48 58.70 90.00 8571.60 8616.00 6621.44 -540.00 6616.32 HS 12700.00 61.85 90.00 8587.23 8631.63 6648.81 -540.00 6643.68 HS 12750.00 66.85 90.00 8608.86 8653.26 6693.86 -540.00 6688.74 HS 12800.00 71.85 90.00 8626.49 8670.89 6740.63 -540.00 6735.51 HS 12850.00 76.85 90.00 8639.98 8684.38 6788.76 -540.00 6783.64 HS 12900.00 81.85 90.00 8649.21 8693.61 6837.88 -540.00 6832.77 HS 12950.00 86.85 90.00 8654.14 8698.54 6887.62 -540.00 6882.51 HS 4.UU 0.00 4.00 0.00 0.00 0.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10.00 10.00 10.00 10.00 10.00 0.00 10. 00 6.20 5960021.18 10 :00 6.21 5960021.87 10 .00 6.23 5960023.02 10 .00 6.24 5960024.22 10 .00 6.26 5960025.44 10 .00 6.28 5960026.70 10 .00 6.29 5960027.96 O./7 byby/"I b./3 5.80 5959766.18 5.81 5959769.52 5.88 5959831.74 6.00 5959968.22 6.00 5959972.23 6.01 5959975.58 6.02 5959980.02 6.03 5959984.09 6.04 5959987.77 6.06 5959991.06 6.07 5959993.96 6.08 5959996.47 6.08 5959998.57 6.09 5960000.28 6.10 5960001.58 6.11 5960002.07 6.11 5960004.11 6.13 5960009.18 6.13 5960009.28 6.13 5960009.28 6.13 5960009.28 6.13 5960010.15 6.13 5960011.55 6.14 5960014.18 6.14 5960015.84 6.15 5960018.39 6.15 5960018.77 6.17 5960019.63 6.17 5960019.74 6.19 5960020.78 6.19 5960021.02 6.19 5960021.07 by4blb./1 N /U.Ly4Lt3tSLS W 14tf.41411y1y 695249.39 N 70.29437837 W 148.41898005 695285.27 N 70.29438497 W 148.41868893 695858.33 N 70.29451416 W 148.41403775 697115.33 N 70.29479713 W 148.40383514 697152.23 N 70.29480542 W 148.40353564 697183.81 N 70.29481232 W 148.40327938 697227.99 N 70.29482129 W 148.40292083 697271.39 N 70.29482928 W 148.471 697313.95 N 70.29483628 W 148.40222342 697355.63 N 70.29484228 W 148.40188541 697396.37 N 70.29484728 W 148.40155507 697436.12 N 70.29485127 W 148.40123282 697474.83 N 70.29485425 W 148.40091904 697512.46 N 70.29485620 W 148.40061411 697548.96 N 70.29485714 W 148.40031841 697566.37 N 70.29485722 W 148.40017742 697646.18 N 70.29485705 W 148.39953102 697845.10 N 70.29485661 W 148.39791992 697849.09 N 70.29485660 W 148.39788761 697849.10 N 70.29485660 W 148.39788753 697849.11 N 70.29485660 W 148.39788745 697883.09 N 70.29485653 W 148.39761227 697938.07 N 70.29485640 W 148.39716699 698041.03 N 70.29485617 W 148.39633310 698106.00 N 70.29485602 W 148.3 686 698206.05 N 70.29485578 W 148. 54 698220.85 N 70.29485575 W 148.39 7668 698254.82 N 70.29485567 W 148.39460159 698258.88 N 70.29485566 W 148.39456870 698299.58 N 70.29485556 W 148.39423902 698309.34 N 70.29485554 W 148.39416000 698311.11 N 70.29485553 W 148.39414568 698315.24 N 70.29485552 W 148.39411223 698342.59 N 70.29485546 W 148.39389069 698387.63 N 70.29485535 W 148.39352590 698434.39 N 70.29485523 W 148.39314723 698482.50 N 70.29485512 W 148.39275756 698531.60 N 70.29485499 W 148.39235986 698581.33 N 70.29485487 W 148.39195716 WeIlDesign Ver SP 2.1 Bld( users) 18-29\18-29\Plan 18-29C\18-29C (P4) Generated 4/22/2009 11:19 AM Page 3 of 4 Comments Measured Inclination Azimuth SufrSea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Tree Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 700 ft Index ftUS ftUS lt5-LyG Igil lL`J25"L~l `JV.VV `JU.VU tSO~~.VU i5b`J`J.4U b`Jl`J.