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Home My WebLink About208-099By Meredith Guhl at 12:51 pm, Jun 21, 2022 Abandoned 6/10/2022 MDG RBDMS 6/21/2022 MDG xGMGR07SEP2022DSR-12/15/22 ' 6.21.2022 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.06.21 12:25:34 -08'00' Monty M Myers ACTIVITYDATE SUMMARY 12/8/2021 Pre Rig MIT's (SIDETRACK) MIT-IA to 2627 psi ***PASS*** OA Integrity Test to 1280 psi ***PASS**** Loaded Tbg w/ 200 bbls of 110* crude. Pumped 9.3 bbls DSL down IA to bring pressure to 2780 psi for MIT-IA. IA lost 115 psi in 1st 15 mins and 38 psi in 2nd 15 mins for a total loss of 153 psi in 30 min test. PASS Bled IA to 1000 psi and got back ~2 bbls. Pumped 3.4 bbls DSL down OA on 2 test. 2nd test took pressure to 1351 psi. OA lost 35 psi in 1st 15 mins and 28 psi in 2nd 15 mins for a total loss of 63 psi in 30 min test. PASS Integeruty Test. Bled OA to 80 psi and got back ~2 bbls. Pad op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG ***Tags hung on IA and OA 1/13/2022 ***WELL S/I ON ARRIVAL***(sidetrack) DRIFTED w/ 20' x 3.70" DUMMY WHIPSTOCK & 3.80" CENT TO XN @ 8,801' MD ***WELL S/I ON DEPARTURE*** 1/26/2022 T/I/O= 2400/75/50 (Load TBG) Travel to location, spot in RU. Job continues next day 1/27/2022 Job continues from previous day. (Load TBG) Pumped 5 bbls 60/40 down TBG followed by 200 bbls KCL. Pumped 38 bbls crude and 3 bbls 60/40 for FP and FP surface lines and unit. Hang tags. WV,SV,SSV=closed IA, OA= OTG. FWHP's 0 1200/350. Well shut in upon departure 1/27/2022 ***WELL SHUT IN ON ARRIVAL*** (WHIPSTOCK SETTING) MIRU HES E-LINE. RIH W/ 4-1/2" BAKER MONOBORE PACKER WHIPSTOCK. HAVE DIFFICULTING FALLING IN HOLE. REACHED ~ 950' AND DECIDED TO PULL OOH TO CHECK TOOLS. NO ABNORMALITIES FOUND ON TOOLS. EXTREMEY STICKY RIH, WILL TRY RE-LOADING WELL WITH HOT FLUIDS AND RE-RUN. SUSPECT HYDRATES. LAY DOWN FOR THE NIGHT. ***JOB CONTINUES ON 28-JAN-22 WSR*** 1/28/2022 ( LRS UNIT 72) ON WEATHER STANDBY WITH HALLIBURTON E-LINE 1/29/2022 ***JOB CONTINUES FROM 27JAN22 WSR*** (Whipstock Setting) RIH & SET 4-1/2" BAKER MONOBORE KB PACKER WHIPSTOCK. TOWS @ 9055'. ORIENTED 181 DEGREES ROHS. RA TAGS INSTALLED. CORRELATED TO BAKER RPM LOG 4-JUNE-2014. WHIPSTOCK DRAWING IN U:DRIVE PICTURE FOLDER FOR REFERENCE. ***JOB CONTINUES ON 30JAN22 WSR*** 1/29/2022 T/I/O= 2375/60/60 Assist HEL w/ (SIDETRACK) Pumped 5 bbls 60/40 followed by 235 bbls 120*F 1%KCL and 38 bbls 160*F crude to load/kill and HOT freeze protect TBG. HEL in control of well upon departure. FWHPs= 1000/500/530 1/30/2022 Assist ELine (SIDETRACK) Pumped 100 bbls crude down Tbg for Eline. ELine in control of well per LRS departure. IA,OA=OTG 1/30/2022 ***JOB CONTINUES FROM 29JAN22 WSR*** (Mill) RIH W/ WELLTEC MILLING BHA. MILL OD= 3.802". MILL XN-NIPPLE AT 8801'. ABLE TO RIH & PULL UP THRU CLEAN. POOH. AT SURFACE MILL GAUGED TO 3.8015". RIG DOWN ELINE ***JOB COMPLETE*** Daily Report of Well Operations PBU 06-21B MIT-IA to 2627 psi ***PASS*** Daily Report of Well Operations PBU 06-21B 6/1/2022 T/I/O=1800/700/0 Pulled well house. Disconnected flow line and AL line, installed blinds and torqued to specs. Removed production tree and installed CDR tree with Kill line. Removed tree cap bonnet and installed tapped blind with jewelry at 90. Swab passed pressure test at API shop. Shell tested tree to 5000 psi. through kill line...Pass. Installed CDR platform on wing. Job complete. FWP's 1800/700/0 Activity Date Ops Summary 6/8/2022 Both modules arrive on DS-06. SimOps with Drill Site Operator and Coil Unit. Spot and set down both modules over well. Connect PUTZ. RU cellar and steam lines. Move Shop building from L1 to DS 6. Spot bleed tank, LVT pup and auxiliary equipment. Open well and confirm 2500 psi on tubing. Bleed off and RD tree flange. NU BOP's. 6/9/2022 Install nozzle, circ reel full of fresh water. Install CT risers. Grease choke valves. Install spill deflector around CT riser. Get RKBs. Complete valve checklist. Flush surface lines with fresh water. Get good shell test, Test BOPs 250 / 3500 psi as per Hilcorp and AOGCC regs. Test witness is waived by AOGCC Inspector Bob Noble. Test 1 IRV, Packoff, C7, C9, C10, C11 Pass. Test 2 Blind / Shear, R2, BL2, C15. Test 3 Annular (2-3/8"), TIW1, B1, B4 Pass. Test 4 Upper 2-3/8" Pipe / Slips, TIW2, B2, B3 Pass Test 5 Lower 2-3/8" Pipe / Slips, C5, C6, C8, TV2 Pass Test Choke A, Choke B Pass. Drawdown Test On Accumulator. Record all closing times. Record N2 bottle pressure. Test 7 Upper 2-3/8" Pipe/Slips, C1, C4, TV1 Pass. Test 8 3" Pipe/Slips, C2, C3 Pass Install BHI floats and test. R/U PDL and record measurements for max pressure deploy length. Pressure test PDL Pump 10 bbls 60/40 methanol and test MPD line to 3500 psi. Open master. T/I/O = 2468, 89, 53. Begin pumping bullhead kill schedule @ 5 bpm and 2478 psi. 10 bbls 60/40 methanol. 271 bbl 1% KCL. T/I/O = 90 , 1141, 363 while swapping to vis pill. 43 bbl High Vis pill. 102 bbls PowerPro mud Shut down pumping and monitor well. T/I/O = 27, 748, 606. Fill hole after 15 minutes with .3 bbls. Fill hole after 15 minutes .9 bbls. Flush stack and blow down line to Return tank. Rig Injector back and prep to MU window milling assembly. MU BOT/BHI window milling BHA #1. 2 7/8" BOT Xtreme Motor and 3.79" NG reamer and 3.80" NG reamer. Displace fresh water in coil to Return Tank. RIH with BHA #1. Pump Rate In = .90 bpm Pump Rate Out = 1.45 bpm. IA = 567 psi, OA = 524 psi. Tag @ GLM 3652'. Run past and pull back through. Run back in hole and did not tag. Resume RIH. 6/10/2022 Continue RIH. Tie-in depth correct -41'. Close EDC, tag whipstock at 9057'. Pick up and start milling window from 9056.4'. Continue milling window from 9056.4'. PVT shows +3.5 bbls, P/U for 10 min pumps off flowcheck, static. Check pits, PVT gain caused by agitators. Continue milling 9056.9'. 8.59 ppg In / Out. 2.49 / 2.46 bpm. Bleed OA from 800 to 500 psi. Mill window from 9059.1'. 8.57 / 8.58 ppg In / Out. 2.78 / 2.77 bpm In / Out. Window ECD 9.55#. Bleed OA to 300 psi. Bleed IA to 1000 psi. Mill window from 9062.9'. 8.56 / 8.57 ppg In / Out. 2.77 / 2.79 bpm In / Out. Window ECD 9.61#. IA 1157 psi, OA 732 psi Mill window from 9065.01'. 8.56 / 8.57 ppg In / Out. 2.78 / 2.80 bpm In / Out. Window ECD 9.61#. IA 1244 psi, OA 393 psi. Appears mill has exited, continue dressing with reamer. Mill 10' of rat hole to 9075' Geologist confirmed formation sand in bottoms up sample. Backream window at 1 fpm. Multiple passes reaming past 9057' until no motor work seen. Dry drift clean. Pump 10 bbl High/Low vis sweep off bottom POOH for lateral BHA. 8.56 / 8.57 ppg In / Out. 2.77 / 2.38 bpm In / Out. Window ECD 9.51#. IA 1330 psi, OA 523 psi OOH. Flow check well and confirm no flow. LD window milling BHA. Window mill and string reamer both 3.79" No-go and 3,80" Go. MU nozzle and jet BOP stack. Flush and blow down choke lines. MU Build BHA with 3.0 deg AKO. M/U injecotr, test QTS. 50-029-20802-03-00API #: Well Name: Field: County/State: PBE 06-21C Prudhoe Bay East Hilcorp Energy Company Composite Report , Alaska 6/11/2022Spud Date: Mill window from 9062.9'. 8. 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW7XHVGD\-XQH$0 7R7RP.DYDQDJK& &F5HJJ-DPHV%2*& 6XEMHFW5(>(;7(51$/@5(1DERUV%23WHVW $WWDFKPHQWV1DERUV&'5$&5HYLVHG[OV[ )ROORZ8S)ODJ)ROORZXS )ODJ6WDWXV)ODJJHG dŚĂŶŬƐdŽŵ͕ǇŽƵĂƌĞĐŽƌƌĞĐƚ͘/ƚƐŚŽƵůĚďĞ/ŶŝƚŝĂůtŽƌŬŽǀĞƌĨŽƌϬϲͲϮϭ͕WdηϮϬϴϬϵϵϬ͘/͛ǀĞĂƚƚĂĐŚĞĚĂƌĞǀŝƐĞĚƌĞƉŽƌƚ ĐŚĂŶŐŝŶŐƚŚĞǁĞůůŶĂŵĞƚŽϬϲͲϮϭ;ϬϲͲϮϭǁĂƐŝŶĐůƵĚĞĚŽŶƚŚĞƌĞƉŽƌƚͿ͘ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ 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. 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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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗dŽŵ<ĂǀĂŶĂŐŚͲ;ͿфdŽŵ͘<ĂǀĂŶĂŐŚΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗^ĂƚƵƌĚĂǇ͕:ƵŶĞϭϭ͕ϮϬϮϮϵ͗ϬϯD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗EĂďŽƌƐKWƚĞƐƚ ,ĞůůŽ͕ŚĞƌĞŝƐŽƵƌŝŶŝƚŝĂůƚĞƐƚŽŶǁĞůůϬϲͲϮϭ͘ ZŐĚƐ͕ dŽŵ dŽŵ<ĂǀĂŶĂŐŚ dƌŝůůƐŝƚĞDĂŶĂŐĞƌʹZϮ ZŝŐϵϬϳϲϳϬϯϬϵϳ ĞůůϵϬϳϴϰϭϮϰϭϬ ,ϰϭϲϵ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:CDR2AC DATE: 6/9/22 Rig Rep.: Rig Phone: (907) 670-3056 Operator: Op. Phone:(907) 670-3097 Rep.: E-Mail Well Name: PTD #22080990 Sundry #321-548 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250 / 3500 Annular:250 / 3500 Valves:250 /3500 MASP:2380 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank PP Annular Preventer 1 7-1/16" GK P Pit Level Indicators PP #1 Rams 1 Blind / Shear P Flow Indicator PP #2 Rams 1 2-3/8" Pipe / Slip P Meth Gas Detector PP #3 Rams 1 3" Pipe/ Slip P H2S Gas Detector PP #4 Rams 1 2-3/8" Pipe / Slip P MS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2-1/16"P Inside Reel valves 1P HCR Valves 2 2-1/16"P Kill Line Valves 1 2-1/16"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 2.0" Piper P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2250 P Quantity Test Result 200 psi Attained (sec)19 P No. Valves 12 P Full Pressure Attained (sec)51 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 10 @ 1990 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:7.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 06/08/22 04:25 Waived By Test Start Date/Time:6/9/2022 13:00 (date) (time)Witness Test Finish Date/Time:6/9/2022 20:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Nabors N. Wheeler / T. Henson Hilcorp T. Kavanagh / R. Burnett PBU 06-21B Test Pressure (psi): alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0609_BOP_Nabors_CDR2AC_PBU_06-21B 9 9 9 9 999 9 9 9 -5HJJ 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. From:Rixse, Melvin G (OGC) To:Joe Lastufka (joseph.lastufka@hilcorp.com) Subject:20211220 1523 MISSING ATTACHMENT for SUNDRY 321-548 PBU 06-21B PTD #208-099 window milling sundry addendum for sundry Date:Monday, December 20, 2021 4:25:05 PM Attachments:06-21C - Sundry (window milling attachement).doc Joe, Thanks for the missing attachment. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 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: Tuesday, December 14, 2021 7:37 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Subject: 06-21B (PTD #208-099) window milling sundry addendum for sundry #321-548 Mel, Looks like there was an attachment inadvertently left off of the submitted and approved sundry (#321-548) for PBU 06-21B (PTD #208-099), please see attached for the missing additional information. I apologize for the error and please let me know if you need anything else or have questions. Thanks! 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 dissemination, 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. The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. • Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: • All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. • Fluids >1% hydrocarbons or flammables must go to GNI. • Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10’ of formation will be milled/drilled with a 3.80” OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: • PBU Drill Site 6 is an H2S pad. o The highest recorded H2S on the pad was from 06-09 (395 ppm) in 1987 o Last recorded H2S on 06-21B was 12 ppm in 2020 o Reservoir Pressure: • The most likely reservoir pressure is expected to be 3,260 psi at 8,800’ TVD (7.1 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,380 psi (from above most likely pore pressure). • Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Coiled Tubing BOPs 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,735'None Casing Collapse Structural Conductor 470psi Surface 2,670psi Intermediate 4,760psi Liner 5,410psi Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Trevor Hyatt Contact Email:trevor.hyatt@hilcorp.com Contact Phone: 777-8396 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,923'9,360'8,837'2,380 9,360', 10,990', 11,312' 17. I hereby certify that the foregoin g is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY 8,430psi Tubing Grade: Tubing MD (ft): 8,736' / 8,393' Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 028311 208-099 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-20802-02-00 Hilcorp Alaska LLC PBU 06-21B Prudhoe Bay Field / Prudhoe Oil Pool Length Size 13Cr80 TVD Burst 8,813' 7,240psi MD 6,870psi 1,490psi 4,930psi 109' 2,511' 7,091' 109' 2,511' 3,032' - 8,582'7" 9-5/8" 20" 13-3/8" 80' 7,266' 2,479' 3,032' - 8,970' Perforation Depth MD (ft): 7,293' 8,972' - 11,640' 5,938' 4-1/2" 8,854' - 8,919' February 1, 2022 8,808' - 11,733'2,925' 4-1/2" 12.6# 8,451' - 8,923' 4-1/2" Baker S-3 Packer ory Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. Drilling Manager 10.19.2021 By Samantha Carlisle at 10:08 am, Oct 19, 2021 321-548 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.10.19 09:46:21 -08'00' Monty M Myers DLB 10/19/2021 DSR-10/19/21MGR19OCT21 Variance to 20 AAC 25.112(i) Alternate plug placement approved with a fully cemented liner. 10-407 BOPE test to 3500 psi. 2,380 X dts 10/20/2021 JLC 10/20/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.20 11:05:06 -08'00' RBDMS HEW 10/22/2021 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: October 18, 2021 Re: PBU 06-21B Sundry Request Sundry approval is requested to set a whipstock and mill the window in 06-21B pre-rig as part of the drilling and completion of the proposed 06-21C CTD lateral. Proposed plan for 06-21C Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT-IA / MIT-OA. A 4-1/2" Whipstock will be set pre-rig with E-line in the 4-1/2" liner. The parent Sag perforations will remain open. Service Coil will mill the XN-nipple and a single string window in the 4-1/2” liner (if scheduling needs arise, the rig will mill the window). See the 06-21C 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 well will kick off drilling in the Shublik, build through the Ivishak and land in Zone 2. The lateral will build back up to Zone 4 and drop to Zone 3 at 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. This completion will completely isolate and abandon the parent Sag perforations. This Sundry covers plugging the existing Sag perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start in February 2022): 1. Slickline: Dummy WS drift a. Drift past whipstock setting location b. All 4-1/2” GLMs are dummied 2. Fullbore: MIT-IA to 2,500 psi and MIT-OA to 1,200 psi 3. E-line: Set 4-1/2” whipstock a. Top of whipstock set at 9,055’ MD (top of window – pinch point) b. Oriented 180° ROHS 4. Service Coil: Mill XN Nipple and Window a. Mill XN-nipple at 8,801’ MD to 3.80” ID b. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,380 psi IV. Mill 3.80” window plus 10’ of rat hole V. Single string window exit out of 4-1/2” liner 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU 06-21C PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,380psi 2. Mill Window (only if not done pre-rig) 3. Drill Build and Lateral 4. Run and Cement Liner* 5. Freeze Protect and RDMO 6. Set LTP* (if needed), RPM log 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 Sundry 321-548 PTD 221-0XX 24 hour notice for AOGCC to witness BOPE test to 3500 psi. Well Bighole 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 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 3" Pipe/Slips 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 15-Jan-21 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2-3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8"Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 3" Pipe/Slips Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. The drilling engineers will serve as quality control for steps 1 and 2. Geologist then Drrilling Engineer (QC) 3 When the Stat Tech receives "a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Stat Tech 4 When the Stat Tech receives any Form 10-407, they will check the History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Stat Tech 5 When the Form 10-407 for the redrill is received, the Stat Tech will change the original well's status from SUSPENDED to ABANDONED. Stat Tech 6 The first week of every January and July, the Stat Tech and one of the Geologists will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Stat Tech Geologist DLB 10/19/2021 DLB 10/19/2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:208-099 6.50-029-20802-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11735 9360 8837 3043,8736,8819 none 9360,10990,11312 3043,8394,8461 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 83 20" 26 - 109 26 - 109 1490 470 Surface 2479 13-3/8" 24 - 2503 24 - 2503 5380 2670 Intermediate 7271 9-5/8" 22 - 7293 22 - 7091 6870 4760 Liner 5938 7" 3032 - 8970 3032 - 8582 7240 5410 Perforation Depth: Measured depth: 8972 - 11640 feet True vertical depth:8584 - 8919 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 24 - 8813 24 - 8456 3043,8736, 8819 3043,8393,8460Packers and SSSV (type, measured and true vertical depth) Liner 2925 4-1/2" 24 - 8813 24 - 8456 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2132038172 81026188 -6 31156 231 502 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:907-564-5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8923 Sundry Number or N/A if C.O. Exempt: N/A no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028311 PBU 06-21B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 7"Baker ZXP LTP,4-1/2" Baker S-3Perm,5" Baker ZXP By Samantha Carlisle at 9:31 am, Nov 12, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.11.12 06:36:09 -09'00' Bo York RBDMS HEW 11/12/2020 SFD 11/17/2020MGR13NOV2020DSR-11/13/2020 ACTIVITYDATE SUMMARY 10/21/2020 T/I/O = 2430/510/140. Temp = SI. T FL (E-line request). AL disconnected. T FL @ 9420' (50' above top of perfs, 144 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:00 10/22/2020 Assist ELine (PERFORATING) Load Tbg w/ 175 bbls crude. ELine in control of well per LRS departure. IA,OA=OTG 10/22/2020 ...Well shut in on arrival... (HES Eline - Set CIBP, Adperf) SET NORTHERN SOLUTIONS 4-1/2" CIBP MID-ELEMENT AT 9360'. PERFORATE 8,976'-9,005' WITH 3.125", 6 SPF, 60 DEGREE PHASING LOADED WITH 22.7gr GEODYNAMIC BASIX CHARGES. (REFERENCE LOG DEPTHS 8,972' - 9,001', SLB MWD 28-JUL-2008). ***Job Complete. Well shut in on departure. Notified DSO to POP** Daily Report of Well Operations PBU 06-21B • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,July 5, 2017 2:10 PM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 DS Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS Prod Controllers; AK, OPS EOC Specialists; Regg,James B (DOA);Wallace, Chris D (DOA);Odom, Kristine Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J Subject: OPERABLE: Producer 06-21 B (PTD#2080990) CMIT-TxIA and MIT-T Passed All, Producer 06-21B(PTD#2080990)was made under evaluation on 06/12/17 for having inner annulus casing pressure over NOL and anomalous IA repressurization. On 07/02/17 slickline set dummy gas lift valves in all stations and performed a passing CMIT-TxIA to 2,760psi and MIT-T to 2,779psi. The passing pressure test confirm two competent well barriers. The well is now reclassified as Operable. Please mind fluid packed annuli when bringing the well online. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED .1(JL 1 720P. WO 'Mita mob'ersorrambode Fro l� GWO Well Integrity Engineer Sent: Mon ,June 12, 2017 10:03 AM To: AK, GWO SU -II Integrity; AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RE o. East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS EOC Specialists; 'Regg, James : IOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.gov'; Odom, Kristine Cc: AK, GWO DHD Well Integrity; A 0 SUPT Well Integrity; AK, GWO Well Integrity Well Information; AKIMS App User; Dempsey, David G; Hibbert, Michael; ;4owski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R; Worthington, Aras J Subject: UNDER EVALUATION: Producer 06-2113 (PT • 080990) Sustained Casing Pressure Inner Annulus All, Producer 06-21B(PTD#2080990)was reported to have sustained inner annulus` - !ng pressure over NOL on 06/08/17. The wellhead pressures were confirmed to be T/I/0=2480/2180/460psi. A equent TIFL performed the same day passed, but follow up monitors show anomalous IA repressurization. The well is no lassified as Under Evaluation,and is on the 28 day clock for diagnostics and repairs. 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, June 12, 2017 12:04 PM To: Wallace, Chris D (DOA); Regg, James B (DOA) Subject: RE: UNDER EVALUATION: Producer 06-21 B (PTD# 2080990) Sustained Casing Pressure Inner Annulus Attachments: 06-21 B.pdf SCANNED JUN 2 3 2017, Sorry I forgot the attachments. 2.800 - 2,600 - 2,400 - 2.200 _-- 2,000- 1,300 - 1 E"1C' - 600 - 400 - 200 - 03/12117 03/19/17 03/2617 04102/17 04109//17 04/16117 From: AK, GWO Well Integrity Engineer Sent: Monday, June 12, 2017 10:03 AM To: AK, GWO SUPT Well Integrity; AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS EOC Specialists; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.gov'; Odom, Kristine Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R; Worthington, Aras J Subject: UNDER EVALUATION: Producer 06-21B (PTD# 2080990) Sustained Casing Pressure Inner Annulus All, Producer 06-21B (PTD#2080990)was reported to have sustained inner annulus casing pressure over NOL on 06/08/17. The wellhead pressures were confirmed to be T/I/0=2480/2180/460psi. A subsequent TIFL performed the 1 • i same day passed, but follow up monitors show anomalous IA repressurization. The well is now classified as Under Evaluation, and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Slickline: Perform GLV Change out,Set TTP 2. Fullbore: MIT-T 3. Well Integrity Engineer:Additional Diagnostics as needed Please rely with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO 2 •_ CNN VVELLFEAD= FMC • SAFETY NOTES:WELL ANGLE>70°@ 9562'"4-112" ACTUATOR= BAKER C 06-21 6_21 B CSHOWN*" NE�TBG&LNR""OR1G WELL&06-21A NOT I INMAL KB.ELE 74' BF.ELEV= 37' KOP= 4200' I` J 2014' —14-1/2"HES X tom?D=3.813' Max Angle= 99°@ 10979' Datum MD= 9428' Datum ND= 8800'SS 13-3/8"CSG,72#,L-80 BT&C,D=12.347" —I 2511' 3032' —I9-518"X 7'ZXP LIP w/TIEBACK SLV,D=6.290" "s-1 3049' H9-5/8"X 7"BKR FLEXLOCK LNR HGR,D=6.320" 41 ii Minimum ID =3.725" 8801' �j I* GAS LFT MANDRE.S 4-1/2" 41 HES XN NIPPLE ►. t I.t1 ST MD N [D V TYPE VLV LATCH PORT DATE i iti 045 3652 3652 1 KGB2 DOME BK 16 05/07/13 1� ►44 4 5668 5574 23 KGB2 DOME BK 16 05/07/13 •. e, 3 6894 6714 20 KGB2 DOME BK 16 05/07/13 /I 111 2 7797 7569 20 KGB2 Y BK 0 07/30/08 ,` 9-5/8"WHIPSTOCK(07/19/08) H 7293' S 14 MY 8640 8315 35 KGB2 SO BK 24 05/07/13 9-5/8"CSG,47#,L-80 BT&C,1D=8.681" —{ —7293' 1 9-5/8'MLLOUT VVINDOW(06-21A) 7293'-7307' PERFORATION SUMMARY REF LOG: SCHLUM MD OH ANAL on 07/26&07/28/08 8676' —14-112"HES X MP,D=3.813" ANGLE AT TOP PERF: 69°@ 9470' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ -0 87 —(7"X 4-112"BKR S-3 PKR ID=3.875" to- 2-3/4" 6 9470-9475 0 06/11/14 '0.4 2-3/4" 6 9482-9492 0 06/10/14 8770' —14-1/2"HES X NP,D=3.813' 2-3/4" 6 9543-9551 0 06/10/14 3-3/8" 6 9680-9700 0 07/17/09 3-3/8" 6 10700-10710 0 09/30/11 8801' --{4-1/2"HES XN NP,D=3.725" 3-3/8" 6 10710-10720 0 09/30/11 2-7/8" 6 11080-11100 0 07/31/08 8808' —{7"X 5"BKR H 2 ZXP LTP w/TIEBACK 2-7/8" 6 11540-11640 C 07/31/08 I SLV,D=4.460" 8813' —14-1/2'WLEG,I)=3.958" 8825' 7"X 5"BKR HMC LNR 43R, 4-1/2"TBG,12.6#,13-CR VAM TOP,.0152 bpf,D=3.958" —{ 8813' D=4.450" 8832' H5"X 4-1/2'XO,10=3.930" ` 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276' H 8970' lii 10990' H4-112"WOT GBP(09/28/11) 0 11312' 14-1/2"BKR CEP(01/19/09) �, PBTD 11646' TA 4404 4-1/2"LNR,12.6#,13CR-80 VAM TOP,.0152 bpf,D=3.958" H 11733' DATE REV BY COMMENTS ' DATE REV BY COME ITS PRUDHOE BAY UNIT 09/15/82 ORIGINAL COMPLETION WELL: 06-21B 07116/00 N2ES CTD SIDETRACK PERMT My"2080990 08/02108 N7E5 CTD SIDETRACK(06-218) API No: 50-029-20802-02-00 05/20/13 SWC/JND GLV CIO(05/07/13) SEC 2,T1ON,R14E,466'FSL&959'FB 06/17/14 RRD/JNR) ADPERFS(06/10-11/14) 06/03/16 ND REV EWED WBS RR TALLIES BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday,June 12, 2017 10:03 AM To: AK, GWO SUPT Well Integrity;AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 DS Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS EOC Specialists; Regg, James B (DOA);Wallace, Chris D (DOA); Odom, Kristine Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Sternicki, Oliver R; Worthington,Aras J Subject: UNDER EVALUATION: Producer 06-21 B (PTD#2080990) Sustained Casing Pressure Inner Annulus All, Producer 06-21B(PTD#2080990)was reported to have sustained inner annulus casing pressure over NOL on 06/08/17. The wellhead pressures were confirmed to be T/I/0=2480/2180/460psi. A subsequent TIFL performed the same day passed, but follow up monitors show anomalous IA repressurization. The well is now classified as Under Evaluation, and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Slickline: Perform GLV Change out,Set TTP 2. Fullbore: MIT-T 3. Well Integrity Engineer:Additional Diagnostics as needed Please rely with any questions, Joshua Stephens Well Integrity Engineer � ��® 'u'! 9 2 Office: 907-659-8110 Cell: 907-341-9068 WO W.r-.r.....r..ue.. 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, May 03, 2016 4:36 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Stechauner, Bernhard; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer; Odom, Kristine; McVey, Adrienne; Wallace, Chris D (DOA) Subject: Operable: Producer 06-21(PTD #2080990) TIFL Passed All, Producer 06-21 (PTD#2080990) passed a TIFL on 05/02/16 after being POP. The passing test confirms two competent barriers in the wellbore. The well has been reclassified as Operable. • Well status is now Operable Please call or email with any questions or concerns. Thank you, Jack Lau (Alternate-)Adrienne Mcl"ei BP Alaska-Well Integrity Superintendent GVVgr gan' s organza, 907-659-5102 From: AK, D&C Well Integrity Coordinator Sent: Wednesday, April 27, 2016 3:06 PM To: AK, D&C Well Integrity Coordinator; AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, RON,AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB F Drillsites; Stechauner, Bernhard; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (iim.re•g@alaska.gov) Cc: AK, D&C DHD Well Integrity Engineer; AK,OPS FF Well Ops Comp Rep; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer; Odom, Kristine; McVey, Adrienne; 'chris.wallace@alaska.gov' (chris.wallace@alaska.qb4 Subject: UNDER EVALUATION: Producer 06-21(PTD #2080990) Sustained IA Pressure over MOASP All, i • I Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, April 27, 2016 3:06 PM To: AK, D&C Well Integrity Coordinator; AK, OPS FS3 OSM;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Stechauner, Bernhard; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer; Odom, Kristine; McVey, Adrienne;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer 06-21(PTD#2080990) Sustained IA Pressure over MOASP All, Producer 06-21 (PTD#2080990)was reported as having sustained IA pressure of 2420 psi on 4/25/16, shortly after being shut in due to the field-wide power outage. It subsequently failed a cold TIFL on 4/26/16.The well is reclassified as Under Evaluation. Plan Forward: 1. Operations: POP well as soon as operationally feasible 2. Downhole Diagnostics: Warm TIFL 3. Well Integrity Engineer:Additional diagnostics as needed Thanks, SCANNED MAY Q 9 2016 Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) Office: (907)659-5102 Email: AKDCWeillntegrityCoordinator@BP.com 1 Pro'ect Well Histo File Cove~age Image ~ rY XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are. viewable by direct inspection of the file. ~(~ ~ - (~ ~` ~ Well History File Identifier Organizing (done> Two-sided III II'III II III II III ^Rescan Needed I)(II'I'I II II III III RE AN DIGI AL DATA Color Items: Diskettes, No. 1~Greyscale Items: ~~a'~ ^ Other, No/Type: 1Y' ^ Poor Quality Originals: ^ Other: NOTES: gY: Maria Date: t ~, Project Proofing gY: Maria Date: 3 0 ~ = Scanning Preparation x 3 gY: _ Maria Date: ~ I~ Production Scanning OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ P iuuiuuiiumii ~~ + =TOTAL PAGES Count does not include cover sheet) /s/ Stage 1 Page Count from Scanned File: ~ (Count does include cover heet) Page Count Matches Number in Scanning P eparation: YES NO BY: Maria Date: ~ ~ ra /s/ ~/f ~~ Q NO` Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: /s/ IIIIIIIII Dint unless rescanning is required. III II IIII I Scanning is complete at this p ned III IIIIIIIIIII VIII Rescan gY; Maria Date: ~s~ Quality Checked IIIIIIIIIIIIIIIIII Comments about thls file: 10!6!2005 Well History File Cover Page.doc FT Za ,o 0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] j�q 4 (a t (7- Sent: Friday, April 20, 2012 6:50 AM �/ To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GP8 FS3 Drillsites; Youngmun, Alex Cc: Olson, Andrew Subject: OPERABLE: 06-21B (PTD #2080990) Tubing Integrity Restored All, Producer 06-218 (PTD #2080990) passed a TIFL on 04/19/2012 confirming tubing integrity. The well is reclassified as Operable. Thank you, Mehreen Vazir t.4 /teerttrte': (Jerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.510 )UP (; 2012 Email: AKDCWeIllntegritvCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Thursday, April 12, 2012 5:57 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Youngmun, Alex Cc: AK, D &C Well Integrity Coordinator; King, Whitney Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC); Le: on, Michael 3 Subject: UNDER EVALUATION: 06 -21B (PTD #2080990) Sustained Casing IA Pressure Over MOASP AII, Producer 06 -218 (PTD #2080990) has confirmed sustained IA casing pr-ssure above MOASP. The wellhead pressures were tubing /IA/OA equal to 212/2200/400 on 4/9/2012. The well has -en reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrit, . Plan forward 1. DI TIFL 2. WIE: Evaluate for gas lift valve change out pending T L results. A TIO plot and wellbore schematic have been inc • ded for reference. f « File: 06 -12B (PTD #2080990) TIO Plotddc » Please call if you have any questions,,46r concerns. 1 • • ? � o 2 -zt_n, Prb Zti e'a bcic0 . Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Q12 Sent: Friday, April 13, 2012 1:16 PM 4 f 1 'I ` ��I, v To: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: 06 -21 B (PTD #2080990) Sustained Casing IA Pressure Over MOASP Jim, It was a typo on the title of the slide and the name of the document file. The well under evaluation is 06 -21 B, which the Y PTD represents. I'm sorry for the mistake. Jerry Murphy BPXA Well Integrity Coordinator From: Regg, James B (DOA) [mailto:jim.re.g(thalaska.gov] Sent: Friday, April 13, 2012 12:16 PM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: 06 -21B (PTD #2080990) Sustained Casing IA Pressure Over MOASP Is file name and title of TIO plot a typo (06 -21B)? Jim Regg AOGCC AS � "�; 2.U%2. 