~II -~4U.UU O`Jl4.VV `JU. UVL IV.UV 0.3U .7`JOVULB.// O`J601L.81 IV /V .L`J4O~4/`J VV -148. 3`J-I/ULLU End Crv 12988.36 90.00 89.32 8655.00 8699.40 6925.96 -539.96 6920.85 --- 10.00 6.31 5960028. 98 698619.65 N 70 .29485489 W 148. 39164675 Crv 6/100 14398.76 90.00 89.32 8655.00 8699.40 8336.02 -523.10 8331.15 90. 00E 0.00 6.43 5960081. 80 700028.98 N 70 .29489703 W 148. 38022883 14400.00 90.00 89.24 8655.00 8699.40 8337.26 -523.09 8332.39 90. 00E 6.00 6.43 5960081. 85 700030.22 N 70 .29489707 W 148. 38021879 14450.00 90.00 86.24 8655.00 8699.40 8387.19 -521.12 8382.35 90. 00E 6.00 6.44 5960085. 09 700080.10 N 70 .29490230 W 148. 37981433 14500.00 90.00 83.24 8655.00 8699.40 8436.93 -516.53 8432.13 90. 00E 6.00 6.45 5960090. 94 700.129.75 N 70 .29491467 W 148. 37941124 18-29C Tgt 2 14512.35 90.00 82.50 8655.00 8699.40 8449.16 -515.00 8444.38 90. 00E 6.00 6.45 5960092. 79 700141.96 N 70 .29491882 W 148. 37931205 14550.00 90.00 80.24 8655.00 8699.40 8486.33 -509.35 8481.61 90. 00E 6.00 6.46 5960099. 38 700179.03 N 70 .29493414 W 148. 37901062 . 14600.00 90.00 77.24 8655.00 8699.40 8535.26 -499.59 8530.64 90. 00E 6.00 6.47 5960110. 39 700227.79 N 70 .29496065 W 148 357 End Crv 14626.60 90.00 75.64 8655.00 8699.40 8561.05 -493.35 8556.50 --- 6.00 6.48 5960117. 28 700253.48 N 70 .29497761 W 148. 37840415 TD / 4-1/2" Lnr 15792.33 90.00 75.64 8655.00 8699.40 9687.40 -204.33 9685.82 -- 0.00 6.56 5960435. 00 701375.00 N 70 .29576346 W 148. 36925810 Legal Description: Northing (Y) fftUSl Easting fXl fftUSl Surface : 3805 FSL 86 FEL S24 T11 N R14E UM 5960392.23 691687.70 18-29C Tgt 1 : 3262 FSL 3410 FEL S20 T11 N R15E UM 5960028.77 698612.81 TD / BHL : 3595 FSL 637 FEL S20 T11 N R15E UM 5960435.00 701375.00 WeIlDesign Ver SP 2.1 Bld( users) 18-29\18-29\Plan 18-29C\18-29C (P4) Generated 4/22/2009 11:19 AM Page 4 of 4 by Schlumherger W~`L DS18-29C (P4) FIELD Prudhoe Bay Unit - EOA STRDCTURE DS-18 Magretk Parameters Surtace Lorali°n NA02] Alaska SMIe Planes. Zone 04, US Feel MisralMne°us Motlel: BGGM 2000 Dp: &1.940' Dale: Apri122. 2009 Lal: N]01 ] 46 619 Nwibing: 59fi0392.23 M15 Gritl GOnV: ~t 0614]282' Sbt 1629 NO RaI: R°lary Tabk (44.40 X above MSL) Mag Dec'. X23655° FS: 5]]14.fi nT Lon'. W148 26 51 640 EasSng: fi9166].]011US Scala Fad: 0.999941 ]409 Plan: 18~29G (P4~ Srvy Dale: April 22. 2009 1200 2400 3600 4800 6000 7200 8400 9600 3600 4800 0 0 N C_ 6000 Ii 7200 8400 • 3600 4800 6000 • 7200 8400 (P4) 1200 2400 3600 4800 6000 7200 8400 9600 Vertical Section (ft) Azim = 90.58°, Scale = 1(in):1200(ft) Origin = 0 N/-S, 0 E/-V by Schlumberger ~" DS18-29C (P4) FIE`D Prudhoe Bay Unit - EOA STRDGTGRE DS-18 Magre <Parame~ers f Surface LOralion NAD2]RIazMa Stale Planes. bne Od, US Feet Mlscellaneo Motlel: BGGM 2008 Dip: 80.940° Dale Ppn122. 2009 La[ N]01]66819 NonM1iy: 5980392.23 flU5 GnC Conv: •t dfi14]282° Sbl. t8-29 NO Raf: Rotary TaEle (0400M1above MSLI Mag Dec: •22855° FS'. 5]]146 nT Lon'. Wt482651.840 Easlifg: 691681.]0 M1US Scale Fact: 0.999941 ]409 Plan: tB-29C (P4) Srvy Dale'. Apn122. 2009 0 1200 2400 3600 4800 6000 7200 8400 9600 24C 12C n n n Z o ease 0 N C 11 N U V ~ -12( v -241: 2400 • 1200 0 • -1200 -2400 0 1200 2400 3600 4800 6000 7200 8400 9600 «< W Scale=1(in):1200(ft) E »> Comparry: Nortti America -ALASKA - BP _ Locai Co-ordinate Ralerence: Well 1 &29 Project: Prudhoe Bay TW Reference: 18-290 plan ~ 44.40ft (Nabors 7ES) Raferance Site: PB DS 18 MD Rt+fererrce: 18-290 plan (~ 44.40ft (Nabors 7ES) Site,F.rror: O.OOft Notch Reference; True Reference Welh 18-29 Survey Calculation Method: Min~num Curvature Well Error; O.OOft Output amore aro at 1.04 sigma Reference Wellbore Plan 18-290 Database: ; EDM .16 - Anc Prod - WH24P Reference Dsalgn: Plan #418-290 Offset TVD Reference: 'Offset Datum Refi~rence' Plan #4 18-290 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refen Depth Range: 3,750.00 to 15,792.33ft Scan Method: Trav. Cylinder North Survey Tool Program Date 4/22!2009 From To (ft} (ft) Survey (WeRbone~ Tool Name Descrlptlon 464.50 3,650.73 1 : MWD -Standard (18-29) MWD MWD -Standard 3,650.73 5,100.00 Plan #4 18-290 (Plan 18-290) MWD MWD -Standard 3,650.73 12,024.00 Plan #4 18-290 (Plan 18-290) MWD+IFR+MS MWD +IFR + Mutti Station --- ~2~2oo~-r~~z3san~f - -- --- Page 2 of 5 COMPASS 2003.16 Build 70 _.__ xp oration Alas~Ca ~ - -.-. -- - Rnfico~ision R-epor~ - Company: North America -ALASKA - BP Project; Prudhoe Bay Rs/eronce Site: PB DS 18 Site Error: O.OOft .:Reference Welt: ' 18-29 wen. Error: - _ o.ooft Reference 1Nellbore ' Plan 18-29C RaMr~ Design Pin #418-29C toca! Cognate Reference: Well 18-29 ND Reference; ' 18-29C plan ~ 44,40ft (Nabors TES) MD fteMrence: 18-29C plan ~ 44.40ft (Nabors TES) North Reference: True Survey lalcutation Method: Minimum Curvature Output errors are at 1.00 sk~ma Database: ` EDM .16 - Anc Prod - WH24P Offset ND Rahrencea ,.,.Offset Datum Summary _ Reference Offset Centre to No-Go Al lowable Measured Measured Centre Dlatance Devlatlon Warning Bite Name Depth Depdr Distance (ft) from Plan OfTset Well - WelErore -Design _ (ft) _ (ft) (fq (ft) Lis DS 02 _ - _ ~:79g$1~- - 7;440:0~ ~19:84 _ tY3:>18- X09.60 Pass~dlajor ' L2-03A - L2-03A - L2-03A 6,796.66 7,440.00 817.84 113.88 709.60 Pass -Major Risk L2-08 - L2-08 - L2-08 12,750.00 11,275.00 763.95 444.46 393.97 Pass -Major Risk L2-08A - L2-08A - L2-08A 15,792.33 14,080.00 460.73 530.71 -69.77 FAIL -Major Risk Lis DS 03 L3-15 - L3-15 - L3-15 15,729.35 11,365.00 728.26 336.77 398.51 Pass -Major Risk Lis LPC LPC-02 - LPC-02 - LPC-02 8,122.75 7,265.00 538.75 159.09 412.85 Pass -Major Risk PB DS 18 18-01 -18-01 - 18-01 3,753.89 3,850.00 337.48 80.07 268.14 Pass -Major Risk 18.01 -18-01A -18.01A 3,753.89 3,850.00 337.48 80.07 268.14 Pass -Major Risk --- - - - ~;752?.f2- ~8id:06 - 90:6 -- - 73:2 -ass - Rfalor is --- 18-02 -18-02A -1 S-02A 3,752.34 3,810.00 90.57 73.20 18.63 Pass -Major Risk ~_8-DZ1$-02APB1_-_18-02AP_Bl_----- _ _ ____ -_- 3,7~ ~,816.0~ 90-52 X3.20_- -__18.63-- Pass - Maior Risk- - 18-02 -Plan 10, 18-026 -Plan #10 3,752.34 3,810.00 90.57 72.92 18.92 Pass -Major Risk 18-03 -18-03 -18-03 4,403.19 4,495.00 66.23 119.43 X6.11 FAIL -Major Risk 18-03 -18-03A -18-03A 4,403.80 4,495.00 66.33 119.47 -46.11 FAIL -Major Risk 18-03 -18-036 -18-036 4,404.45 4,495.00 66.43 119.50 X6.10 FAIL -Major Risk 18-04_18-04 -18-04 ___ _ ______ ___ ___-___3 750.00_ 3,830.00 745.51 _ 61.90-_ -_ 691.21 Pass -Major Risk 18-04 - '18-U4A -18-04A 3,750.00 3,830.00 745.51 61.90 691.21 Pass -Major Risk 18-04 - 18-046 - 18-048 3,750.00 3,820.00 745.87 61.91 691.56 Pass -Major Risk 9"6-04 =18={t4~fllaTY#..6b__ _ _ _ - ___- - _3~750~90 ~~829.00 - - 745.8~ ~'4:-74 _ c ~ ~ _-v9,'-, ~ n___ r~J ~utalor _ 18-04 -18-046P61 - 18-046PB1 3,750.00 3,820.00 745.87 61.91 691.56 Pass -Major Risk 18-11 -18-11 DPN - 18-11 DPN 3,750.00 3,970.00 693.14 58.83 635.12 Pass -Major Risk _ 18-12 - 18-12 -18-12 _ 9,118.44 - 7,750.00 315.73 270.36 65.87 Pass -Major Risk 18-12 -18-12A - 18-12A 9,118.44 7,750.00 315.73 270.86 65.42 Pass -Major Risk 18-12 -18-128 -18-126 9,118.44 7,750.00 315.73 270.91 65.40 Pass -Major Risk 18-13 -18-13 -18-13 6,556.91 6,040.00 515.77 104.28 421.52 Pass -Major Risk 18-13 -18-13A -18-13A 6,555.55 6,045.00 515.66 103.65 422.25 Pass -Major Risk ____ ------;t8='f~ 18=136 =18=T3~ ~555~5~ b,045:06 - 515~fi~- - TOS~d 42~3T - ass - alor ~s 18-13 -18-136 -Plan #7 6,555.55 6,045.00 515.66 103.54 422.37 Pass -Major Risk 't$-1 ~ - 1 R-13RPR1 - '~$-1 ~RPR7_- ~Fi 5555- -_6,045 00 515 RR 103.54 422..37 PaSS~MajOr__RISk_-- 18-13 - 18-136P61 -Plan #2 6,555.55 6,045.00 515.66 103.54 422.37 Pass -Major Risk 18-13 -18-136PB2 -18-136PB2 6,555.55 6,045.00 515.66 103.52 422.39 Pass -Major Risk a #~ --- -- ---.. ___.6;5555b- - 64500 5Y566 -'i03:57 - - ~22~39 Pass= lGTaj~r R'is ---- 18-13 - 18-13BP63 -18-13BPB3 6,555.55 6,045.00 515.66 103.52 422.39 Pass -Major Risk _ 18-13 -18-136P63=Plan #4 __ _.___- __..__ __6 555.55 6045.00 51.5.66 103,52 _ 422.39 - Paass -Major Risk _____.__ 18-13 -18-13PB7 - 18-13PB1 6,556.91 6,040.00 515.77 104.33 421.48 Pass -Major Risk 18-13 -18-13PB2 -18-13PB2 6,556.91 6,040.00 515.77 104.33 421.48 Pass -Major Risk 18-14 -18-14 - 18-14 6,243.88 6,260.00 603.07 92.02 521.80 Pass -Major Risk 18-14 -18-14A -18-14A 6,242.17 6,255.00 603.08 91.95 521.80 Pass -Major Risk 18-14 -18-14APB1 - 18-14AP61 6,242.17 6,255.00 603.08 91.95 _ 521.80 Pass -Major Risk 18-14 -18-148 -18-148 _ 6 242.99 6,255.00 603.07 91.99 521.80 Pass -Major Risk 18-14 -18-148 - 18-146 wp06 6,242.99 6,255.00 603.07 91.84 521.94 Pass -Major Risk 18-14 - 18-1 _ 18-140 .. - - _ -- -_ -- -. ~24~~99 ~2~5~00 - -- ~i0-3~~ _~J1 X99 52:80 - o~~~ sew:,,. o:~~ ___ -- 18-15 - 18-15 -18-15 3,750.00 4,120.00 1,123.30 52.91 1,075.08 Pass -Major Risk 18-17 - 18-17 -18-17 3,750.00 3,875.00 1,341.68 77.52 1,272.49 Pass -Major Risk - T~f9~1 --19 -18~~ -3;72-34 - -~.77~ ~ 7Q6~4 - - T1:~6 ass Ma1or 18-21 - 18-21 -18-21 8,206.88 6,985.00 728.75 222.23 542.54 Pass -Major Risk - -18=21A--18=21A__ _ __.___-__- _ R ~n~ R8 6,985.00- X28_75- ~~~ ~~ __ _._542.5a Pass-_Major . 18-22 -18-22 -18-22 5,872.47 5,535.00 741.66 59.47 684.18 Pass - Major Risk 'f~12597iiGf Page 3 of 5 COMPASS 2003.16 Build 70 Company: North America -ALASKA - BP Local Go•ordirrate Reference: Well 18-29 _ 'Project: Prudhoe Bay TVD Reference; ! 