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeIIIntegrityCoordinatorftp .com] Sent: Thursday, April 12, 2012 5:57 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Youngmun, Alex Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC); LeBaron, Michael J Subject: UNDER EVALUATION: 06 -21B (PTD #2080990) Sustained Casing IA Pressure Over MOASP All, Producer 06 -21 B (PTD #2080990) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 212/2200/400 on 4/9/2012. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward 1. DHD: TIFL 2. WIE: Evaluate for gas lift valve change out pending TIFL results. A TIO plot and wellbore schematic have been included for reference. «06 -12B (PTD #2080990) TIO Plot.doc» «06 -21 B (PTD #2080990) wellbore schematic.pdf» 1 • • Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2 PBU 06-21B PTD #2080990 4/12/2012 TIO Pressures Plot Well: 06-21 4.000 - i • 3,000 —0— Tbg IA 2,000 - + OA 0 O 000A On 1,000 - i 01/14/12 01/21/12 01/28/12 02/04/12 02/11/12 02/18/12 02/25/12 03/03/12 03/10/12 03/17/12 03/24/12 03/31/12 04/07/12 TREE = CIW • WELLHEAD = FMC SAFET TES: WELL ANGLE> 70° @ 9562 * *" 4.1/2" ACTUATOR = BAKER C 0 6 -21 B SHOWN TBG & LNR' * ** ORIG WELL & 06 -21A NOT KB. ELEV = 74' BF. ELEV = 37' I ( KOP = 4200' I 2014' 1-14-1/2" HES X NIP, ID = 3.813" I Max Angle = 99° @ 10979' Datum MD = 9428' Datum TV D = 8800' SS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2511' 3032' H 9 -5/8" X 7" ZXP LTP w /TIEBACK SLV, ID = 6.290" I " ��, 3049' I- I9 -5/8" X 7" BKR FLEXLOCK LNR HGR, ID = 6.320" I X 1 WI Minimum ID = 3.725" @ 8801' �1�1 I* 4 -1/2" HES XN NIPPLE ►� + 4j GAS UFTMANDRELS r 4 "At ST MD TVD DEVI TYPE VLV LATCH PORT DATE N N 5 3652 3652 0 KGB2 DOME BK 16 03/14/10 14 4 5668 5574 0 KGB2 SO BK 20 03/14/10 � ,�� 3 6894 6714 20 KGB2 DMY BK 0 07/30/08 , 1 ,�� 2 7797 7569 20 KGB2 DMY BK 0 07/30/08 9 -5/8" WHIPSTOCK (07/19/08) 7293' �1 � 1 f I� + � 1 8640 8315 35 KGB2 DMY BK 0 07/30/08 9 -5/8" CSG, 47 #, L -80 BT &C, ID = 8.681" H -7307 I 9 -5/8" MILLOUT WINDOW (06 -21A) 7293' - 7307' 8676' I- I4 -1/2" HES X NIP, ID = 3.813" I Ill PERFORATION SUMMARY 36' J-17" X 4-1/2" BKR S -3 PKR, ID = 3.875" I REF LOG: SCHLUM MD OH FINAL on 07/26 & 07/28/08 t� i4 i li ANGLE AT TOP PERF: 80' @ 9680' �� 8770' H4-1/2" HES X NIP, ID = 3.813" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE I 3 -3/8" 6 9680 - 9700 0 07/17/09 8801' 1-14-1/2" HES XN NIP, ID = 3.725" I 3 -3/8" 6 10700 - 10710 0 09/30/11 3-3/8" 6 10710 - 10720 0 09/30/11 8808' I- 7" X 5" BKR HR ZXP LTP w /TIEBACK 2 -718" 6 11080 - 11100 0 07/31/08 2 -7/8" 6 11540 - 11640 C 07/31/08 SLV, ID = 4.460" 8813' I- -I4 -1/2" WLEG, ID = 3.958" I 8825' J 7" X 5" BKR HMC LNR HGR, 14-1/2" TBG, 12.64, 13CR VAM TOP, .0152 bpf, ID = 3.958" H 8813' ID = 4.450" I 8832' N 5" X 4-1/2" XO, ID = 3.930" I 17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" H 8970' ii r r 10990' I- [4 -1/2" WOT CIBP (09/28/1 I � 11312' H4 -1/2" BKR CIBP (01 /19/09) I i r I PBTD I 11646' 14 04 I 4 -1/2" LNR, 12.64, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" I 11 733' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/15/82 ORIGINAL COMPLETION 01/04/1 GJF /PJC FINAL DRLG CORRECTIONS WELL: 06 -21B 07/16/00 N2ES CTD SIDETRACK 10/10/11 RMH/ PJC CIBP / A DPERF (09/28- 30/11) PERMIT No: r 2080990 08/02/08 N7ES CTD SIDETRACK (06-21B) API No: 50- 029 - 20802 -02 -00 02/04/09 JKD /SV SET CIBP (01/19/09) SEC 2,1 R14E, 466' FSL & 959' FEL 07/26/09 RRD /PJC PERFORATIONS (07/17/09) 04/16/10 ? /JMD DRLG DRAFT CORRECTIONS u BP Exploration (Alaska) • 24 -OCT -2011 Schlwrierger No. 5802 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD Z -21A BG4H -00097 PPROF W /DEFT & GHOST 9- Oct -11 1 1 13 -15 BINC -00066 PRIMARY DEPTH CONTROL LOG 21- Sep -11 1 1 13 -25 BJGT -00070 PRIMARY DEPTH CONTROL LOG 26- Sep -11 1 1 R -12A AWJI -00158 USIT 16- Aug -11 1 1 Z -65 BX69 -00003 ISOLATION SCANNER 5- Oct -11 1 1 A -25B AV1 P -00098 USIT 6- Aug -11 1 1 • 18 -12C AWJI -00162 MDT 13- Sep -11 1 1 S -09 BVYC -00011 USIT 11- Oct -11 1 1 R -12A BBSK -00098 PRIMARY DEPTH CONTROL LOG 28- Sep -11 1 1 Y-36 BVYC -00007 PPROF 2- Oct -11 1 1 06-21B BD88 -00173 MEMORY DEPTH DETERMINATION • 28-Sep-11 06 -21 B BD88 -00173 PPROF W /DEFT & GHOST �1 29- Sep -11 1 1 W -10A BCRC -00132 PPROF 11- Sep -11 1 1 1 1 N-04A BVYC -00009 CROSSFLOW CHECK 5- Oct -11 1 1 A -25B BG4H -00096 SCMT 7- Oct -11 1 1 17 -04B BR12 -00019 LEAK DETECT LOG 3- Oct -11 1 1 W -16A BCRC -00133 PPROF 12- Sep -11 1 1 Z -21A BR12 -00020 MEMORY STP SURVEY 5- Oct -11 1 1 Z -29 BD88 -00168 PPROF W /DEFT & GHOST 22- Sep -11 1 1 3- 45/M -39 BD88 -00175 IPROF 3- Oct -11 1 1 R -12A BBSK -00098 SCMT 29- Sep -11 1 1 R -12A BVYC -00005 ISOLATION SCANNER 12- Sep -11 1 1 14 -30A BG4H -00093 PRIMARY DEPTH CONTROL LOG 3- Oct -11 1 1 N -04A BINC -00069 PPROF 14- Oct -11 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ArMAIEDJUN 2 0 'zU32 7.0/5 99 24 -OCT -2011 Schhunkerger No. 5802 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD Z -21A BG4H -00097 PPROF W /DEFT & GHOST 9- Oct -11 1 1 13 -15 BINC -00066 PRIMARY DEPTH CONTROL LOG 21- Sep -11 1 1 13 -25 BJGT -00070 PRIMARY DEPTH CONTROL LOG 26- Sep -11 1 1 R -12A AWJI -00158 USIT 16- Aug -11 1 1 Z-65 BX69 -00003 ISOLATION SCANNER 5- Oct -11 1 1 A -25B AV1P -00098 USIT _ 6- Aug -11 1 1 • 18 -12C AWJI -00162 MDT 13- Sep -11 1 1 S -09 BVYC -00011 USIT 11- Oct -11 1 1 R -12A BBSK -00098 PRIMARY DEPTH CONTROL LOG 28- Sep -11 1 1 Y -36 BVYC -00007 PPROF 2- Oct -11 1 1 06 -219 BD88 -00173 MEMORY DEPTH DETERMINATION a 0 .t- 28- Sep -11 1 1 06 -21B BD88 -00173 PPROF W /DEFT & GHOST 1 / 29- Sep -11 1 1 W -10A BCRC -00132 PPROF 11- Sep -11 1 1 N-04A BVYC -00009 CROSSFLOW CHECK 5- Oct -11 1 1 A -25B BG4H -00096 SCMT 7- Oct -11 1 1 17 -04B BR12 -00019 LEAK DETECT LOG 3- Oct -11 1 1 W -16A BCRC -00133 PPROF 12- Sep -11 1 1 Z -21A BR12 -00020 MEMORY STP SURVEY 5- Oct -11 1 1 Z -29 BD88 -00168 PPROF W /DEFT & GHOST 22 -Sep -11 1 1 3- 45/M -39 BD88 -00175 IPROF 3- Oct -11 1 1 R -12A BBSK -00098 SCMT 29- Sep -11 1 1 R -12A BVYC -00005 ISOLATION SCANNER 12-Sep-11 1 1 14-30A BG4H -00093 PRIMARY DEPTH CONTROL LOG 3- Oct -11 1 1 N -04A BINC -00069 PPROF 14- Oct -11 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 JUN20Z012. • ALASKA OIL AN DS CONSERVATION COMMISSION • EIVED OCT lb REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 1151 Stimulate El °t Aitifia Oil & Gas Cans. Cafranissi Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ ' ncno °ga 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 208 -0990 3. Address: P.O. Box 196612 Stratigraphic0 Service p 6. API Number: Anchorage, AK 99519 - 6612 50- 029 - 20802 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028311 , PBU 06 -21 B 10. Field /Pool(s): • PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11735 feet Plugs (measured) 10990, 11312 feet true vertical 8923.13 feet Junk (measured) None feet Effective Depth measured 11648 feet Packer (measured) 3032 8736 8808 feet true vertical 8919.87 feet (true vertical) 3032 8393 8451 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20 "91.5# H-40 33 - 113 33 - 113 1490 470 Surface 2479' 13- 3/8 "72# L -80 32 - 2511 32 - 2511 4930 2670 Production 7263' 9 -5/8" 47# L -80 30 - 7293 30 - 7091 6870 4760 Liner 5938' 7" 26# L -80 3032 - 8970 3032 - 8582 7240 5410 Liner 2925' 4 -1/2" 12.6# 13CR80 8808 - 11733 8451 - 8923 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# 13Cr80 28 - 8813 28 - 8456 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer 3032 3032 4 -1/2" Baker S -3 Perm Packer 8736 8393 5" Baker ZXP Top Packer 8808 8451 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ;` ` , , ' '111'', 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 295 6,251 3,862 884 Subsequent to operation: 544 35,794 2,599 317 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0" Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP0 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 Joe Lastufka Printed Na e •e Las u Ai i Title Petrotechnical Data Technologist 1 , Signat re \ i Phone 546 -4091 Date 10/20/2011 OCT f , y /- /p., y - ff Form 10 -404 Revised 10/2010 RBDMS OCT 2 0 20 p Submit Original Only 06-21B 208 -099 ' PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06 -21B 7/31/08 PER 11,080. 11,100. 8,924.71 8,921.62 06 -21B 7/31/08 PER 11,540. 11,640. 8,914.28 8,919.44 06 -21B 1/19/09 BPS 11,312. 11,640. 8,908.26 8,919.44 06 -21 B 7/17/09 APF 9,680. 9,700. 8,941.03 8,944.01 06 -21B 9/29/11 BPS 10,990. 11,312. 8,938.76 8,908.26 06 -21 B 9/30/11 APF 10,700. 10,710. 8,964.88 8,964.89 06 -21 B 9/30/11 APF 10,710. 10,720. 8,964.89 8,964.94 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 • • • 06 -21B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY k . 9/29/2011 !Continued from 09/28/11 WSR. CTU 8 w/ 1.75" CT. Scope; pprof, cibp, adperf Log PPROF w/ Ghost from 8600' - 11270' @ 40 fpm. Log 60 & 80 fpm passes from `9300'- 11270'. Make stop counts at 11270', 11000' & 9300', flag pipe @ 10900'. ;pooh. Data good. (phone APE, obtain permission to set CIBP higher than requested in program due to scale) RIH w/ BHA; 2.375" ctc, dfcv, disco, blank sub, 2.86" x -o, 3.6" setting tool, 2.5" adapter, 4 1/2" WOT CIBP (oal= 11.35') Set plug @ 10990' ;pooh. Cut 150' pipe. Chain inspection /pack off changeout. MU WOT MHA. MU /RIH 'w /SWS Gun #1. 10' of 3 3/8" w/ 10' of decentralizer to shoot high side 3 spf. ;Continued on 09/30/11 WSR. 9/30 /2011 ;Continued from 09/29/11 WSR. CTU 8 w/ 1.75" CT. Scope; pprof, cibp, adperf RIH w/ Gun #1: 10' of 3 3/8" w/ 3 spf w/ 10' decentralizer oriented to shoot high side. Tag plug @ 10990', correct to plug. Shoot Gun #1 (cry, 10710'- 10720', RIH w/ Gun #2; 10' of 3 3/8" w/ 3 spf w/ 10' decentralizer oriented to shoot high side. Tag plug @ 10990', correct to plug. Shoot Gun #2 10700'- 10710', pooh. all shots fired.. **job complete ** FLUIDS PUMPED BBLS 189 50/50 METH 165 1 % KCL 354 TOTAL TREE= ^ CIW WELLHEAD = FMC 1. SAFETY NOTES: WELLOLE> 70° © 9562 "*" 4 -1/2" ACTUATOR = BAKER C O 6 -21 B SHOWN ROM E & LNR "r"* ORIG WELL & 06 -21A NOT KB. ELEV = 74' , BF. ELEV = 37' I L ■ KOP = 4200' I 2014' 1-14-1/2" HES X NIP, ID = 3.813" 1 Max Angle = 99° @ 10979' Datum MD = 9428' Datum TVD = 8800' SS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2511' 3032' 1--19 - 5/8" X 7" ZXP LTP w /TIEBACK SLV, D = 6.290" I 4 -I I 3049' H9 -5/8" X 7" BKR FLEXLOCK LNR HGR, ID = 6.320" A '1 Minimum ID = 3.725" @ 8801' � 1 i�i • 4-1/2" HES XN NIPPLE o `•i GAS LIFT MANDRELS � � � N • ST MD TVD DEV TYPE VLV LATCH PORT DATE ��(► 5 3652 3652 0 KGB2 DOME BK 16 03/14/10 1 4 5668 5574 0 KGB2 SO BK 20 03/14/10 • . . 3 6894 6714 20 KGB2 DMY BK 0 07/30/08 � v # i 11 �� 2 7797 7569 20 KGB2 DMY BK 0 07/30/08 19 -5/8" WHIPSTOCK (07/19/08) 7293' .4 1i 1 ,.i + 1 8640 8315 35 KGB2 DMY BK 0 07/30/08 19 -5/8" CSG, 47 #, L -80 BT &C, ID = 8.681" H -7307 1 q , 9 -5/8" MILLOUT WINDOW (06-214) 7293' - 7307' 8676' H4-1/2" HES X NIP, ID = 3.813" l PERFORATION SUMMARY ,+ ( 8736' (--17" X 4 -1/2" BKR S -3 PKR, ID = 3.875" REF LOG: SCHLUM MD OH FINAL on 07/26 & 07/28/08 ��• ANGLE AT TOP PERF: 80° @ 9680' �� L HES X NIP, D = 3.813" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9680 - 9700 0 07/17/09 1 8770. 01, 1-14-1/2" 1 88 I-�4 -/2" HES XN NIP, ID = 3.725" 3 -3/8" 6 10700 - 10710 0 09/30/11 3 -3/8" 6 10710 10720 0 09/30/11 $80$' I-1 7" X 5" BKR HR ZXP LTP w /TIEBACK 2 -7/8" 6 11080 - 11100 0 07/31/08 2 -7/8" 6 11540 - 11640 C 07/31 /08 SLV, ID = 4.460" 8813' H4 -1/2" WLEG, ID= 3.958" I 8825' I — 7" X 5" BKR HMC LNR HGR, 14 -1/2" TBG, 12.6 #, 13CR VAM TOP, .0152 bpf, ID = 3.958" I-I 8813' ID = 4.450" I 8832' H5" X 4 -1/2" XO, ID = 3,930" I ii 7" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" H 8970' 2 . -------- 10990'J 14 - 1/2" WOTCIBP(09 /28/11) to 11312' I- 14 -1/2" BKRCIBP(01 /19/09) 1 PBTD I 11646' r 14-1/2" LNR, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" I - 1 11733' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNR 09/15/82 ORIGINAL COMPLETION 01/04/11 GJF /PJC FINAL DRLG CORRECTIONS WELL: 06 -21B 07/16/00 N2ES CTD SIDETRACK 10/10/11 RMH/ PJC CIBP/ ADPERF (09/28 - 30/11) PERMIT No: 2080990 08/02/08 N7ES CTD SIDETRACK (06 -21 B) API No: 50- 029 - 20802 -02 -00 02/04/09 JKD /SV SET CIBP (01/19/09) SEC 2, T1 ON, R14E, 466' FSL & 959' FEL 07/26/09 RRD /PJC PERFORATIONS (07/17/09) 04/16/10 ? /JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 3/4/2010 Permit to Drill 2080990 Well Name /No. PRUDHOE BAY UNIT 06 -21B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 20802 -02 -00 MD 11735 TVD 8923 Completion Date 8/2/2008 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Ye� DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES / PWD, DIR / GR / RES, NEU / DEN (data taken from Logs Portion of Master Well Data Maint Well Log Information: el Log/ Electr 1 Data Digital Dataset Log Log Run Interval OH / T pe Med /Frmt Number Name Scale Media No Start Stop CH Received Comments 'ED D Asc Directional Survey 0 11735 Open 8/4/2008 pt , Directional Survey 0 11735 Open 8/4/2008 D C Las 17270 /Resistivity 9003 11735 Open DRHO, RPM, GR, RPD, RPS, RPX FIELD DATA C Lis 19089 eduction /Resistivity 6963 11730 Open 12/3/2009 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, I RAM, DRHO, NPHI,. TRPM bL g,16, Induction /Resistivity 25 Blu 7260 11735 Open 12/3/2009 MD Vision Service Induct ion /Resistivity 25 Blu 7260 11735 Open 12/3/2009 TVD Vision Service Well Cores /Samples Information: Sample Interval Set • Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? YCD Daily History Received? N Chips Received ? -'(/'N — Formation Tops N Analysis 4 1-144----- Received? DATA SUBMITTAL COMPLIANCE REPORT 3/412010 Permit to Drill 2080990 Well Name/No. PRUDHOE BAY UNIT 06-21 B Operator BP EXPLORATION (ALASFC/~ INC API No. 50-029-20802-02-00 MD 11735 TVD 8923 Comments: Compliance Reviewed By: Completion Date 8/2/2008 Completion Status 1-OIL Current Status 1-OIL UIC N Date: V ~J 1.~~ BP Exploration (Alaska) Ina Attn: Well Integrity Coordinator, PRB-20 - _ Post Office Box 196612 Anchorage, Alaska 99519-6612 . January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission g ~ 0 333 West 7th Avenue Anchorage, Alaska 99501 ~~- ~- Subject: Corrosion Inhibitor Treatments of GPB DS 06 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 06 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-Oti Date: 12/10/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al O6-o1 1750490 50029201720000 NA Sealed NA os-o2 1770780 50029202820000 NA Sealed NA o6-o3A 1951520 50029201b6010o NA Sealed NA Os-04A 2001020 50029201790100 NA Sealed NA os-05 1780200 50029202980000 NA Sealed NA o6-os6 2050980 50029202010200 NA Sealed NA os-o7 1780210 50029202990000 NA Sealed NA 06-o8A 1951950 50029203000100 NA Sealed NA 06-09 1790730 5002920a000000 NA Sealed NA 06-10A 1981960 50029204020100 NA Sealed NA os-11 1791100 50029204280000 NA Sealed NA 06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009 06-13A 2061020 50029204570100 NA Sealed NA 06-14B 2090120 50029204580200 NA Sealed NA os-15 1800320 50029204590000 NA Sealed NA 06-16 1800330 50029204600000 NA Sealed NA 06-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009 06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009 06-20A 2050790 50029207990100 NA 1 NA 5.10 10/4/2009 06-21B 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 06-22A 1930570 500292o8os0100 NA 1.5 NA 5.10 10/4/2009 06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6!2009 06-24A 2000960 50o292os22o1oo NA Sealed NA 1 fr 11_bhunUep NO. 5180 Alaska Data & Consulting Services Company: State of Alaska 2526 Gambol! Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD OWDW -SW B3SO -00032 RST/WFL L' /U } -43 e q 11/07/09 1 1 L -223 B581 -00014 USIT " ' 3 a 10/21/09 1 ()qtr.- c S -218 B5JN -00018 USIT () 10/21/09 1 1 L -222 BM-000m USIT. a - t 9 11/07/09 1 1 - L2 -24 B14B -00079 RST l 7C, it 1 D �jL V ( Q, 10/31/09 1 1 r 12 -32 8148 -00078 RST �j e ‘.1 Sj 7 3� t �1j)C -/ 10/30/09 1 1 11-14 _ AV1 H•00029 RST 5 -- 0 / 9 S _ i 0/27/09 1 1 L2 -18A 8148.00077 RST / / n / 1013W09 1 1 D -288 AXED -00053 MCNL a( - • n /1/Q1 10/02/09 1 1 S -228 B8K5 -00008 RST Lr C? i • - 1 / -i nellq- 10/27/09 1 1 D -24 AWL8-00038 RST 15• ,0449 09/27/09 1 1 18 -15B AYS4 -00107 RST y - or '" • ' 10/31/09 1 _ 1 _ _ 04 -21 r0115 RST •r - • 0 10/27/09 1 1 L2 -07A • • • r RST _ a - • • O aj r 10/29/09 1 1 _ OWDW -SW • _ _ r tir / 0( - e ,h ■ 11/07/09 - 1 1 12- 05APB1 40015441 OH MWD/LWD EDIT - • - � Q, ( , 07/01/07 2 1 (.....) 06-218 08AKA0016 OH MWDILWD EDIT (5 �n 07/2W08 2 1 D-16A 09AKA0175 OH MWD/LWO EDIT an- )-n , - _ r _ 09/07/09 2 1 L -223 09AKA0081 014 MWDILWD EDIT Ed 10_, -- Q n 10/10/09 2 1 L -223 8581 -00014 CH EDIT PDC (USIT) ( )Sr a( n1 /AjD jr3 10/21/09 1 S -218 _ B5JN-00018 CH EDIT PDC (USIT) ( )1(4_, a� - (_ i.1 /la " 10/21/09 1 L -222 8 V 350 -00031 CH EDIT PDC (USIT) i a�, -- 1 i0 /do 11/07/09 1 04-33A 09AKA0075 OH MWD /LWO EDIT a 663-00h .5 19 ovS 09/19/09 2 1 • • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center 1112 -1 2525 Gambetl Street, Suite 400 900 E. Benson Blvd. (/ 1 Anchorage, AK 99503-2838 "' ' v41 ) M t % ' , Maunder Th~maa ~ (~3A) - From: Prebte, Gary B (SAIC) [Gary.Preble(d,~bp.com] Sent: Thursday, August 13, 200910:31 AM To: Maunder, Thomas E (DOA) Subject: Emailing: 06-21 B-208-099-PERF-ATTACHMENT.PDF Attacfiments; ~-21 B-208-099-PERF-ATTACHMENT.PDF ,~.---- afrz~~zos-a-~E RF-ATTACFlI+~IENT,,, Tom, Please change the date Thanks on the 10-9Q4 for the plug to read 1/19/09. The message is ready to be sent with the following file or link attachments: 06-21B-~08-099-PERF-ATTACHMFNT,PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine- how attachments are- bandied, - - --- --- - -- ---- ---- ------- - Page 1 of 1 lttnder Thoanas E (~aA) From; Maunder: Thomas ~ (pt~A) Seat; Tht~rsda~~. August 13.2409 9`33 A~tl Tea: 'Preble, Gary B (SAIC)' St~F~~e; Q~ Q~s-2'tB (2€-01 Gary, I was reviewing the 4t}~ for the recent adperf operation on this well- A plug is Nsted at 11312 ~n the 404 sheet but not on the "perP' sheet. tt appears that the Plug is above the Pam at 11540-5£Q isolating them. If a new caetf sheet is needed. email is f:ne. Tom Maunder, PE ;Q;GGI"'C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~E~EIV~ ~a~ :JUL. 2 ~(i[ 1.Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ ~~83~~r ~ ~, _ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension '~' -' ~~ Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well '' 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 2os-os9o 3. Address: P.O. Box 196612 Stratigraphic ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-20802-02-00 7. KB Elevation (ft): 9. Well Name and Number: 65.73 RT PBU 06-21 B 8. Property Designation: 10. Field/Pool(s): ADLO-028311 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: fj ~ fL~ ~ o l ~~E~.~~, Total Depth measured 11735 feet Plugs (measured) 11312' 1/ true vertical 8923.13 feet Junk (measured) None Effective Depth measured 11648 feet true vertical 8919.87 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 Surface - 80' Surface - 80' 1490 470 Surface 2510 13-3/8" 72# L-80 Surface - 2510' Surface - 2510' 4930 2670 Production 7293 9-5/8" 47# L-80 Surface - 7293' Surface - 7091' 6870. 4760 Liner 5938 7" 26# L-80 3032' - 8970' 3032' - 8582' 7240 5410 Liner 2925 4-1/2" 12.6# 13CR80 8808' - 11733' 8451' - 8923' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR SURFACE - 8813' 0 0 - Packers and SSSV (type and measured depth) 4-1/2"X7" BOT S-3 PKR 8736' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 233 27524 488 1318 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas WAG ~ GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature .~ Phone 564-4944 Date 7/23/2009 Form 10-404 Revised 04/2006 ~~~ ~''J',~ ~ ~ ~~a~ Submit Origjnal Only/ a 06-21 B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY I 7/17/2009 CTU #6 1.75" CT (Interact Publishing) Job Scope: Memory GR/CCL Log / Adperf. MIRU CTU #6.MU and RIH logging tool with 3.68" Nozzle. Log from 9800' ctmd to 8500' ctmd. Flag pipe at 9650'. POOH. MU and RIH with 3-3/8" , ~20' gun with PJ3406 HMX charges 6 SPF, 60 degree phasing. Perforate interval 9680' - 9700' MD. POOH. All shots fired. Ball recovered. Well freeze protected j ~ to 2500' with 50/50 methanol. Notify DSO of well status. RDMO. **"Job I Complete"** FLUIDS PUMPED BBLS 66 50/50 METH 170 1% KCL W/SAFELUBE 236 Total tN-21 E3 2fl8-039 SW Name ,Qp~rB~ion D~i~ P~~ Q~@Citii Code ~@~~s ~ ' TQ ~@~&S ~S6 'Tvd ~ Tvd '1 ~85@ Q6-21B Tt3i R 11,x. 1i,it~?. 8,3~~.Ti ' 8,92"1.6 €!6-Z'E B 'X~3i148 'PER 1"#=!54Q. 4i,6~1. 8,~'14.~8 8,9'~9.~4 t~ Zi B iM'#9 BRS 1 # }3'! 2. ~ 4 i,~'l7. 8,9~.2C ' 8„818.3 t16-~i~ 711Tft19 '~4P"F 9,6~tt. 9 7th?. ~,!~t1.#~3 8,~t4.Q9 AB ABAN~3QNEL1 PER PfRf APF aQD PERT ' RPP REPERF BPP BRtQCsE PLUG P ULLED 'SL &L.C?'P'CED L~+tER BPS BRIDGE PLUG SET SPR 'SAN[? PLUta REMt~VEt? ffCC! F~L.L CLEAN CWT SPS 'SAND PLUG SET FIL FlLL SQL !SQUEEZE. FAtLEa MER l~IECHANtC~. ISOLATED RE~AOVED SQZ SQUEEZE MiS ~ItECFiANICAL ISOLATED STC STRADDLE PACK,. CLOSED ELK ~ECHANtCAL LEAK STO STRADDLE PACK, OPEN OH 'OPEN HOLE 06-21 B 208-099 PERF ~TTOC_HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06-21B 7/31/08 PER 11,080. 11,100. 8,924.71 8,921.62 06-216 7/31/08 PER 11,540. 11,640. 8,914.28 8,919.44 06-21 B 7/17/09 APF 9,680. 9,700. 8,941.03 8,944.01 B ABANDONED PER PERF ADD PERF RPF REPERF BPP IDGE PLUG P ULLED SL SLOTTED LINER BPS BRI LUG SET SPR SAND PLUG REMOVED FCO FILL CLE T SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATE OVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK O STRADDLE PACK, OPEN OH OPEN HOLE '. I (~ ~ k -n r W Maunder, Thomas E (DOA) From: Vazquez, Eleazar [vazge0@BP.com] Sent: Tuesday, November 04, 2008 8:14 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 06-21 B (208-8S9j Hi Tom, The slurry yields for the 7" liner cement are the following: LiteCrete Lead Cement Density: 11.5 ppg Yield: 2.770 cuft/sk Class G Tail Cement Density: 15.8 ppg Yield: 1.160 cuft/sk Page 1 of 1 The original plan for well 06-21 B was to seta 7" drilling liner at the Top of the Sag River and bring it 150' inside the 9-518" casing window. Then, a scab liner would be run from the top of the 7" drilling liner up to 3,000 MD. However, after having reviewed the planned operations with management, it was determined that bringing the 7" drilling liner up to 3,000 MD would save approximately two days and 400K dlls based on our AFE. In addition, the cement design had to be changed to be able to perform the cement job as one stage job. The result was fully cemented casing from the Top of the Sag River to 3,031 MD. It was an oversight on my part to keep you out of the loop of communication that eliminated a planned operation; however, the final result was the same. There will be a conversation between Greg Hobbs and I on this matter after my return to the office. If you have any other questions, please let me know. Thanks, Eli From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, November 03, 2008 9:41 AM To: Vazquez, Eleazar Cc: Hobbs, Greg S (ANC) Subject: DS 06-21B (208-099) Eli, I am reviewing the 407 completion report for this well and have a couple of questions. 1. What are the slurry yields for the 7" liner? 2. When this well was permitted, it was stated that the 7" would be set as a liner and then a tieback or scab would be installed. According to the operations reports, the string was set as a long liner. I do not find any communication regarding the change of plans. I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC 11/5/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~C~ ~i.~G 2 9 200$ WELL COMPLETION OR RECOMPLETION REPORT ANO;Li & GaJ Cons. Camm~: Al~chorage 1 a. Well Status: ®Oil ~ ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,oe zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 8!2/2008 12. Permit to Drill Number 208-099 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/20/2008 ~ 13. API Number 50-029-20802-02-00- 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 7/27/2008 ' 14. Well Name and Number: PBU 06-216- 466' FSL, 959' FEL, SEC. 02, T10N, R14E, UM Top of Productive Horizon: 2176' FSL, 3367' FEL, SEC. 02, T10N, R14E, UM 8. KB (ft above MSL): 65.73' Ground (ft MSL): 37' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2759' FSL, 3893' FEL, SEC. 02, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 11648' 8920' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 686026 y- 5941066 Zone- ASP4 10. Total Depth (MD+TVD) 11735' 8923" 16. Property Designation: ADL 028311 TPI: x- 683575 y- 5942717 Zone- ASP4 - ASP4 n 5943286 Z 683034 h T l D 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: o e y- : x- ota ept 18. Directional Survey ®Yes ^ No u i r ni n rin d info i n er 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 C 25.071): DIR / GR / RES / PWD, DIR / GR / RES, NEU /DEN `/jNOoN~La ~'o? f3i'9D ~~ I ~TYD 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 1. H-40 rfa 80' rf 30" Po 7 1 1 17- F ' - /8" 47 L- u u a 7 91' 1 -1/4" 5 I I I s " 7" 6# L- 3 8 7' 3 8-1/2" 4 x Li r t 1 x l ' ~~ ~ ~ ~ ~. 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i nterval open d N b f i Si .SIZE DEPTH SET MD PACKER SET MD er): ze an um orat on (MD+TVD of Top & Bottom; Per 6 s f 2-718" Gun Diameter 4-1/2", 12.6#, 13Cr80 8813' 8736' , p MD TVD MD TVD 11080' -11100' 8925' - 8922' 1 ' ' ' ' 25. Aclo, FRACTURE, CEMENT SQUEEZE, ETC. 8914 - 89 9 11540 - 11640 DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 152 Bbls of Diesel 26, PRODUCTION TEST Date First Production: August 25, 2008 Method of Operation (Flowing, Gas Lift, etc.): Flowin Date Of Test: 8/26/2008 HOUrS Tested: 9 PRODUCTION FOR TEST PERIOD OIL-BBL: 625 GAS-MCF: 19,380 WATER-BBL: 141 CHOKE SIZE: 80 GAS-OIL RATIO: 31,021 Flow Tubing Press. 317 CaSing PreSS: 2000 CALCULATED 24-HOURRATE• OIL-BBL: 1,666 GAS-MCF: 51,680 WATER-BBL: 376 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Cores Ac 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 29_9AG25GA71. {~UC1sFLET101~i None ~~-". ~~l. SEP ~D 9 20D6 ~~ ~1 Form 10-407 Revis~rgOM~ ~ ~ ~ ~ CONTINUED ON REVERSE SIDE G 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND "RS 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. Sag River 8980' 8590' None Shublik A 9008' 8612' Shublik B 9040' 8636' Shublik C 9062' 8653' Sadlerochit 9105' 8686' Top CGL 9442' 8871' Base CGL /Zone 2C 9725' 8947' Zone 2C /Base CGL (Inverted) 10946' 8946' Formation at Total Depth (Name): Zone 2C /Base CGL (Inverted) 10946' 8946' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Signed Terrie Hubble Title Drilling Technologist Date w / PBU 06-21 B 208-099 Prepared By Name/Number. Tenie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Eleazar ~EiP v3zquez, 5645918 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. ITeM 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. ITeM 4b; TPI (Top of Producing Interval). ITeM 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 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). ITeM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 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 25.07E IreM 29: Provide a listing of intervals tested. and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 06-21 Common Name: 06-21 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surtace Pressure Leak Off Pressure (BHP) EMW 7/19/2008 FIT 7,293.0 (ft) 7,091.0 (ft) 8.90 (ppg) 1,143 (psi) 4,421 (psi) 12.00 (ppg) 7/24/2008 FIT 8,970.0 (ft) 8,583.0 (ft) 8.50 (ppg) 714 (psi) 4,504 (psi) 10.10 (ppg) Printed: 8/13/2008 2:37:08 PM BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 7/15/2008 ~ 15:00 - 17:00 2.00 MOB ~ P 17:00 - 20:00 3.00 MOB P 20:00 - 22:00 2.00 MOB P 22:00 - 00:00 2.00 MOB P 7/16/2008 00:00 - 02:00 I 2.00 MOB P 02:00 - 04:00 2.00 DHB P 04:00 - 05:00 1.00 DHB P 05:00 - 06:00 1.00 KILL P 06:00 - 08:00 2.00 KILL ~ P 08:00 - 08:30 0.50 DHB P 08:30 - 10:00 1.50 WHSUR P 10:00 - 11:30 1.50 BOPSU P 11:30 - 12:30 1.00 BOPSU P 12:30 - 20:30 8.00 BOPSU P 20:30 - 21:15 0.75 BOPSU P 21:15 - 22:30 1.25 WHSUR P 22:30 - 00:00 1.50 PULL P 7/2008 00:00 - 01:00 1.00 WHSUR P PRE Release rig from DS 06-19A at 15:00 hrs. Bridle up and prepare derrick & lay down. Derrick down move due to soft gravel around DS 06-19A. PRE Move rig down well row to DS 06-21. Lay mats, spread herculite, spot sub unit over well. PRE Spot pit module, coat bridle lines with sealant. Prepare and inspect derrick to raise. PRE PJSM. Raise derrick. Bridle down. Accept rig at 00:00 on 7-16-2008 DECOMP Accept rig at 00:01 16-July-2008. Rig up top drive. Connect lines in interconnect. Take on seawater to pits. Load pipeshed with drillpipe. DECOMP Pressure test OA to 2000 si for 30 minutes -Passed. Perform CMIT - TxIA to 3,500 psi for 30 minutes -Passed. Bleed down pressure and blow down all lines. DECOMP Rig up Drill Site Maintenence with lubricator. Pressure test lubricator to 1000 psi - OK. Pull BPV - OK. DECOMP Reverse circulate -3 bbls diesel from tubing to cuttings tank. Shut down, swap lines. Circulate ~5 bbls diesel out from IA to cuttings tank. DECOMP Circulating 50 bbl soap sweep and seawater surface to surface down tubing and out IA displacing well from 9.3 ppg brine to clean up tubing prior to pulling. 5 bpm, 360 psi. DECOMP Drv-rod in back aressure valve. Test from below to 1000 psi for 10 minutes. DECOMP Nipple down existing tree and adapter flange. Check threads on tubing hanger and crossover. Install blanking plug into BPV. DECOMP Nipple up BOPE. DECOMP RU for pressure testing BOPE. Install 4" test joint into blanking plug. Run pressure testing lines. DECOMP Test BOPE (upper rams, annular & all manifold valves and c okes) to 250 psi low and 3500 psi high pressure using 4" and 5.5" test joints. Lower ram test postponed to after pulling 5.5" tubing -tubing hanger and plugs extend too high to close lower rams without interference. Jeff Jones waived state witness of test. Test witnessed by NAD TPs B. Perry, C. Weaver and BP WSLs C. Clemens, M. Martyn. During 2 tests, blanking plug leaking by. Had to wash off plug w/ rig pumps to re-seat ball in plug. After washing seat, test good. DECOMP Rig down from BOP testing. Lay down test joint. Blow down lines. Pull blanking plug from wellhead. DECOMP Rig up Drill Site Maintenence with lubricator extensions. Pressure test lubricator to 1000 psi - OK. Bleed off well pressure through IA valve. Retrieve BPV from well. No trapped pressure below. Rig down Drill Site Maintenence Lubricator. DECOMP RU to pull 5.5" completion. Pull landing joint to rig floor. Screw into tubing hanger. Back out lockdown screws. DECOMP Attempt to back out lock down screws on tubing hanger. 