18-290 plan ~ 44,40ft (Nabors 7ES) Rehrence 3ke; PB D318 MD Reference:' ' 18-290 plan ~ 44.40ft (Nabors 7ES) :Site Error: ' O.OOft North Reference: !True Referenc® Welh 18-29 Survey Caloulation Method: ' !Minimum Curvature Well Error. O.OOft Output errors are et 1.00 sigma Reference Mlelitsore ' Plan 18-290 '.Database: EDM .16 - Anc Prod - WH24P Reference pesign: Plan#418-290 08'set TYD`Rehrence•. ' ! Offset Datum Summary Reference Offset Centre to' No-Go Allowable Measured Measured Centre Distance Devlatlon Warning Sib Name Depth ' Depth Distance fft) from Pian Offset WeN'- WelNsore • Design (tt) _ (tt) (tt) (ft) PB DS 18 - - 22A - 47- __ ._~~ ~9~47 ~84~18- _1'ass-RRajarRistc _ ._---- 18-25 -18-25 -15-25 12,476.79 11,135.00 413.41 475.51 -31.82 FAIL -Major Risk 18-25A -18-25A - 18-25u4 12,459.56 11,110 00 405.53 475.56 -40.38 FAIL -Major Risk ____,_ 18-25APB1 - 18-25AP61 - 18-25AP61 12,459.56 11,110.00 405.53 475.46 -40.28 FAIL -Major Risk 18-28 -18-28 -18-28 8,350.61 7,400.00 268.22 238.57 35.20 Pass -Major Risk 18-28P61 -18-28PB1 -18-28PB1 8,350.61 7,400.00 268.22 238.57 35.20 Pass -Major Risk 18-29 - '18-29 -18-29 3,793.47 3,800.00 1.19 12.80 -11.40 FAIL -Major Risk 18-29 -18-29A -18-29A 3,793.47 3,800.00 1.19 12.91 -11.51 FAIL -Major Risk 18-29 -18-296 -18-296 --- 3,793.37 _ 3,800.00 _ - - - 1.18 _ 12.92 --- -11.53 FAIL -Major-Risk _ _ _- 18-29 -18-296P61 -18-29BP61 3,793.37 3,800.00 1.18 12.92 -11.53 FAIL -Major Risk 18-30-~-18-30- - --z-187.29 - -6,270-.00 1 1~. ,a _ 184.1 ~oR1 as __p~~ ~Maj~-~k - 18-31 -18-31 -18-31 3,751.28 3,885.00 421.40 51.39 379.81 Pass -Major Risk 18-31 - 18-31A -18-31A 3,751.28 3,885.00 421.40 51.44 379.81 Pass -Major Risk ~3T =- T8=31PST~8=31 PS7 __-3,75T:2~ 3, ~ ~T Pass = 6lfajo~ Risk- -- ---__. 18-32 -18-32 -18-32 7,440.55 6,630.00 652.62 178.14 474.43 Pass -Major Risk -18-32=58~2A-1 f3-32A - - ---_ _- - __ _ __ __7 44.0.55 - 6-630-0~ B52B2 178-36 47422 P_ass~- lfAajoLRisk _ __ __ _ 18-32 -18-32A -Plan #103 7,440.55 6,630.00 652.62 178.38 474.19 Pass -Major Risk 18-32 -18-326 -18-326 7,440.55 6,630.00 652.62 179.63 472.94 Pass -Major Risk 18-33 -18-33 - 18-33 Out of range 18-33 -18-33A - 18-33A Out of range 18-33 - 18-33A -Plan ff3 ut o ran e g - 18-33 -18-33AP61 -18-8 33AP61 -_ _- --- - _ . - -- - ---- Out of range 18-34 -18-34 -1834 12,623.35 11,925.00 661.20 470.82 198.13 Pass -Major Risk - - - ---- - 4722/200J 1 f=~2:59AM - _- - - -Page4 of 5- _ ---- --_ -COMPASS 2003.16 Build 70 Project: Prudhoe Bay Site: PB DS 18 -- Well: 18-29 Wellbore: Plan 18-29C Design: Plan #4 18-29C From kop to TD Scan interval 100 ft Scale 1:100 All wells Major Risk o 90 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ft/in] From kop to TD Scan interval 100 ft Scale 1:100 8-03, 18-25, and L2-08 Risk 1:200 Project: Prudhoe Bay Site: PB DS 18 Well: 18-29 Wellbore: Plan 18-29C Design: Plan #4 18-29C 0 90 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation (100 ft/in] Alaska Department of ~ral Resources Land Adminish•ation ~m Page 1 of~~ Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources ~~ Alaska DNR Case Summary File Type: ADL File Number: 28321 ~ Prin_table Case File Summary See Township, Range, Section and Acreage? C Yes ~"_) No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract _ , File: ADL 28321 ~'"~ Search for Status Plat Updates As of 05/19/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tyne: 784 OIL & GAS LEASE COMP DNR Ufzit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2480.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype : NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 015E Section: 17 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 015E Section: 18 Section Acres: 599 Meridian: U Township: O11N Range: 015E Section: 19 Section Acres: 601 Meridian: U Township: O11N Range: 015E Section: 20 Section Acres: 640 Legal Description OS-28-1965 *** SALE NOTICE LEGAL DESCRIPTION *** C14-1 Sl TI l N, R 1 SE, UM 17, 18, 19, 20 2480.00 End of Case Summary Last updated on 05/1912009. http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=2832... 5/19/2009 Alaska Department of ~ral Resources Land Administration ~m Page 1 of~ Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 2$307 ~+Printable Case File__Summary See Township, Range, Section and Acreage? New search Yes ~'=i No LA$_Menu I Case Abstract ~ Case Detail I Land Abstract _~ File: ADL 28307 ~'`'''' Search _for _Status Plat Updates As of 05/19/2009 Customer 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1966] 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Tyne: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Locution: DOG DIV OIL AND GAS Case Status: 35 ISSUED States Date: 09/14/1965 Total Acres: 2560.000 Dcrte Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Strbt~pe: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Rarrge: 014E Section: 13 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 014E Section: 14 Section Acres: 640 Meridian: U Township: O11N Range: 014E Section: 23 Section Acres: 640 Meridian: U Township: O11N Range: 014E Section: 24 Section Acres: 640 Legal Description OS-28-1965 *SALE NOTICE LEGAL DESCRIPTION* C14-12811N 14E UM 13,14,23,24 2560.00 U- 3- 7 End of Case Summary Last updated on 0 5/1 912 0 0 9. http://dnr.alaska.gov/projects/las/Case_Summary.cfin?FileType=ADL&FileNumbei=2830... 5/19/2009 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~,~6lQyG~~ ~/~'~ ~(J-v?9~ PTD# o?09Q.SS Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: f~'C/Q„y0~.,~,~)/ POOL: ~.E'l/D.~P~E ~~I,L,1y~C//G Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (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. Non-Conventional Please note the following special condition of this permit:. Well production or production testing of coal bed methane is not allowed for (name of well) until after (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 program. Rev: 1 / 11 /2008 WELL PERMIT CHECKL{$T field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Wel( Name: PRUDHOE BAY UNIT 18.29C Program DEV Well bore seg ^ PTD#:2090550 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 1 PEND GeoArea 