2 lock downs will not back out. Cycle tension on tubing hanger with Printed: 8/13/2008 2:31:14 PM • BP EXPLORATION Page 2 of 13 ~ Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/17/2008 00:00 - 01:00 1.00 WHSUR P DECOMP topdrive to assist - no change. AWGRS well service report from 24-June-08 lists all lock down screws cycled - OK. 01:00 - 03:30 2.50 WHSUR N SFAL DECOMP Continue to work at backing out 2 seized lock down screws. Mobilize Cameron with LDS drilling equipment to location. 03:30 - 09:00 5.50 WHSUR N SFAL DECOMP RU and begin drilling out seized up lock down screws. 09:00 - 09:30 0.50 PULL P DECOMP Pull tubing hanger to rig floor. Hanger pulled free at 175k hookload. Moving upweight was 145k. Monitor well -static. 09:30 - 10:00 0.50 PULL P DECOMP Circulate bottoms up with clean seawater ~ 480 gpm & 305 psi while rigging up control line spooling equipment. 10:00 - 20:30 10.50 PULL P DECOMP POH LD 191 joints of 5.5" 17 # 8rd tubing, 1 cut joint 21.23' strap, 6 GLMs, 1 SSSV Nipple and 2 stainless steel control lines w/ 27 clamps and 5 stainless steel bands recovered as expected. 20:30 - 21:00 0.50 BOPSU P DECOMP RU to test lower BOPE rams. Install test plug on 4" test joint. Fill stack. 21:00 - 21:30 0.50 BOPSU P DECOMP Pressure test lower rams w/4" test jt. to complete BOP test 250 psi / 3500 psi low/high pressure. Note: Outer annulus open to bleed tank with no flow -continue to monitor. 21:30 - 22:30 1.00 BOPSU P DECOMP RD from pressure testing lower pipe rams. 22:30 - 00:00 1.50 CLEAN P DECOMP MU BHA #1 - 8.5" MXL-1 RR bit, 9-5/8" casing scraper, Float sub, XO, 3ea 6-3/8" DCs, XO, HWDP. 7/18/2008 00:00 - 04:00 4.00 CLEAN P DECOMP PU 4" HWDP and 4" HT40 drill pipe 1X1 and RIH with BHA #1. Note: Outer annulus open to bleed tank with no flow. 04:00 - 05:00 1.00 CLEAN P DECOMP Tag up on 5.5" tubing stub at 7,785' md. PU - 155k, SO - 145k. Circulate bottoms up ~ 488 gpm, 1710 psi. 05:00 - 06:00 1.00 CLEAN P DECOMP Rack back 5 stands. PJSM & MU HES 9 5/8" Storm Packer and RIH setting top of the packer ~ 35' & LD running tool. Test packer from above to 1000 psi. Held. 06:00 - 09:00 3.00 WHSUR P DECOMP MU 9-5/8" Packoff running tool and engage packoff. !, BOLDS and pull packoff free with 40k. MU new 9-5/8" packoff and attempt to install, unable to run packoff pass TBG head. 09:00 - 10:00 1.00 WHSUR P DECOMP PJSM - ND BOP &TBG head and set stack on stump. Remove old TBG head from cellar. 10:00 - 14:00 4.00 WHSUR P DECOMP Clean & inspect mandrel hanger Install new 9-5/8" packoff and energize LDS. NU new TBG head and BOP. Test 9-5/8" packoff to 5000 psi for 30 min. Test Held. 14:00 - 15:30 1.50 WHSUR P DECOMP RU Test equipment and test TBG head flange to 250 psi / 3500 psi. Good Test RD /blow down test equipment. 15:30 - 16:00 0.50 WHSUR P DECOMP PJSM - MU HES Storm packer running tool and engage packer ~ 35', Check pressures 0 psi, Release packer POH & LD same. 16:00 - 19:00 3.00 CLEAN P DECOMP POH from 7350' to BHA #1 19:00 - 20:00 1.00 CLEAN P DECOMP Stand Back 4" HWDP and Collar stand, LD 9-5/8" casing scrapper & bit, Clean and clear floor. 20:00 - 22:30 2.50 DHB P DECOMP PJSM - RU for E-Line EZSV setting run. 22:30 - 00:00 1.50 DHB P DECOMP RIH on E-Line w/ Gamma Ray, Collar Locator, Casing Packer Setting Tool, HES 9-5/8" EZSV Plug. 7/19/2008 00:00 - 00:30 0.50 DHB N DECOMP Troubleshoot 65 feet of stranded armor. Cut away birdnested Printed: 8/13/2008 2:31:14 PM • BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABORS 7ES Rig Number: i Date From - To Hours ~ Task Code NPT Phase Description of Operations 7/19/2008 00:00 - 00:30 0.50 DHB N DECOMP wire, file down both ends, tape down single strand at ends to prevent further damage. 00:30 - 03:00 2.50 DHB P DECOMP Cont' E-Line, Tag up softly on top of tubing stump at 7785' E-Line md. Log up and see collar depth at 7325' md. Correlate and pull into position. Set Top of EZSV at 7320' E-Line and 5' above Collar. POH logging CCL to 200' md. 03:00 - 03:30 0.50 DHB P DECOMP Pressure test 9-5/8" csg /EZSV to 3500 psi and record on chart for 15 min. Held 03:30 - 06:30 3.00 STWHIP P WEXIT MU Smith 9-5/8" Trackmaster whipstock / MWD BHA /Surface test MWD and multi-cycle valve. Orient whipstock to BHA. 06:30 - 10:00 3.50 STWHIP P WEXIT RIH w/ whipstock BHA on 4" HWDP & DP from 209' to 7,318' md. 10:00 - 11:00 1.00 STWHIP P WEXIT Tag up on top of EZSV ~ 7,320' md. Pick up 2 feet and orient and set whipstock at 9 deg right of highside. Top of slide at 7,293' md, center window at 7,300' md, bottom of slide at 7,307' md. Set down 20k to confirm set, PU 50k to shear off. 11:00 - 12:30 1.50 STWHIP P WEXIT Displace well from seawater to 9.0 ppg milling fluid. 450 gpm, 1600 si. ~~. 12:30 - 17:00 4.50 STWHIP P WEXIT Establish parameters. Mill wondow in casing from 7,293' - Qlo,'Z~$ 7307' and plus 20 feet of new formation from center of window to 7,320' md. PU - 147k, SO - 143k, RTW - 145k 100 rpm, 7k TO on, 2k TO off 500 gpm, 2250 psi. 17:00 - 18:30 1.50 STWHIP P WEXIT Circulate and reciprocate to clean up hole. 500 gpm, 2250 psi. Pump 50 bbl super sweep pill. 285 pounds of metal recovered from milling operations. 18:30 - 19:00 0.50 STWHIP P WEXIT Pull one stand. Perform FIT to 12.0 ppg. MW 8.9 ppg, 7,293' and / 7,091' tvd at top of window. Pressure up to 1,143 psi and hold for 10 minutes - OK. 19:00 - 21:30 2.50 STWHIP P WEXIT Pull 3 stands out of hole and encounter 20k overpull and swabbing. Work pipe. Bring pumps online and circulate rotate and reciprocate. PU 150k, SO 140k, RTW - 145k. Pump 2 x surface to surface volumes at 550 gpm, 2350 psi. One 25 bbl weighted sweep and one 50 bbl super sweep pill went around. Saw formation cuttings returning throughout circulation until second super sweep pill back to surface. After super sweep back to surface, cuttings load cleaned up. Shut down pumps and monitor well. 21:30 - 00:00 2.50 STWHIP P WEXIT Pump dry job and POH from 7,127' - 1,776' md. No overpulls or swabbing. 7/20/2008 00:00 - 00:30 0.50 STWHIP P WEXIT POH from 1,776' to top of BHA ~ 209' md. 00:30 - 01:30 1.00 STWHIP P WEXIT LD milling BHA #2. Bottom mill full gauge, middle mill 1/8" un er gauge, watermellon mill 1/4" under gauge. 01:30 - 02:30 1.00 STWHIP P WEXIT Pull wear bushing. Function rams. Jet stack. Install wear bushing. 02:30 - 04:00 1.50 DRILL P WEXIT MU 8.5" drilling BHA #3 - DTX619M-D6 8.5" bit, 1.5 degree motor, ARC, MWD, NM Stab, tea NM Spiral DCs, NM Stab, iea Spiral DC, Float, Jars, HWDP. Shallow test -good. 04:00 - 07:00 3.00 DRILL P WEXIT RIH on DP to 6,831' and picking up 42 joints 1x1 before RIH w/ stands from derrick. 07:00 - 08:30 1.50 DRILL P WEXIT Slip/Cut 85' of drilling line. Inspect drawworks. Service top drive, blocks and crown. Printetl: 8/13/2008 2:31:14 PM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date From - To Hours Task Code NPT 7/20/2008 108:30 - 10:00 1.501 DRILL P 10:00 - 12:00 I 2.00 DRILL P 12:00 - 13:00 I 1.001 DRILL I P 13:00 - 15:30 I 2.50 I DRILL I P 15:30 - 19:00 I 3.501 DRILL I P 19:00 - 00:00 5.00 DRILL I P 7/21/2008 100:00 - 06:00 6.00 I DRILL P 06:00 - 12:00 I 6.001 DRILL I P 12:00 - 00:00 12.00 DRILL I P 17/22/2008 100:00 - 00:45 I 0.751 DRILL P 00:45 - 02:45 2.00 I DRILL I P 02:45 - 04:30 I 1.751 DRILL I P Start: 7/15/2008 Rig Release: 8/2/2008 Rig Number: Page 4 of 13 ~ Spud Date: 8/27/1982 End: 8/2/2008 Phase Description of Operations WEXIT MAD Pass for tie in to original wellbore from 6,955' to 7,136' and at 350 fph logging speed. 545 gpm, 1400 psi. Thin back mud from milling fluid during MAD pass operations. INT1 RIH to 7,320' and - no fill found. Begin drilling. Drill from 7,320' - 7,361' and PU - 155k, SO - 145k, RTW - 145k, 5k WOB 480 gpm, 1710 psi on, 1620 psi off INTi Hole packing off and splinterery and blocky shales coming ov Pull back to 7,289'. Continue to have pack-off issues in casing. Work pipe and circulate to clean up. INTi Circulate in spike fluid and weight up mud to 10.4 ppg. 420 gpm, 1740 psi. INTi RIH to top of 8' fill at 7,353' md. Resume drilling. Vary parameters as necessary to work fill out of hole w/ intermittant packoffs. 1 - 1.5 inch shale splinters and cavings were the majority of cuttings across shakers. Drill from 7,353' to 7,413' md. Shakers gradually cleaned up to just drilled cuttings. INT1 Directionally drill ahead from 7,413' to 7,596' md. PU - 155k, SO - 145k, RTW - 145k, 5-10k WOB 480 gpm, 2225 psi on, 2015 psi off 40 rpm, 5.5k TO on, 4k TO off MW - 10.7ppg CECD - 10.89ppg, AECD - 11.27ppg AST - 5.88 hr, ART - 1.71 hr, ADT - 7.59 hr INT1 Directionally drill ahead from 7,596' to 7,786' md. PU - 160k, SO - 151 k, RTW - 155k, 5-10k WOB 500 gpm, 2480 psi on, 2400 psi off 40 - 80 rpm, 5.5k TO on, 3.1 k TO off MW - 10.7ppg CECD - 11.O6ppg, AECD - 11.17ppg INT1 Directionally drill ahead from 7,786' to 8,025' md. PU - 162k, SO - 145k, RTW - 150k, 5-15k WOB 550 gpm, 3000 psi on, 2835 psi off 80 rpm, 5.7k TO on, 3.4k TO off MW - 10.7ppg CECD - 11.09ppg, AECD - 11.12ppg INTi Directionally drill ahead from 8,025' to 8,900' md. PU - 177k, SO - 154k, RTW - 160k, 5-10k WOB 500 gpm, 2945 psi on, 2830 psi off 80 rpm, 6.Ok TO on, 4.Ok TO off MW - 10.7ppg CECD - 11.07ppg, AECD - 11.28ppg AST - 11.35 hr, ART - 6.12 hr, ADT - 17.47 hr INT1 tionall drill ahead from 8,900' to TD at 8,971' md. Identi TD w/ clear reverse drilling break. PU - 178k, SO - 155k, RTW - 162 bB 500 gpm, 2945 psi on, 2830 psi off 80 rpm, 6.Ok TO on, 4.Ok TO off MW - 10.7ppg CECD - 11.07ppg, AECD - 11.28ppg ART - 0.97 hrs, ADT - 0.97 hrs. INT1 CBU x 2.5. 500 gpm, 2845 psi. Sample from bottoms up shows sand w/ glauconite. Intermittant 1 "-2" shale splinters seen over shakers every 15-20 seconds. Splinter frequency remained constant from 1 - 2.5 BU. INT1 Short trip from TD to 7,210' md. Pulled great. No swabbing. rrirnea: wisrzuun c~i:igrm BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date From - To Hours Task Code NPT Spud Date: 8/27/1982 Start: 7/15/2008 End: 8/2/2008 Rig Release: 8/2/2008 Rig Number: Phase Description of Operations 7/22/2008 102:45 - 04:30 I 1.751 DRILL I P 04:30 - 05:00 0.50 DRILL P 05:00 - 05:30 0.50 DRILL P 05:30 - 07:00 I 1.501 DRILL I P 07:00 - 12:30 I 5.501 DRILL I P 12:30 - 14:30 2.00 I DRILL P 14:30 - 15:30 1.00 DRILL P 15:30 - 16:30 1.00 DRILL P 16:30 - 18:00 I 1.501 DRILL I P 18:00 - 19:00 I 1.001 DRILL I P 19:00 - 21:30 2.50 DRILL P 21:30 - 00:00 2.50 DRILL P 00:00 - 03:00 3.00 BOPSU P 03:00 - 03:45 0.75 CASE P 03:45 - 12:00 8.25 CASE P 12:00 - 12:30 ~ 0.50 ~ CASE ~ P INT1 Only one 20k overpull seen at 7,720' md. Wiped once down to 10k. Othewise, less than 5k overpulls on entire trip into window. PU - 185k ~ TD, 165k ~ window. INTi Service topdrive and draworks. INT1 RIH from 7,210' and to TD ~ 8,971' md. Took 15k slackoff at 8,910' md. Otherwise, less than 5k slackoffs on RIH. INT1 Circulate Hi-Vis sweep surface to surface. Rotate and reciprocate while circulating. 500 gpm, 2709 psi, 80 rpm PU - 180k, SO - 150k, RTW - 155k 2" - 4" splintered shales unloading over shakers at bottoms up and continuing through return of surface to surface sweep. INT1 Circulate and condition mud increasing weight due to shale breakout. Increase weight over several ciculations from 10.7 ppg to 11.2 ppg. (Actual ECDs during drilling were 11.25ppg) Shakers cleaned up and the few splinters that continued to come were only 1/2" in size. INT1 Shut down, monitor well -Static. MW in 11.2, MW out 11.2. POH from 8,971' and to 7,213' md. One 20k overpull ~ 8,470'. Wiped once and reduced to 5k over. No other pulls over 5k during trip out. INTi Service topdrive, drawworks, blocks & crown. INTi RIH from 7,213' to TD ~ 8,971' md. Had to work BHA down at depth where Jars were across window -able to pass on 3rd attempt. No other problems RIH to TD. Precautionary wash last stand to TD to avoid plugging nozzles. No obvious sign of fill on bottom. INT1 Circulate 1.5 bottoms up. 450 gpm, 2070 psi. PU - 180k, SO - 155k, RTW - 160k, 80 rpm. Saw clear bottoms up returns and only less than 1/2" sized shale debris made up 30% of returns. INTi Shut down, monitor well -Static. MW in 11.2, MW out 11.2. POH from 8,971' and to 7,196' md. No over pulls over 5k during trip out. INT1 Pump dry job. Drop 2" rabbit. POH from 7,196 to top of HWDP ~ 810' md. INTi Lay down HWDP to shed 1x1. Lay down BHA #3. Bit Grade 1 - 2 - WT - S - X - I - BT - TD. Outer cutters on 2 blades would be graded a 4. Outer cutters on 4 blades would be graded a 1. One nozzle 90% plugged w/float rubber. LNRi PJSM. Install test lu CO to rams f/3.5" x 6" to 7". RU test equipment and test to 250/3500 psi low/high pressure. Record on chart. Test good. LNR1 RU casing running equipment. LNRi MU shoe track w/Bakerlok. RIH and check floats both ways. Function as required both ways. MU tq on BTC 7,950 ft lbs. RIH w/7" 144 joints of 26# L-80 BTC-M liner string at 1 jt. per minute to 5,911' filling each jt w 2 ine, topping off every 10 joints. LNR1 MU 7" x 9-5/8" Flexlock finer hanger2XP liner top packer/Hydraulic setting tool w/rotating dog sub to 7" liner. RIH w/ 1 stand of DP to 6,046' md. Nnnted: turuzuuar.'staarnn • BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: i Date From - To Hours ~ Task Code NPT ~ Phase Description of Operations 7/23/2008 12:30 - 14:00 1.50 CASE P LNR1 Circulate 304 bbls, 205 gpm, 430 psi. PU - 160k, SO - 145k. 14:00 - 15:00 1.00 CASE P LNR1 RIH from 6,046' to 7,226' w/drillpipe from derrick. Lay down 2 singles for spaceout on bottom. 15:00 - 16:00 1.00 CASE P LNR1 Circulate above 9-5/8" window. Stage pump rates up and pump bottoms up 2 s 08 gpm, 530 psi. PU - 175k, SO - 153k. 16:00 - 17:30 1.50 CASE P LNRi RIH from 7,226' to 8,940'. No drag or overpulls more than 5k. Correct displacement volumes. 17:30 - 18:00 0.50 CASE P LNRi Pick up last single with cement head. MU top drive cementing head. Wash liner down and tag bottom at 8,971' md. Pick up 1 foot and set shoe ~ 8 970' md. PU - 197k, SO - 165_k. 18:00 - 20:30 2.50 CEMT P LNR1 Stage up pump rates to 205 gpm, 850 psi. PJSM w/Schlumberger, Baker, all hands, BP WSL, NAD TP. 20:30 - 00:00 3.50 CEMT P LNR1 Pump 5 bbls H2O w/Schlumberger pumps to floor and out tee to flow line. Shut in. Test lines to 4500 psi and walk lines. Pump mud push to rig floor w/Schlumberger pumps and overboard all H2O in lines via tee at floor. Pump a total of 24.4 bbls -11.4 ppg mud push down hole. At 21:27 start to mix and pump 159.2 bbls o 11.5 ppg Lite rete slur .ICP - 870 psi, - 695 psi. but down. At 22:09 start to mix and pump 29.2 bbls class G tail slurry plus additives at 164 gpm'1CP - psi, - psi. ut down. Wash lines to T' on rig floor. Drop drill pipe wiper dart and note plug drop indicator trip. Total displacement = 255.9 bbls. Switch to rig and pump 130 bbls 11.2 ppg LSND mud ~ 5 bpm ICP - 333 psi, FCP - 917psi. (Slow to 3 bpm at 25 bbls away & see drill pipe wiper dart catch liner wiper plus ~ 30.3 bbls away. and shear off as expected before returning to 5 bpm). At 130 bbls away, reduce pump rate to 3 bpm for next 40 bbls ICP - 615 psi, FCP - 835 psi. At 170 bbls away, reduce pump rate to 2 bpm for next 52 bbls ICP - 715 psi, FCP - 881 psi. At 222 bbls away, reduce pump rate to 1.5 bpm for next 34 bbls ICP - 940 psi, FCP - 1124 psi. See plugs bump landing collar as expected. Full returns throughout job. Cement in place at 23:57. Bring pressure up to 2800 psi and hold f/3 mins. 7/24/2008 00:00 - 01:00 1.00 CASE P LNRi Settin han er and aaker after bumping plug. Slack off entire string weight - 45k to check liner hanger. Hanger holding. Pressure to 4,300 psi and see slight indication on weight indicator of pusher tool stroke. Bleed off pressure to zero and check floats for bleedoff back to surface. Floats holding. Rotate 15 turns right at the tools to release C-2 running tool, pressure up to 1000 psi. PU until PBR packoff cleared liner top extension sleeve and pressure bled off to 100 psi PU - 75k, SO - 72k. Circulate cement 50 bbls above liner top. PU rotating dog sub clear of liner top and rotate at 15 rpm. SO rotating w/ 45k (entire string weight) three times to confirm ZXP packer set. PU 20' to clear liner top w/stinger and put NOGO mark on drill pipe. Circulate cement out of well at 480 gpm. Mud ush seen at surface and -20 bbls of contaminated cement noted, 01:00 - 01:30 0.50 CASE P LNR1 Shut down and lay down cementing head and 1 single. 