890 Unit 11650 ONOff Shore ~ Annular Disposal ^ Administration 1 Petmitfeeaitached--- - ---- ------- -- --- - ---- NA ----- ----- -- -- -- ------ - - -- -- -- - -- 2 Lease numberapRraRnate---- -- -- --- - - -- ------ Yom- -- --- -- - - - ------ -- -- -- -- --- - --------- 3 Uni-quewelinameandnumbe[- --- -- - - - -- - -- --- Yes- -- -- --- - ----- - -------- ---- -- -- - - ---- ----- 4 Well located in a-deFnedpaal-- - ---- - -- --- -- ----- Yes- -- - -- -- - - -- ------ 5 )Nell located properdistanoe_f[om drilling unit_boundary_ - - - - - - - - - - - - - - - - - - - Yes . _ _ _ _ _ - - _ - - . _ ------------------------------------------------------------- 8 WellloeatedpropRrdisianae-f[orrtatherwells------------------------------ Yes- ------------------------------------------------------------ 7 Sufficient acrsa9e available in_driUigg Unlt - - - - - - - - - - - - - - - - Yes - - - - - - - 2560 acres. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 Ifdsyiated,is-wellboreplatincluded-- -- ------ -- --- ---- ._ Yes- ---- --- --- ----- - -- --- -- ------ -- - - -- --- ----- 9 OpEratoronlyaffectadparty-- -- -- -- -- -- - --- ---- YES - ------- - -- -- --- -- ------- -- ------ -- -----~ --- 10 Operato[hasappr9priatebot~din.farce--------------------------------- N°-- ------BlanketBond#6194193.--------------------------------------------------- 11 Pe[mitcaDbeissuedwithout~nservalionarder---------------------------- Yes- ----.------.------------------------------------------------------------ Appr Date 12 Pem]itca[~beiasuedwlthoutadminigtrative_approval------------------------- Yes- -----.----------------------------------------------------------------- 13 CanpermltbeappravedbefarE1@iteY-wait---- -- ---- --- -- ------- Yes- ---- - -- -- - -- -- ~ ------- - ----- -- - --- -- -- -------- ACS 511912009 14 WelllocaiedwilhinareaeridstrataautbarizedbylnjQati9a9[de[#(put-IQ#in-comments)_(Far- NA__ _____________________________________________-__-__--__--_--___--------- 15 AIIwEOs_wiihin714_mileareeof[eYiewidentified(Fa[seNlcewellanly)--------------- -NA-- -------------------------------------------~--------------------------- 16 Pre-Rroducedinjector. duration ofprep[oductianlessthan3months-(Forsarvicewellan~r)-- NR__ _______________________________________________________________-.-------- 17 NoDaonven,gascanfarmsfoAS31,04.034(1.1.A),U~2.A-D) -- - --- ---- NA --- -- - ---- -- ------ --- ----- -- -- - -- -- - ------ - -- - 18 Cbndu_cto[string_provided______-___----------------------------_ NA__ ____._Canduatarset_inpS1$-29(192-193).---------.----------.-.-----------------.-- Engineerln9 19 Sudacecasing-pratectsallknownUSDWS__--._____________________-__ NA_ _____-Naaquifers,-AIQ4B,-conalus[on5.--__________-__._--_--______-_ 20 CMT-voladequate-taci[culakeon_canduator&surf-csg________________________ NA-_ --_.__Surfaceaasingsetin-RS 18-29.---_---______-_______--__-_-_-__-____--______ 21 CMT-vol-adequate_tatie-inlongsiripgtosurfcsg___________________________ Yes_ __-._New7"IinerwAl-be fullycemenledinia9-518"aasing.--______-__-___--______--______-_-__ 22 C-MT_willcoyerahknownproduativehorizans__-_-___-_-__--__.__-____-_ No__ _____Slo#edlinercompletion planned.________._.______________-_-___--_-___-_----- 23 CasingdesignSadequateforC,?B&_permafrost-------------------_--_-- Yes- -----------.------------------------------------------------------------ 24 Adequate tankage-or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YES - _ _ - - _ _ Rig equipped with steel pits. No reserve pii planned•_ All wasteto approved disposal well(s), _ _ - _ _ - _ _ - . - _ _ 25 Ifa_rs-dnll,has_a10-403 forabandanmeAtbeEnapRroaed--------------------- Ye$- ------30.9,166---,--------------.----.----------------.----------,----------- 26 Adequate weNbore Separationproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ . _ _ _ - Y_es . - _ - - _ _ Proximity analysis perfo[med. ClosSe approaahsS identified. Some we11s to be SI. , - _ _ _ - _ - - _ _ _ _ _ _ 27 Ii diverterregUired,daeSitmeEtrEgulations_______---------------------- NA-_ ______BQPStaak_vrillalready_beinplace,--------------------------------------____-- 28 program schematic & equip list adequate_ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Dulling fluid Yes _ _ - . _ _ _ Maximum Expeoied fo[malion pressure 7,4,BMWin-zone. _ MW-plannQd-up-ta 1Q.$ ppafar-HRZ-and 8.6.ppq in zorl pppr Date - TEM 512012009 29 BQPES,dolheymeetregulation-- - -- - ---- -- -- ----- Yes- - - - ---- - - -- - ------ - ----- -- ----- -- - ---- 30 BODE press rating approp[iate;lest to_(Rut psig in-commEnts)- _ _ - _ _ - _ _ _ _ _ _ _ - _ - - _ YES _ _ _ _ _ _ _ MASP calculated at 2477 psi. 35Q0-psi-BOP tastpianned_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ 31 Choke_manifaklcamplieswlAPl_RP•53(May$4)-------------------------- YeS- ----------------------------------------------- ---------------------- ii~~" 32 1Norkwillo4'asirwithoUtoperationshutdown----------------------------- YeS- ---------------------------------------------------------------------- 33 Is presence-of 1125 gas pr4ba41e _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . . _ _ . - - H2$ iS reported a1 pS 16._ Mud should preclude-H2S_on rig, Rg has Sensors and-alarms.- - - _ _ - _ _ _ - _ _ _ - _ 34 MechanicalcondRionofweliSwithinAQRyerified(.For-service well only)______________ NA__ --______---_--____.---_-_______-____________-.-_--___---_-_____-__._-__-_ 35 Permit-can betssuedw/ohyd[ogen_suifidemeasures----------------------- --K°- ------MdxlevelH2$an-pad was20ppm-(i11281Q8)---------------------------------------- Geology 36 Data-preseniedanpo}ential9verpressurezones- - - _ _ . _ _ - - _ Appr Date 37 SEismicanalysis. of shallow gas_zones- - - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 5119!2009 38 Seabed conditionsurvey_(ifaff•share)------------------------------- --h1A-- --------.-------------------------------------------- -- -- --- ----- 39 Coniaatnamelphoneforweekty-pla9-resSrepoQs-[e~loraioryonly~_______________ _Yes_ _---__RyanCiolkosz--564-5977,_-_______-._-_____-__--__-__--_---._-__-__________ Geologic Commissioner: Engineering PubNc Date: C ommissi~ner: Date Commissioner Date /I