01:30 - 02:30 1.00 CASE P LNR1 POH on DP to top of running tools. rnntea: wi:vruuu c~t:tn rm BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: i Date From - To Hours Task Code NPT Phase Description of Operations 7/24/2008 02:30 - 03:00 0.50 CASE P LNRi Lay down running tools and inspect. Pusher tool sheared sucessfully. Backup dog sub not sheared due to low string weight. 03:00 - 03:30 0.50 BOPSU P LNRi PJSM. Install test plug. CO top rams t/3.5" x 6" from 7". 03:30 - 04:00 0.50 BOPSU P LNRi RU test equipment and test upper rams with 4" test joint to 250/3500 psi low/high pressure. Record on chart. Test good. Function test all rams and Annular Preventer. ', 04:00 - 04:30 0.50 BOPSU P LNR1 RD test equipment. Install wear bushing. LD test jt. i 04:30 - 06:00 1.50 DRILL P PROD1 PU 6-1/8" drilling BHA #4 w/MX-R18DX, 7/8 2 stage AIM Motor 1.5ABH w/float, NM Stab, NM Flex Lead DC, Impulse MWD, ADN, 3 NM Flex DC, XO, Hyd Jars. 06:00 - 09:00 3.00 DRILL P PROD1 RIH picking up 4" drill pipe 1x1 from 222' to 3,150'. Shallow tested MWD at 1,300' - 250 gpm, 1248 psi. 09:00 - 11:30 2.50 DRILL P PROD1 RIH on 4" DP from derrick from 3,150' to 8,750'. 11:30 - 12:30 1.00 DRILL P PROD1 RU test equipment and test casing to 3500 psi and hold for 30 mins w/chart. 85 strockes to ressure u to 3500 psi. 15 minute pressure 3500 psi, 30 minute pressure 3500 psi. RD test equipment. 12:30 - 16:30 4.00 DRILL P PRODi Tag up and drill plugs/landing collar & cement from 8,884' to 8,968'. 250 gpm, 2030 psi, 50 rpm, 5.5k tq. Found plugs on depth at 8,884' and collar on depth at 8,926'. 16:30 - 18:30 2.00 DRILL P PRODi Displace well f/11.2 LSND mud to 8.5 ppg Flo-Pro. 250 gpm, 1350 psi. Pump 150 bbls H2O and 50 bbl Hi-Vis spacer pill between LSND and FloPro SF. 18:30 - 19:00 0.50 DRILL P PROD1 Tag up on shoe and drill out at 8,970' and drill new hole to 8 992'. 250 gpm, 1390 psi, 50 rpm, 3.5k tq, 5-10k WOB. Pull back above 7" shoe at 8,884'. 19:00 - 20:00 1.00 DRILL P PROD1 RU and Perform FIT to 10.1 ppg EMW w/8.5 ppg mud, 8,583' 20:00 - 00:00 4.00 DRILL P PROD1 Directionally drill ahead from 8,992' to 9,045' md. Drilling through Shublik slow (10-20 fph). 10% of cuttings across shakers are very hard black and crystaline. PU - 165k, SO - 148k, RTW - 155k, 5-15k WOB 250 gpm, 1380 psi on, 1290 psi off 50 - 80 rpm, 4.Ok TO on, 3.Ok TO off MW - 8.4ppg ART - 1.03 hrs, AST - 2.45 hrs ADT - 3.48 hrs. 7/25/2008 00:00 - 06:00 6.00 DRILL P PROD1 Directionally drill ahead from 9,045' to 9,285' md. Drilling through Shublik slow (10-20 fph). 10% of cuttings across shakers were very hard black and crystaline during Shublik drilling. ROP increased again at top of Saddlerochit ~ _9,105' md_ ~PU - 168k, SO - 149k, RTW - 158k, 5-15k WOB 250 gpm, 1450 psi on, 1400 psi off 50 - 80 rpm, 4.5k TO on, 3.5k TO off MW - 8.4pP9 06:00 - 12:00 6.00 DRILL P PROD1 Directionally drill ahead from 9,285' to 9,554' md. PU - 172k, SO - 134k, RTW - 158k, 5-15k WOB 250 gpm, 1468 psi on, 1340 psi off 80 rpm, 4.5k TO on, 3.5k TO off, MW - 8.4ppg 12:00 - 23:00 11.00 DRILL P PROD1 Directionally drill ahead from 9,554' to 10,000' md. PU - 175k, SO - 147k, RTW - 155k, 5-15k WOB 250 gpm, 1490 psi on, 1441 psi off rnntea: wt:N~uuss c.~t:tn rrvi BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/25/2008 12:00 - 23:00 11.00 DRILL P PROD1 80 rpm, 4.Ok TO on, 3.Ok TO off MW - 8.4PP9 ART - 7.28 hrs, AST - 9.88 hrs ADT - 17.16 hrs. 23:00 - 00:00 1.00 DRILL P PROD1 Begin circulating hole clean. 250 gpm, 1426 psi. Reciprocate 70' & rotate 100 rpm. 3k Tq off. PU - 175k, SO - 147k, RTW - 155k. 7/26/2008 00:00 - 00:30 0.50 DRILL P PROD1 Continue circulating. Total circulation 1.3 bottoms up. 250 gpm, 1426 psi. Reciprocate 70' & rotate 100 rpm. 3k Tq off. PU - 175k, SO - 147k, RTW - 155k. Shut down, monitor well -static. MW in - 8.4+ppg, MW out 8.4+ppg 00:30 - 04:00 3.50 DRILL P PROD1 POH from 10,000' and to top of BHA at 282' md. Pump salt weig e ry ~o once insi a casing s oe: No overpulls or swabbing while POH. 04:00 - 06:00 2.00 DRILL P PRODi PJSM. Lay down or rack back BHA #4 as appropriate. Remove nuclear source. Download MWD tools & re-program. Bit grade 3-7-BT-A-E-2-LT-PR. 06:00 - 07:00 1.00 DRILL P PROD1 PU 6-1/8" drillin BHA #5 w/ DTX-613M-B15 bit, 7/8 2 stage AIM Motor 1.5ABH w loat, NM Stab, NM Flex Lead DC, Impulse MWD, ADN, 3 NM Flex DC, Ball Catcher Sub, CCV, XO, Hyd Jars. 07:00 - 10:00 3.00 DRILL P PROD1 RIH on 4" DP from derrick from 296' to 8,890'. Shallow test MWD ~ 1000' md, 250 gpm, 850 psi. 10:00 - 11:00 1.00 DRILL P PROD1 Slip and cut 90' of drilling line. Service topdrive and drawworks. 11:00 - 12:00 1.00 DRILL P PROD1 Continue RIH from 8,890' to 9,850' md. PU - 175k, SO - 150k. 12:00 - 13:00 1.00 DRILL P PROD1 Ream undergauge hole from 9,850' and to 10,000' md. 246 gpm, 1397 psi, 50 rpm. 13:00 - 16:00 3.00 DRILL P PROD1 Directionally drill ahead from 10,000' to 10,195' md. PU - 177k, SO - 147k, RTW - 155k, 7k WOB 250 gpm, 1510 psi on, 1421 psi off 80 rpm, 4.Ok TO on, 3.Ok TO off, MW - 8.4ppg 16:00 - 16:45 0.75 DRILL P PROD1 Well took a 20 bbl loss in 10 minutes at 10,195' and bit depth. is up o 0 om, s u own pumps an ro pumps intermittantly to fill hole while mixing up 40 bbl 25 pound/bbl LCM pill. 16:45 - 17:45 1.00 DRILL P PROD1 Sot LCM ill. Well takin 25 bbls/hr while spotting pill, and reduced to 5 bbls er hour after pill around corner. 17:45 - 00:00 6.25 DRILL P PROD1 Directionally drill ahead from 10,195' to 10,620' md. - Seeoage losses during drilling at 5-10 bph. PU - 180k, SO - 145k, RTW - 157k, 7k WOB 250 gpm, 1672 psi on, 1524 psi off 80 rpm, 5.Ok TO on, 3.Ok TO off MW - 8.4+ ppg ART - 6.05 hrs, AST - 0.27 hrs, ADT - 6.32 hrs. 7/27/2008 00:00 - 06:00 6.00 DRILL P PROD1 Directionally drill ahead from 10,620' to 11,040' md. a e losses to erin off to zero. PU - 182k, SO - 145k, RTW - 157k, 7k WOB 250 gpm, 1690 psi on, 1542 psi off 80 rpm, 6.Ok TO on, 4.Ok TO off MW - 8.5 PP9 06:00 - 12:00 6.00 DRILL P PROD1 Directionally drill ahead from 11,040' to 11,444' md. Printed: 8/13/2008 2:31:14 PM • • BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/27/2008 06:00 - 12:00 6.00 DRILL P PROD1 Losses during drilling at -25 bph. PU - 190k, SO - 140k, RTW - 155k, 7k WOB 250 gpm, 1795 psi on, 1630 psi off 80 rpm, 6.5k TO on, 4k TO off MW - 8.5 PP9 ART - 5.95 hrs, AST - 2.25 hrs, ADT - 8.3 hrs. 12:00 - 16:00 4.00 DRILL P PROD1 Directionally drill ahead from 11,444' to 11,735' md. Stringing in LCM PU - 187k, SO - 140k, RTW - 153k, 7k WOB 250 gpm, 1751 psi on, 1597 psi off 80 rpm, 6.5k TO on, 4k TO off MW - 8.5 ppg 12:00-16:00 -ART - 2.17 hrs, AST - 0.53 hrs, ADT - 2.7 hrs. 16:00 - 16:30 0.50 DRILL P PROD1 Circulate one open hole volume - 250 gpm, 1600 psi. After TD, losses increasing gradually to 40-50 bph. Still strinaina in LCM. 16:30 - 23:00 6.50 DRILL P PROD1 MAD Pass ~ no faster than 300 fph from TD ~ 11,735' and to 10,600' md. 250 gpm, 1380 psi, PU - 178k, SO - 150k, RTW 155k, 80 rpm, 3.5k TO. 23:00 - 00:00 1.00 DRILL P PRODi Backream ~ _ 50 fpm pulling speed from 10,600' - 10,037' md. No sliding during that interval while drilling. 7/28/2008 00:00 - 04:00 4.00 DRILL P PRODi MAD Pass ~ no faster than 300 fph from 10,037' and to 9,200' md. 80 rpm, 3.Ok TO. Still stringing in LCM. Losses varying from 25-40 bgh. 04:00 - 05:30 1.50 DRILL P PROD1 Drop ball to open CCV at 7" liner shoe. 1200 psi opening pressure spike seen at 900 strokes while pumping at 85 gpm. Circulate at 500 gpm 1340 psi. Dynamic losses still at 35 bph with increased pump rate. Shakers cleaned up except for LCM products after 1 1/2 bottoms up. 05:30 - 06:00 0.50 DRILL P PROD1 Observe well for static losses. Gtatir. loss rate at a steady 17, 06:00 - 07:45 1.75 DRILL P PROD1 Build 30 bbl LCM pill of 40 pounds per bbl of LCM. Drop BHA shut-off ball for CCV and pump down. After 900 strokes, BHA assumed to be shut off. Spot LCM Pill at casing shoe - 250 gpm, 850 psi. 07:45 - 08:00 0.25 DRILL P PROD1 Shut down, monitor well. Static loss rate still 15+ bbls per our., MW in 8.5ppg, MW out 8.5 ppg. 08:00 - 11:00 3.00 DRILL P PROD1 POH from 9,160' to top of BHA at 296'. 11:00 - 13:00 2.00 DRILL P PROD1 PJSM. Lay down BHA #5. Remove nuclear source. Download MWD tools. Bit grade 2-2-CT-A-X-I-WT-TD. 13:00 - 15:00 2.00 CASE P RUNPRD RU 4.5" casing running equipment w/Torque Turn and compensator for Chrome VamTop. PJSM. 15:00 - 20:15 5.25 CASE P RUNPRD PU and BakerLok shoetrack, jts 1,2,3. RIH and check floats. PU and RIH w/69 jts of 4.5" 12.60# 13-Cr-80 VamTop liner. Torque Turn to 4440 . I s. 20:15 - 22:30 2.25 CASE P RUNPRD RD casing equipment. Change bales. MU Baker ZXP linertop packer/ HMC liner hanger assembly to liner and circulate 1.5 liner volumes. Stage pumps up to 5 bpm, 138 psi, from 4 bpm, 120 psi, 3 bpm 110 psi. PU 62k, SO - 60k. 22:30 - 00:00 1.50 CASE P RUNPRD RIH w/liner on 4" drill pipe f/derrick from 2,896' - 4,861'. Filling pipe every 10 stands. ~nntea: wi:sreuun csi:iarm BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/29/2008 00:00 - 02:00 2.00 CASE P RUNPRD Continue running in hole to casing shoe with 4.5" Liner and hanger on drillpipe from 4,861 to 8,790' 02:00 - 03:00 1.00 CASE P RUNPRD Circulate 1.5 drill pipe + liner volume at 4 bpm, 529 psi. Loss rate at a steady 27 bph while circulating 3 bpm and 4 bpm. No cnange seen witn rate cnange. 03:00 - 05:30 2.50 CASE P RUNPRD RIH w/. 4.5" Liner on 4" dril- pipe from derrick to TD ~ 11,735' md. Circulate each stand down at 3 bpm from casing shoe to 10,200' and (depth of initial losses). Circulate to remove LCM Pill. 11,735' md. 05:30 - 09:00 3.50 CASE N SFAL RUNPRD RU cement head. During RU of cement head, Cement head union broke at weld-on 1502 union, The Union broke off at the cement head swivel. The cement manifold did not fall due to safety strap attached to Top Drive. RD cement head, MU topdrive. Circulate ~ 3 bpm / 610 psi, Replace Cement Head. 09:00 - 12:00 3.00 CEMT P RUNPRD Cement liner as follows: Pump water through Tee to flow line and pressure test lines to 4,500 psi. Flush water out through Tee to flow line then switch down hole with 20 bbl MudPush II at 11.0 ppg. Mix (batch mix) and pump 78 bbl (376 sx) 15.8 ppg class "G" with Gas-block additive at 5 BPM. Wash up lines through "T". NO Cement on top of Plug. Switch to rig pumps, Drop wiper dart and displace dart with 43 bbl 8.4 ppg pert pill followed with 88 bbl 8.5 ppg drilling mud at 4.5 BPM and last 11 bbl at 2 BPM. Bumo olua. CIP ~ 11:52 12:00 - 14:00 2.00 CEMT P RUNPRD Pressure up to 4000 psi to set Hanger and release from running tool. Bleed pressure and check floats. P/U to ensure running tool is released, S/O 75K per Baker Rep to set packer with rotation. Repeat sequence to ensure set. Positive surface indication of set. Pressure up string to 1000 and pick up. Circulate 30 bbl at 533 gpm / 1575 psi. Pick up and circulate out cement at max pump rate, 16 bbls of cement returns. 14:00 - 15:00 1.00 CEMT P RUNPRD Displace mud from the top of the 4.5" liner to 8.5 ppg seawater Monitor Well 8.5 ppg In /Out 15:00 - 18:00 3.00 CASE P RUNPRD POH with Stand back to 2509" 18:00 - 20:00 2.00 CASE P RUNPRD Lay Down Excess Drill Pipe -L/D Running Tool, Pimn sheared on "Dog" Sub -No Cement in Drill Pipe or On the collars 20:00 - 21:00 1.00 CASE P RUNPRD L/D Third Party equipment and clear floor -Pull Wear bushing 21:00 - 00:00 3.00 BOPSU P OTHCMP PJSM with Rig Crew on testing BOP's Test BOP's to 250 Low and 3500 psi High - i Hess 'Test by AOGCC rep Lou Grimaldi, test witnessed by BP WSL Dave Newlon, NAD Toolpusher Lenward Toussant Test using 4.5" test joint Test to 250 psi low and 3500 psi high, each test held for 5 Pnmetl: wi~izooa r.~i:ia rM BP EXPLORATION Page 11 of 13 Legal Well Name: 06-21 3.00 BOPSU P OTHCMP minutes and charted #1 Test -Top Pipe 3 1/2" x 6" Var.Rams, Choke Valves 1,2,3,16, HCR Kill valve, Upper IBOP #2 Test -Choke Valves 4,5,6, Manual Kill valve, TIW, Manual IBOP #3 Test -Choke Valves 7,8 & 9 #4 Test -Test Super Choke and Manual Choke to 250 psi low, 1500 high 2.50 BOPSU P OTHCMP Finish Testing BOP's to 250 Low and 3500 psi High -Witness of Test by AOGCC rep Lou Grimaldi, test witnessed by BP WSL Dave Newlon, NAD Toolpusher Lenward Toussant Test using 4.5" test joint Test to 250 psi low and 3500 psi high, each test held for 5 minutes and charted #5 Test -Choke Valves 10, 11 and 15 #6 Test -Choke Valve #14 #7 Test -Manual Valve on BOP stack #8 Test -Choke Line HCR Valve on Stack #9 Test -Bottom 2 7/8" x 5" Var. Pipe Rams #10 Test -Blind Pipe Rams, Choke Valves 12 &13 Accumulator Test Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABORS 7ES Rig Number: i Date From - To Hours ~ Task Code NPT Phase Description of Operations 7/29/2008 121:00 - 00:00 7/30/2008 100:00-02:30 02:30 - 03:00 0.50 BOPSU P 03:00 - 04:00 1.00 CASE P 04:00 - 09:30 5.50 PERFO P 09:30 - 10:30 1.00 BOPSU P 10:30 - 13:00 2.50 13:00 - 17:00 4.00 17:00 - 19:30 2.50 19:30 - 00:00 7/31/2008 00:00 - 03:30 03:30 - 04:00 04:00 - 06:00 06:00 - 10:00 Operations Summary Report P P P 4.50 PERFO~ N 3.50 PERFO N 0.50 PERFO N Test using 2.875" test joint to 250 Low and 3500 psi High Bottom Rams and Annular No Failures, Good Test OTHCMP Rig Down Test Joint and Set Wear Bushing RUNPRD Test 4 1/2" Production Liner to 3500 psi for 30 minutes -Lost 20 psi first 15 minutes & 0 psi the last 15 minutes OTHCMP PJSM with Schlumberger Perforating Crew and NAD Rig Crew -Pick up Perf. Guns and 2 7/8" Fox DP OTHCMP R/U and test 2 7/8" Dart and TIW valves -record and charted tests -Test to 250 psi low and 3500 psi high -Good test on TIW valve, -Dart valve failed, change out and retested and passed OTHCMP Continue picking up 2 7/8" Fox Drill pipe to 2928' OTHCMP RIH with 4" Drill Pipe -Tag. LC ~ 11,643 (tag 3' high) -Set Guns on depth OTHCMP Rig up and perform firing sequence 3x ~~ -no surface indications of guns firing -No drop in fluid -No Indications on Drill pipe sonic monitor -Pressure test liner and casing to 1200 psi for 10 min., No Drop in pressure -Monitor well, static, 8.5 ppg seawater In & Out DFAL OTHCMP POH with guns ,standing back 4" drill pipe DFAL OTHCMP Lay Down 2 7/8 "Fox" Drill Pipe DFAL OTHCMP PJSM on Laying down unfired Perforating Guns -Schlumberger Perf Crew, NAD Rig Crew and Toolpusher and BP WSL 2.00 PERFOB~ N DFAL OTHCMP 4.00 PERFOB N DFAL OTHCMPDFAL OTHCMP did not Fire ~r run #2 rnntea: wi3¢uua z:~ianrrvi ~ ~ BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date From - To ~ Hours Task Code NPT Spud Date: 8/27/1982 Start: 7/15/2008 End: 8/2/2008 Rig Release: 8/2/2008 Rig Number: Phase Description of Operations 7/31/2008 06:00 - 10:00 0:00 - 14:00 14:00 - 17:30 17:30 - 18:20 4.00 .00 3.50 0.83 PERFO ERFO PERFO PERFO N N N N DFAL FAL DFAL DFAL OTHCMP THCMP OTHCMP OTHCMP -Downloaded data from "E" firing heads -Consult with Schlumberger Technical team -Inspect guns and prepare new "E" firing heads and redundant mechanical head -O & A pert string Pick up Perforating guns and 2 7/8Fox Drill pipe RIH with Perf Guns on 4" drill to LC ~ 11643' Put guns on depth -Flush all air out of Kill line and Stand Pipe -Line up to fire Guns -Perform firing sequence, E firing heads fired ~ 18:20 hrs -Positve indication of both sets of guns firing -Same firing sequence used as in run #1 _~ Perforations ~ 11,080 -11,100 ~ ~ 11,540 -11,640 Initial losses at 18 BPH to formation. c umberger 2.88" 6 spf Power Jet Omega Guns 18:20 - 19:00 0.67 PERFO P OTHCMP POOH to 10900' to get guns above perforations 19:00 - 20:00 1.00 PERFO P OTHCMP CBU ~ 290 gpm / 1830 psi Monitor well, Losin fluid ~ 5-10 b h 8.5 ppg In/Out 20:00 - 00:00 4.00 PERFO P OTHCMP POH Laying down drill pipe 1 x 1 Losing fluid to formation at 2 BPH 8/1/2008 00:00 - 03:30 3.50 PERFO P OTHCMP Lay Down 4" Drill Pipe 1 x 1 03:30 - 07:00 3.50 PERFO P OTHCMP Lay Down 2 7/8" Fox Drill Pipe 1 x 1 Losing fluid to formation at 1-2 BPH 07:00 - 10:00 3.00 PERFO P OTHCMP PJSM with Schlumberger Perforating crew and NAD Rig Crew on laying down pert guns safely -Lay Down Perforating guns -All Shots Fired 10:00 - 11:00 1.00 PERFO P OTHCMP Clear Floor of Perf Gun Handling Equipment -Prep for Rig Up equipment 11:00 - 13:00 2.00 BUNCO RUNCMP Pull Wear Bushing -PJSM on Rigging Up to Run Completion -R/U Double Stack Power Tong, Elevators, Slings, Computer and Compensator 13:00 - 00:00 11.00 BUNCO RUNCMP R80 Vam To tubin as per running tally -WLEG 'XN' nipple, X nipple, Baker S-3 packer, X Nipple, 5 GLM, X nipple -Baker-Loc below Packer -No SSSV -Jet Lube Seal Guard thread compound on pin end connections -Avg Torque on connection = 4400 ft/Ibs -X' nipple placed at 2014' per tubing detail. -5 GLMs, 4.5" X 1" KBG2 - 1 R. -The #5 GLM ~ 3658 'md installed with DCK shear valve on BEK 8/2/2008 00:00 - 02:00 2.00 BUNCO RUNCMP Pick up 4.5" 12.6# 13CR80 Vam Top tubing as per running tally and tag up on bottom of PBR ~ 8819 (tubing depth) Repeat Sequence with the same results Tag top of Liner 8808.5' Nnntea: tsit~~~uuts rsta4rnn ~ ~ BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 06-21 Common Well Name: 06-21 Spud Date: 8/27/1982 Event Name: REENTER+COMPLETE Start: 7/15/2008 End: 8/2/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/2/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/2/2008 02:00 - 02:30 0.50 BUNCO RUNCMP Pull Back to Jt #206 -P/U space out pup 9.84' -P/U Jt #207 -Make up Hanger , Pup jt and RIH with Landing Jt. -PUW = 123k /SOW = 115k -85k sitting on hanger -Set WLEG 5.41' in PBR 02:30 - 03:00 0.50 BUNCO RUNCMP Run in Lock Down Screws an torque to 450 Wlbs of Torque 03:00 - 04:30 1.50 BUNCO RUNCMP Rig Up and Reverse circulate 95 bbl seawater treated with corrosion inhibitor into the annulus followed by 173 bbls of seawater to position of GLM #5 to top of packer 04:30 - 06:00 1.50 BUNCO RUNCMP Dro ball /rod to RHC lu .Set the packer as per Baker and test the tubin to 3500 psi for 30 minutes. No Pressure loss, Good Test. Slowly bleed tubing pressure to 1500 psi. Test the Test. Bleed IA then Tubing to 0. Pressure up IA to z(ib() psi and see shear valve shear open. Circ both ways to ensure circulation. 06:00 - 06:30 0.50 BOPSU P RUNCMP -Set TWC - est from below 1000 psi 10 min 06:30 - 07:30 1.00 BOPSU P RUNCMP D BOPE stack and set back on stump 07:30 - 12:00 4.50 WHSUR P RUNCMP NU Adapter and tree. -Test Packoff to 5000 psi for 30 min, good test -Test tree w/diesel to 5000 psi for 30 min, good test 12:00 - 16:30 4.50 WHSUR P RUNCMP -Lubricate out TWC. - itt a ed and Freeze Protect -PT 3500psi -Reverse circulate 152 bbls diesel, 1 bpm, 750 psi. -U-Tube, Blow down lines. 16:30 - 18:30 2.00 WHSUR P RUNCMP -RU DSM -Set BPV and test to 1000 psi for 10 min 18:30 - 19:00 0.50 WHSUR P RUNCMP Install Gauges , ecure a an eady tree for handover 19:00 - 00:00 5.00 RIGD P POST Ready Rig to move from DS-06 to "D" Pad -Waiting on rig mats and plywood to be laid down on road (Mats being used moving another rig) -Clear 3rd party equipment and haul MWD and Geo Shacks to D Pad -Move Drilling Mud Products and drilling tools to D pad Release Rig ~ 23:59 08/02/2008 Printetl: 6/13/2008 2:31:14 PM by '" ~ . _ .. _ Schlumberger uauo-c-i rs purvey rc~~c~n Report Date: July 30, 2008 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski gient: BP Exploration Alaska Vertical Section Azimu~: 324.200° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: DS-06 / 06-21 ND Reference Datum: Rotary Table Well: 06-21 TVD Reference Elevation: 65.73 ft relative to MSL Bor~ole: 06-21 B Sea Bed 1 Ground Level Elevation: 37.00 ft relative to MSL UIMIAPIIk: 5000292080202 Magnetic Declination: 23.189° Survey Name 1 Date: 06-21 B /July 22, 2008 Total Field Strength: 57680.314 nT Tort I AHD 1 DDI 1 ERD ratio: 215.332° / 4527.82 ft / 6.106 / 0.505 Magnetic Dip: 80.897° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: July 22, 2008 Location Latll.ong: N 70.24394129, W 148.49737372 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 5941065.630 ftUS, E 686025.550 ftUS North Reference: True North Grid Convergence Angle: +1.41421924° Total Corr Mag North -> True North: +23.189° Grid Scale Factor. 0.99993931 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea ND Typ Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de d ft ft ft ft ft ft ft de 100 ft ftUS ftUS n nn n nn n nn n nn n nn n nn aoe~na~ az auan9F FF N 7n 9d3Qd19A W 1dR d973T~79 rroteaea-up u.uu WRP 28.73 u.vu 0.00 u.uu 0.00 -va.~~ -37.00 ~.~~ 28.73 .,.~~ 0.00 ,,.~~ 0.00 .,..,,. 0.00 .,...., 0.00 .,..,., 0.00 ....,., 0.00 .,.,, .,.,,.,.,,., 5941065.63 ..___-- -- 686025.55 •- • - - ~-- ~ ~-- -- ~ ~- - - - - N 70.24394129 W 148.49737372 CB Gyro MS 91 .73 0.00 180.00 26.00 91. 73 0.00 0.00 0.00 0.00 0.00 0.00 5941065.63 686025.55 N 70.24394129 W 148.49737372 191 .73 0.25 156.00 126.00 191. 73 -0.21 0.22 0.22 -0.20 0.09 0.25 5941065.43 686025.64 N 70.24394075 W 148.49737300 291 .73 0.25 165.00 226.00 291. 73 -0.63 0.65 0.65 -0.61 0.23 0.04 5941065.03 686025.80 N 70.24393963 W 148.49737183 391 .73 0.50 163.00 326.00 391. 73 -1.25 1.31 1.31 -1.24 0.42 0.25 5941064.40 686026.00 N 70.24393791 W 148.49737034 491 .73 0.25 167.00 425.99 491. 72 -1.86 1.96 1.96 -1.87 0.59 0.25 5941063.78 686026.19 N 70.24393619 W 148.49736891 591 .73 0.00 180.00 525.99 591 .72 -2.06 2.18 2.18 -2.08 0.64 0.25 5941063.57 686026.24 N 70.24393561 W 148.49736852 691 .73 0.00 180.00 625.99 691 .72 -2.06 2.18 2.18 -2.08 0.64 0.00 5941063.57 686026.24 N 70.24393561 W 148.49736852 791 .73 0.00 180.00 725.99 791. .72 -2.06 2.18 2.18 -2.08 0.64 0.00 5941063.57 686026.24 N 70.24393561 W 148.49736852 891 .73 0.25 98.00 825.99 891 .72 -2.21 2.40 2.28 -2:11 0.86 0.25 5941063.54 686026.46 N 70.24393553 W 148.49736677 991 .73 0.25 51.00 925.99 991 .72 -2.35 2.81 2.36 -2.00 1.25 0.20 5941063.66 686026.84 N 70.24393582 W 148.49736366 1091 .73 0.25 47.00 1025.99 1091 .72 -2.31 3.25 2.33 -1.72 1.57 0.02 5941063.95 686027.17 N 70.24393660 W 148.49736100 1191 .73 0.50 47.00 1125:99 1191 .72 -2.23 3.90 2.41 -1.27 2.05 0.25 5941064.41 686027.63 N 70.24393782 W 148.49735713 1291 .73 0.50 26.00 1225.99 1291 .72 -1.97 4.76 2.63 -0.58 2.56 0.18 5941065.11 686028.13 N 70.24393970 W 148.49735301 1391 .73 0.75 41.00 1325.98 1391 .71 -1.62 5.85 3.20 0.31 3.18 0.30 5941066.01 686028.73 N 70.24394212 W 148.49734800 1491 .73 0.75 18.00 1425.97 1491 .70 -1.08 7.14 4.07 1.42 3.82 0.30 5941067.15 686029.33 N 70.24394517 W 148.49734290 1591 .73 0.50 17.00 1525.97 1591 .70 -0.43 8.23 4.82 2.46 4.15 0.25 5941068.19 686029.63 N 70.24394801 W 148.49734024 1691 .73 0.00 0.00 1625.96 1691 .69 -0.16 8.67 5.15 2.88 4.27 0.50 5941068.61 686029.75 N 70.24394915 W 148.49733921 1791 .73 0.00 0.00 1725.96 1791 .69 -0.16 8.67 5.15 2.88 4.27 0.00 5941068.61 686029.75 N 70:24394915 W 148.49733921 1891 .73 0.25 259.00 1825.96 1891 .69 -0.07 8.89 4.95 2.84 4.06 0.25 5941068.57 686029.54 N 70.24394904 W 148.49734094 1991 .73 0.75 239.00 1925.96 1991 .69 0.07 9.75 4.10 2.46 3.28 0.52 5941068.17 686028.77 N 70.24394801 W 148.49734720 2091 .73 0.50 200.00 2025.95 2091 .68 -0.12 10.80 3.09 1.71 2.57 0.48 5941067.40 686028.08 N 70.24394596 W 148.49735293 2191 .73 1.00 186.00 2125.95 2191 .68 -1.01 12.11 2.37 0.43 2.33 0.53 5941066.12 686027.87 N 70.24394247 W 148.49735487 SurveyEditor Ver SP 2.1 Bld( doc4Ox_1OO) 06-21\06-21\06-21 B\06-21 B Generated 8/28/2008 12:35 PM Page 1 of 5 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hde Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure R d de R R ft R ft R R de t00R RUS RUS ZZyl. /3 1.UU l`JU. uu [[[a. yo t~ai.oo -~. cu iaoa c. or -~.u c. w v.i~ ~a-.~vv.. -.~ ~~~.,~,.,.~ ~.,... ~.,.~.,...~ .. ~~., .~.. ,.... 2391 .73 0.75 170. 00 2325. 92 2391. 65 -3. 33 15.35 3. 33 -2. 76 1. 87 0.46 5941062. 92 686027.49 N 70. 24393376 W 148 .49735858 2491 .73 0.75 1.83. 00 2425. 91 2491. 64 -4. 43 16.65 4. 50 -4. 05 1. 95 0.17 5941061. 62 686027.60 N 70. 24393021 W 148 .49735794 2591 .73 1.00 192. 00 2525. 90 2591. 63 -5. 53 18.18 5. 83 -5. 56 1. 74 0.28 5941060. 11 686027.42 N 70. 24392609 W 148 .49735968 2691 .73 0.75 190. 00 2625. 89 2691. 62 -6. 57 19.70 7. 21 -7. 06 1. 44 0.25 5941058. 61 686027.17 N 70. 24392200 W 148 .49736206 2791 .73 0.75 200. 00 2725. 88 2791. 61 -7. 39 21.01 8. 39 -8. 32 1. 11 0.13 5941057. 34 686026.86 N 70. 24391856 W 148 .49736479 2891 .73 1.00 195. 00 2825. 87 2891. 60 -8. 31 22.53 9. 80 -9. 78 0. 66 0.26 5941055. 87 686026.45 N 70. 24391458 W 148 .49736842 2991 .73 1.25 205. 00 2925. 85 2991. 58 -9. 40 24.49 11. 61 -11. 61 -0. 03 0.32 5941054. 02 686025.81 N 70. 24390957 W 148 .49737396 3091 .73 1.00 182. 00 3025. 83 3091. 56 -10. 62 26.43 13. 48 -13. 47 -0. 52 0.51 5941052. 15 686025.36 N 70. 24390449 W 148 .49737793 3191 .73 1.00 186. 00 3125. 81 3191. 54 -11. 96 28.17 15. 22 -15. 21 -0. 64 0.07 5941050. 41 686025.28 N 70. 24389974 W 148 .49737892 3291 .73 1.00 195. 00 3225. 80 3291. 53 -13. 16 29.92 16. 95 -16. 92 -0. 96 0.16 5941048. 69 686025.01 N 70. 24389506 W 148 .49738148 3391 .73 1.00 160. 00 3325. 78 3391. 51 -14. 55 31.61 18. 60 -18. 58 -0. 89 0.60 5941047. 03 686025.12 N 70. 24389052 W 148 .49738089 • 3491 .73 0.75 170. 00 3425. 77 3491. 50 -15. 98 33.13 20. 05 -20. 05 -0. 48 0.29 5941045. 58 686025.57 N 70. 24388652 W 148 .49737756 3591 .73 0.75 170. 00 3525. 76 3591. 49 -17. 16 34.44 21. 34 -21. 34 -0. 25 0.00 5941044. 29 686025.83 N 70 .24388300 W 148 .49737573 3691 .73 0.75 166. 00 3625. 76 3691. 49 -18. 36 35.75 22. 62 -22. 62 0. 02 0.05 5941043. 02 686026.13 N 70 .24387950 W 148 .49737353 3791 .73 0.75 218. 00 3725. 75 3791. 48 -19. 15 36.97 23. 77 -23. 77 -0. 22 0.66 5941041. 87 686025.91 N 70 .24387636 W 148 .49737551 3891 .73 0.75 188. 00 3825. 74 3891. 47 -19 .80 38.25 24. 94 -24. 93 -0. 72 0.39 5941040. 69 686025.45 N 70 .24387318 W 148 .49737950 3991 .73 1.50 229. 00 3925. 72 3991. 45 -20 .39 40.14 26. 50 -26. 44 -1. 79 1.06 5941039. 16 686024.41 N 70 .24386906 W 148 .49738821 4091 .73 6.25 215. 00 4025. 47 4091. 20 -22 .30 46.87 32. 30 -31. 76 -5. 91 4.81 5941033. 74 686020.43 N 70 .24385453 W 148 .49742142 4191 .73 10.00 226. 00 4124. 45 4190. 18 -25 .33 60.96 44. 93 -42. 25 -15. 28 4.04 5941023. 02 686011.32 N 70 .24382586 W 148 .49749710 4291 .73 13.00 238. 00 4222. 44 4288. 17 -25 .83 80.83 62. 52 -54. 25 -31. 07 3.82 5941010. 63 685995.83 N 70 .24379308 W 148 .49762462 4391 .73 14.50 246. 00 4319. 59 4385. 32 -22 .52 104.56 83. 51 -65. 30 -52. 05 2.42 5940999. 07 685975.13 N 70 .24376289 W 148 .49779404 4491 .73 16.75 249. 00 4415. 88 4481. 61 -16 .28 131.48 107. 84 -75. 56 -76. 94 2.39 5940988. 20 685950.50 N 70 .24373486 W 148 .49799507 4591 .73 18.50 253. 00 4511. 19 4576. 92 -7 .48 161.75 135. 76 -85. 36 -105. 57 2.13 5940977. 69 685922.13 N 70 .24370808 W 148 .49822627 4691 .73 20.50 254. 00 4605. 45 4671 .18 3 .56 195.13 167. 09 -94. 83 -137. 58 2.03 5940967. 44 685890.37 N 70 .24368222 W 148 .49848476 4791 .73 22.25 255. 00 4698. 57 4764 .30 16 .22 231.57 201. 88 -104. 56 -172. 70 1.79 5940956 .85 685855.50 N 70 .24365564 W 148 .49876840 4891 .73 22.50 255. 00 4791. 04 4856 .77 29 .74 269.64 238. 68 -114. 41 -209. 47 0.25 5940946 .09 685818.98 N 70 .24362872 W 148 .49906534 4991 .73 22.00 256. 00 4883 .59 4949 .32 43 .49 307.50 275. 55 -123. 89 -246. 12 0.63 5940935 .71 685782.57 N 70 .24360281 W 148 .49936137 5091 .73 22.50 255. 00 4976 .15 5041 .88 57 .24 345.37 312. 66 -133. 38 -282. 78 0.63 5940925 .32 685746.17 N 70 .24357690 W 148 .49965740 5191 .73 22.50. 256. 00 5068 .54 5134 .27 71 .14 383.64 350. 32 -142. 96 -319. 83 0.38 5940914 .83 685709.37 N 70 .24355072 W 148 .49995660 5291 .73 22.50 256. 00 5160 .92 5226 .65 85 .35 421.90 388. 06 -152. 22 -356. 96 0.00 5940904 .66 685672.48 N 70 .24352542 W 148 .50025646 5391 :73 22.25 256 .00 5253 .40 5319 .13 99 .49 459.97 425. 69 -161. 43 -393. 90 0.25 5940894 .54 685635.78 N 70 .24350026 W 148 .50055474 5491 .73 22.50 256 .00 5345 .87 5411 .60 113 .62 498.04 463. 39 -170. 63 -430 .83 0.25 5940884 .43 685599.09 N 70 .24347509 W 148 .50085303 5591 .73 22.50 256 .00 5438 .25 5503 .98 127 .83 536.31 501. 35 -179. 89 -467 .96 0.00 5940874 .25 685562.20 N 70 .24344979 W 148 .50115289 5691 .73 22.50 255 .00 5530 .64 5596 .37 141 .73 574.57 539. 39 -189. 47 -505 .01 0.38 5940863 .76 685525.40 N 70 .24342361 W 148 .50145208 5791 .73 22.25 256 .00 5623 .11 5688 .84 155 .56 612.64 577. 25 -199. 01 -541 .86 0.46 5940853 .32 685488.80 N 70 .24339756 W 148 .50174969 5891 .73 .22.50 255 .00 5715 .59 5781 .32 169 .39 650.71 615. 14 -208 .54 -578 .72 0.46 5940842 .89 685452.19 N 70 .24337151 W 148 .50204729 5991 .73 22.25 255 .00 5808 .06 5873 .79 182 .90 688.77 653. 08 -218 .39 -615 .49 0.25 5940832 .13 685415.68 N 70 .24334459 W 148 .50234423 6091 .73 22.25 255 .00 5900 .61 5966 .34 196 .35 726.64 690. 84 -228 .19 -652 .06 0.00 5940821 .43 685379.36 N 70 .24331781 W 148 .50263959 6191 .73 22.00 255 .00 5993 .25 6058 .98 209 .72 764.30 728. 40 -237 .94 -688 .44 0.25 5940810 .79 685343.23 N 70 .24329117 W 148 .50293337 6291 .73 21.75 254 .00 6086 .05 6151 .78 222 .65 801.56 765. 59 -247 .89 -724 .34 0.45 5940799 .95 685307.59 N 70 .24326396 W 148 .50322330 6391.73 21.75 254.00 6178.93 6244.66 235.20 838.61 802.60 -258.11 -759.96 0.00 5940788.86 685272.24 N 70.24323605 W 148.50351096 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 06-21\06-21\06-21 B\06-21 B Generated 8/28/2008 12:35 PM Page 2 of 5 Comments Measured Inclination Azimuth Subsea ND ND Vertical Along Nde Gosure NS EW DLS Northing Easting Latitude Longitude Depth Seaion Departure ft d d R R ft ft R ft R d 100 R RUS RUS t)4y1./3 ZI:bU YD4.UU UL/I.tl`J bJJ/AL L4/.Oy 8/0.4/ 8Jy.41 -G08.L/ -/7a.Jy u.GO o~iur/I.OJ oooco/.vl Iv ~V.GYJCVOC.7 vv iwo.aw~ai VJ 6591.73 21.00 253.00 6365.09 6430.82 259.67 911.71 875.63 -278.56 -830.14 0.62 5940766.69 685202.59 N 70.24318017 W 148.50407766 6691.73 20.75 254.00 6458.53 6524.26 271.44 947.34 911.24 -288.68 -864.30 0.44 5940755.73 685168.69 N 70.24315250 W 148.50435355 6791.73 20.50 253.00 6552.12 6617.85 283.09 982.57 946.44 -298.68 -898.08 0.43 5940744.90 685135.17 N 70.24312517 W 148.50462629 6891.73 20.25 253.00 6645.86 6711.59 294,31 1017.38 981.25 -308.86 -931.37 0.25 5940733.90 685102.14 N 70.24309735 W 148.50489515 6991.73 19.50 253.00 6739.90 6805.63 305.26 1051.38 1015.24 -318.80 -963.88 0.75 5940723.16 685069.89 N 70.24307018 W 148.50515769 7091.73 19.00 252.00 6834.31 6900.04 315.62 1084.35 1048.20 -328.71 -995.33 0.60 5940712.48 685038.70 N 70.24304309 W 148.50541161 7191.73 18.25 252.00 6929.07 6994.80 325.38 1116.28 1080.14 -338.58 -1025.70 0.75. 5940701.86 685008.58 N 70.24301612 W 148.50565688 Tie-In Survey 7291.73 18.00 251.00 7024.11 7089.84 334.63 1147.39 1111.24 -348.45 -1055.20 0.40 5940691.27 684979.34 N 70.24298915 W 148.50589511 TOW 7293.00 18.00 251.00 7025.32 7091.05 334.75 1147.78 1111.64 -348.58 -1055.57 0.00 5940691.13 684978.97 N 70.24298880 W 148.50589811 BOW 7307.00 19.70 251.80 7038.57 7104.30 336.09 1152.31 1116.16 -350.02 -1059.86 12.28 5940689.59 684974.72 N 70.24298486 W 148.50593273 Inc+Trend 7346.81 16.97 253.22 7076.36 7142.09 340.01 1164.83 1128.68 -353.79 -1071.80 6.95 5940685.52 684962.88 N 70.24297455 W 148.50602914 7442.90 17.39 256.64 7168.16 7233.89 350.06 1193.20 1157.01 -361.16 -1099.20 1.14 5940677.48 684935.67 N 70.24295441 W 148.50625038 7533.36 18.10 259.88 7254.32 7320.05 361.31 1220.77 1184.39 -366.75 -1126.18 1.34 5940671.22 684908.83 N 70.24293912 W 148.50646831 7625.59 18.44 263.15 7341.90 7407.63 374.58 1249.67 1212.90 -371.01 -1154.77 1.17 5940666.26 684880.36 N 70.24292748 W 148.50669916 7722.56 20.12 266.60 7433.43 7499.16 390.94 1281.68 1244.14 -373.83 -1186.65 2.09 5940662.66 684848.56 N 70.24291976 W 148.50695660 MWD+IFR+MS 7820.36 20.59 270.24 7525.13 7590.86 410.07 1315.69 1276.87 -374.75 -1220.64 1.38 5940660.89 684814.61 N 70.24291722 W 148.50723109 7915.99 21.38 290.14 7614.53 7680.26 434.44 1349.64 1306.94 -368.67 -1253.86 7.46 5940666.15 684781.25 N 70.24293382 W 148.50749940 8012.66 22.88 305.36 7704.15 7769.88 466.85 1385.87 1333.00 -351.71 -1285.76 6.11 5940682.31 684748.94 N 70.24298013 W 148.50775701 8109.84 23.50 319.56 7793.55 7859.28 504.07 1423.97 1353.60 -326.01 -1313.76 5.78 5940707.31 684720.32 N 70.24305033 W 148.50798314 8204.63 25.02 323.36 7879.97 7945.70 542.96 1462.91 1370.23 -295.54 -1337.98 2.30 5940737.18 684695.35 N 70.24313356 W 148.50817881 8300.52 29.28 325.74 7965.28 8031.01 586.69 1506.65 1387.84 -259.87 -1363.29 4.58 5940772.21 684669.17 N 70.24323099 W 148.50838329 8394.94 32.99 332.42 8046.11 8111.84 635.25 1555.42 1405.22 -217.98 -1388.21 5.36 5940813.47 684643.23 N 70.24334543 W 148.50858457 8491.31 34.57 335.03 8126.21 8191.94 688.08 1608.99 1422.09 -169.93 -1411.90 2.23 5940860.91 684618.36 N 70.24347668 W 148.50877597 8586.83 33.62 334.07 8205.31 8271.04 740.75 1662.54 1440.05 -121.58 -1434.91 1.14 5940908.68 684594.17 N 70.24360876 W 148.50896182 8682.49 35.51 336.81 8284.09 8349.82 793.96 1716.80 1459.22 -72.22 -1457.43 2.56 5940957.47 684570.44 N 70.24374360 W 148.50914379 8777.90 36.15 334.60 8361.44 8427.17 848.68 1772.65 1480.57 -21.33 -1480.41 1.51 5941007.78 684546.21 N 70.24388263 W 148.50932948 8872.35 35.85 334.54 8437.85 8503.58 903.29 1828.16 1504.53 28.81 -1504.25 0.32 5941057.31 684521.14 N 70.24401958 W 148.50952209 8910.37 35.85 .335.11 8468.67 8534.40 925.17 1850.43 1514.52 48.96 -1513.72 0.88 5941077.22 684511.17 N 70.24407463 W 148.50959861 9020.17 39.62 337.14. 8555.49 8621.22 990.89 1917.61 1544.82 110.41 -1540.87 3.61 5941137.97 684482.52 N 70:24424250 W 148.50981793 9051.98 40.16 338.86 8579.90 8645.63 1010.70 1938.01 1553.90 129.33 -1548.51 3.86 5941156.69 684474.42 N 70.24429417 W 148.50987966 9083.98 39.96 337.46 8604.39 8670.12 1030.69 1958.60 1563.23 148.44 -1556.17 2.88 5941175.61 684466.29 N 70.24434638 W 148.50994156 .9115.95 42.88 337.88 8628.37 8694.10 1051.25 1979.75 1573.20 168.00 -1564.20 9.17 5941194.97 684457.78 N 70.24439983 W 148.51000647 9148.24 46.26 338.06 8651.37 8717.10 1073.26 2002.41 1584.02 189.01 -1572.70 10.47 5941215.76 684448.76 N 70.24445720 W 148.51007513 9180.30 48.19 337.90 8673.14 8738.87 1096.11 2025.94 1595.51 210.82 -1581.52 6.03. 5941237.35 684439.41 N 70.24451679 W 148.51014643 9211.73 52.41 338.38 8693.21 8758.94 1119.58 2050.12 1607.53 233.26 -1590.52 13.48 5941259.55 684429.86 N 70.24457809 W 148.51021915 9243.15 56.05 338.72 8711.57 8777.30 1144.27 2075.61 1620.35 256.99 -1599.84 11.62 5941283.04 684419.96 N 70.24464290 W 148.51029445 9274:72 56.96 337.22 8728.99 8794.72 1169.84 2101.93 1634.13 281.39 -1609.72 4.90 5941307.19 684409.48 N 70.24470956 W 148.51037426 9306.10 60.30 335.05 8745.33 8811.06 1196.05 2128.72 1649.18 305.88 -1620.56 12.17 5941331.41 684398.03 N 70.24477647 W 148.51046189 9337.00 62.30 333.87 8760.17 8825.90 1222.72 2155.82 1665.34 330.33 -1632.25 7.29 5941355.56 684385.75 N 70.24484326 W 148.51055632 9364.70 62.01 334.61 8773.11 8838.84 1246.84 2180.32 1680.26 352.39 -1642.89 2.58 5941377.35 684374.56 N 70.24490352 W 148.51064233 9400.27 65.60 331.62 8788.81 8854.54 1278.36 2212.23 1700.53 380.84 -1657.33 12.60 5941405.43 684359.43 N 70.24498124 W 148.51075900 9433.11. 67.65 332.18 8801.84 8867.57 1308.23 2242.37 1720.47 407.44 -1671.53 6.44 5941431.66 684344.58 N 70.24505387 W 148.51087371 • SurveyEditor Ver SP 2.1 Bld( doc40x_100) 06-21\06-21\06-21 B\06-21 B Generated 8/28/2008 12:35 PM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hde Closure NS EW DLS Northing EasOng Latitude Longitude ~~ Section Departure R de d R R R R R R R de 100 R RUS RUS `J~460.UZ bt3. 23`J 331. b3 i5t513. bb tf25/`J. 325 1.53/.bU ZZ/Z .UI "I/4U. 3/ 433. Di3 -lb8D. 4`J 4.LU ~`J414D/. 4b bC43G`J .`J6 N /U .L4~lLO3U VV -148. ~1U`J80~U .9497.18 71. 19 331. 69 8824. 63 8890. 36 1367.57 2302 .24 1761. 03 460. 19 -1699. 84 7.15 5941483. 70 684314 .98 N 70 .24519797 W 148. 51110243 9529.95 70. 79 332. 03 8835. 30 8901. 03 1398.28 2333 .22 1782. 42 487. 51 -1714. 45 1.57 5941510. 65 684299 .70 N 70 .24527260 W 148. 51122050 9561.65 70. 84 331. 62 8845. 72 8911. 45 1427.96 2363 .16 1803. 36 513. 90 -1728. 59 1.23 5941536. 68 684284 .91 N 70 .24534469 W 148. 51133472 9594.53 74. 17 331. 73 8855. 60 8921. 33 1459.04 2394 .52 1825. 62 541. 50 -1743. 46 10.13 5941563. 91 684269 .36 N 70 .24542009 W 148. 51145493 9626.71 76. 06 332. 55 8863. 87 8929. 60 1489.84 2425 .61 1847. 78 568. 99 -1758. 00 6.37 5941591. 03 684254 .16 N 70 .24549519 W 148. 51157235 9659.03 77. 52 332. 49 8871. 25 8936. 98 1520.98 2457 .08 1870. 32 596. 91 -1772. 51 4.52 5941618. 58 684238 .96 N 70 .24557144 W 148. 51168966 9692.00 81. 79 333. 22 8877. 17 8942. 90 1553.03 2489 .50 1893. 69 625. 76 -1787. 31 13.13 5941647. 06 684223 .46 N 70 .24565026 W 148. 51180919 9722.03 83. 76 334. 53 8880. 95 8946. 68 1582.40 2519 .29 1915. 02 652. 51 -1800. 42 7.86 5941673. 47 684209 .68 N 70 .24572332 W 148. 51191518 9755.27 86. 23 334. 53 8883. 85 8949. 58 1614.97 2552 .40 1938. 73 682. 40 -1814. 66 7.43 5941703. 00 684194 .71 N 70 .24580498 W 148. 51203024 9784.74. 86. 89 332. 46 8885. 62 8951. 35 1644.00 2581 .82 1960. 39 708. 73 -1827. 79 7.36 5941728. 99 684180 .94 N 70 .24587688 W 148. 51213632 9817.09 89. 18 331. 22 8886. 73 8952. 46 1676.04 2614 .15 1985. 03 737. 23 -1843. 05 8.05 5941757. 10 684164 .99 N 70 .24595474 W 148. 51225961 • 9848.76 89. 08 331. 20 8887. 21 8952. 94 1707.47 2645 .82 2009. 59 764. 98 -1858. 30 0.32 5941784. 47 684149 .06 N 70 .24603054 W 148. 51238284 9880.42 89. 18 331. 06 8887. 69 8953. 42 1738.90 2677 .47 2034. 38 792. 70 -1873. 58 0.54 5941811. 80 684133 .09 N 70 .24610627 W 148. 51250634 9912.81 89. 39 330. 82 8888. 09 8953. 82 1771.06 2709 .86 2059. 99 821. 01 -1889. 31 0.98 5941839. 71 684116 .67 N 70 .24618360 W 148. 51263346 9945.01 89. 29 328. 96 8888. 46 8954. 19 1803.10 2742 .06 2085. 99 848. 86 -1905. 47 5.78 5941867. 16 684099 .84 N 70 .24625968 W 148. 51276397 9990.53 89. 65 331. 23 8888. 89 8954. 62 1848.37 2787 .58 2122. 95 888. 32 -1928. 16 5.05 5941906. 04 684076 .18 N 70 .24636745 W 148. 51294734 10022.20 89. 62 329. 95 8889. 09 8954. 82 1879.85 2819 .25 2148. 69 915. 91 -1943. 71 4.04 5941933. 23 684059 .95 N 70 .24644281 W 148. 51307300 10053.80 89. 48 329. 46 8889. 34 8955. 07 1911.30 2850 .84 2174. 82 943. 19 -1959. 65 1.61 5941960. 11 684043 .34 N 70 .24651734 W 148. 51320180 10085.70 89. 58 330. 07 8889. 60 8955. 33 1943.05 2882 .74 2201. 32 970. 75 -1975. 71 1.94 5941987. 27 684026 .61 N 70 .24659262 W 148. 51333160 10117.88 89. 62 331. 55 8889. 82 8955. 55 1975.01 2914 .92 2227. 86 998. 84 -1991. 41 4.60 5942014. 96 684010 .23 N 70 .24666935 W 148. 51345842 10150.05 89. 38 330. 43 8890. 10 8955. 83 2006.95 2947 .09 2254. 49 1026. 97 -2007. 01 3.56 5942042. 70 683993 .94 N 70 .24674619 W 148. 51358448 10182.01 89. 20 330. 13 8890. 50 8956. 23 2038.73 2979 .05 2281. 31 1054. 73 -2022. 85 1.09 5942070. 05 683977 .41 N 70 .24682200 W 148. 51371251 10213.75 89. 31 331. 81 8890. 91 8956. 64 2070.25 3010 .79 2307. 86 1082. 48 -2038. 25 5.30 5942097. 41 683961 .34 N 70 .24689780 W 148. 51383696 10245.98 89. 24 331. 93 8891. 32 8957. 05 2102.19 3043 .01 2334. 68 1110. 90 -2053. 44 0.43 5942125. 44 683945 .44 N 70 .24697543 W 148. 51395975 10277.36 89. 20 331. 75 8891. 75 8957. 48 2133.29 3074 .39 2360. 93 1138. 56 -2068. 25 0.59 5942152. 73 683929 .96 N 70 .24705100 W 148. 51407942 10309.21 89. 27 332. 21 8892. 17 8957. 90 2164.84 3106 .24 2387. 66 1166. 67 -2083. 21 1.46 5942180 .46 683914 .31 N 70 .24712779 W 148. 51420033 10341.57 89. 14 331. 89 8892. 62 8958. 35 2196.89 3138 .60 2414. 92 1195. 26 -2098. 38 1.07 5942208 .66 683898 .44 N 70 .24720587 W 148. 51432289 10373.07 89. 03 330. 91 8893. 12 8958. 85 2228.14 3170 .09 2441. 76 1222. 91 -2113. 46 3.13 5942235 .93 683882 .69 N 70 .24728140 W 148. 51444473 10405.33 89. 03 332. 29 8893. 67 8959. 40 2260.13 3202 .35 2469. 31 1251. 28 -2128. 80 4.28 5942263 .92 683866 .66 N 70 .24735890 W 148. 51456871 10437.13 88. 72 331. 65 8894. 29 8960 .02 2291.63 3234 .14 2496. 46 1279. 35 -2143. 74 2.24 5942291 .60 683851 .03 N 70 .24743556 W 148. 51468945 • 10468.31 88. 55 330. 73 8895. 04 8960 .77 2322.57 3265 .31 2523. 41 1306. 66 -2158. 76 3.00 5942318 .53 683835 .34 N 70 .24751016 W 148. 51481085 10500.36 88. 62 330. 97 8895. 83 8961 .56 2354.39 3297 .35 2551. 30 1334: 64 -2174. 37 0.78 5942346 .12 683819 .05 N 70 .24758660 W 148. 51493698 10532.47 88. 55 331. 18 8896. 62 8962 .35 2386.26 3329 .45 2579. 28 1362. 74 -2189. 89 0.69 5942373 .82 683802 .83 N 70 .24766334 W 148. 51506245 10564.32 88. 48 330. 62 8897. 45 8963 .18 2417.88 3361 .29 2607. 17 1390. 56 -2205. 38 1.77 5942401 .25 683786 .67 N 70 .24773933 W 148. 51518759 10596.68 88. 48 331. 26 8898 .31 8964 .04. 2450.01 3393 .64 2635. 59 1418. 83 -2221. 09 1.98 5942429 .13 683770 .26 N 70 .24781657 W 148. 51531458 10628.40 89. 44 330. 78 8898 .88 8964 .61 2481.50 3425 .35 2663. 52 1446. 58 -2236. 45 3.38 5942456 .48 683754 .22 N 70 .24789235 W 148. 51543876 10659.81 89. 65 328. 57 8899 .13 8964 .86 2512.76 3456 .76 2691. 59 1473. 69 -2252. 31 7.07 5942483 .19 683737 .70 N 70 .24796640 W 148. 51556691 10692.21 90. 20 329. 54 8899 .17 8964 .90 2545.04 3489 .16 2720. 78 1501. 47 -2268. 97 3.44 5942510 .56 683720 .36 N 70 .24804230 W 148. 51570156 10723.24 89. 57 328. 70 8899 .23 8964 :96 2575.96 3520 .19 2748. 79 1528. 11 -2284. 90 3.38 5942536 .79 683703 .78 N 70 .24811504 W 148. 51583027 10754.13 91. 06 325. 83 8899 .07 8964 .80 2606.80 3551 .08 2777. 15 1554. 09 -2301. 60 10.47 5942562 .34 683686 .44 N 70 .24818600 W 148. 51596524 10786.46 93.22 325.38 8897.86 8963.59 2639.10 3583.39 2807.21 1580.74 -2319.85 6.82 5942588.54 683667.54 N 70.24825881 W 148.51611271 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 06-21\06-21\06-21 B\06-21 B Generated 8/28/2008 12:35 PM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hde Closure NS EW DLS Northing Fasting Latitude Longitude Depth Section Departure ft de d ft ft ft ft ft ft ft de 100 ft ftUS A~IC.I A '1~ ftUS C07GA0 ~C AI ~l\ 7A0~]7/10A \A/ A AO GAC7G(1']C l UiSlif.Jtl `J3.80 Jto.ia 08yO. oy oao i.oA: ~oru.ya ov lo.co cow.ao Iovo. ao -caa~. a~ c.iv o~-.wl-. .~, - 10850.81 97.34 325.24 8892. 72 8958.45 2703.21 3647.52 2867.18 1633. 43 -2356. 41 10.73 5942640 .31 683629.70 N 70 .24840272 W 148. 51640815 10883.03 97.42 325.49 8888. 58 8954.31 2735.16 3679.47 2897.11 1659. 72 -2374. 57 0.81 5942666 .14 683610.90 N 70 .24847453 W 148. 51655491 10914.71 97.97 325.01 8884. 34 8950.07 2766.55 3710.86 2926.57 1685. 52 -2392. 46 2.30 5942691 .49 683592.37 N 70 .24854499 W 148. 51669953 10946.45 98.56 323.21 8879. 78 8945.51 2797.96 3742.27 2956.30 1710. 96 -2410. 87 5.91 5942716 .47 683573.34 N 70 .24861449 W 148. 51684833 10979.10 99.12 322.17 8874. 76 8940.49 2830.21 3774.54 2987.11 1736. 62 -2430. 43 3.58 5942741 .64 683553.16 N 70 .24868457 W 148. 51700635 11010.18 99.11 322.30 8869. 84 8935.57 2860.88 3805.22 3016.52 1760. 88 -2449. 22 0.41 5942765 .42 683533.77 N 70 .24875083 W 148. 51715823 11041.64 98.88 320.90 8864. 92 8930.65 2891.92 3836.30 3046.42 1785. 23 -2468. 52 4.46 5942789 .29 683513.88 N 70 .24881734 W 148. 51731420 11073.50 98.91 320.39 8859. 99 8925.72 2923.34 3867.77 3076.86 1809. 57 -2488. 48 1.58 5942813 .13 683493.32 N 70 .24888382 W 148. 51747550 11105.68 98.88 320.76 8855. 02 8920.75 2955.06 3899.57 3107.65 1834. 13 -2508. 67 1.14 5942837 .18 683472.53 N 70 .24895089 W 148. 51763866 11137.04 98.29 320.15 8850 .34 8916.07 2986.01 3930.58 3137.71 1858. 04 -2528. 42 2.69 5942860 .59 683452.21 N 70 .24901620 W 148. 51779821 11169.30 95.94 318.21 8846. 34 8912.07 3017.89 3962.58 3168.92 1882. 26 -2549. 34 9.42 5942884 .29 683430.69 N 70 .24908235 W 148. 51796730 11200.33 93.73 316.42 8843 .72 8909.45 3048.59 3993.50 3199.29 1904. 99 -2570. 30 9.15 5942906 .49 683409.18 N 70 .24914442 W 148. 51813669 11232.64 91.33 316.38 8842 .30 8908.03 3080.56 4025.78 3231.09 1928. 36 -2592. 56 7.43 5942929 .30 683386.35 N 70 .24920825 W 148. 51831655 11264.33 89.29 314.86 8842 .13 8907.86 3111.89 4057.47 3262.39 1951. 01 -2614. 72 8.03 5942951 .40 683363.64 N 70 .24927010 W 148. 51849565 11297.09 89.62 316.14 8842 .44 8908.17 3144.28 4090.22 3294.77 1974. 37 -2637. 68 4.03 5942974 .18 683340.11 N 70 .24933391 W 148. 51868118 11328.71 89.62 316.52 8842 .65 8908.38 3175.60 4121.84 3325.96 1997. 25 -2659. 51 1.20 5942996 .51 683317.72 N 70 .24939637 W 148. 51885762 11361.09 89.24 316.48 8842 .97 8908.70 3207.68 4154.22 3357.89 2020. 73 -2681. 80 1.18 5943019 .44 683294.86 N 70 .24946051 W 148. 51903773 11390.42 89.24 316.42 8843 .36 8909.09 3236.74 4183.55 3386.82 2041. 99 -2702. 01 0.20 5943040 .19 683274.14 N 70 .24951856 W 148. 51920102 11424.43 88.59 317.29 8844 .00 8909.73 3270.47 4217.55 3420.34 2066. 80 -2725. 26 3.19 5943064 .41 683250.28 N 70 .24958632 W 148. 51938894 11456.56 87.76 316.69 8845 .03 8910.76 3302.33 4249.67 3451.98 2090. 28 -2747. 17 3.19 5943087 .35 683227.81 N 70 .24965045 W 148. 51956596 11488.19 87.63 316.77 8846 .30 8912.03 3333.66 4281.27 3483.16 2113. 29 -2768. 83 0.48 5943109 .82 683205.58 N 70 .24971330 W 148. 51974103 11519.78 87.46 316.62 8847 .65 8913.38. 3364.95 4312.83 3514.31 2136. 26 -2790. 48 0.72 5943132 .24 683183.38 N 70 .24977602 W 148. 51991597 11552.21 87.39 317.15 8849 .11 8914.84 3397.09 4345.23 3546.27 2159. 91 -2812. 62 1.65 5943155 .33 683160.66 N 70 .24984060 W 148. 52009491 11584.39 86.94 316.24 8850 .70 8916.43 3428.95 4377.37 3578.00 2183. 30 -2834 .66 3.15 5943178 .17 683138.05 N 70 .24990448 W 148. 52027306 11615.70 86.84 316.28 8852 .40 8918.13 3459.92 4408.63 3608.91 2205. 89 -2856 .28 0.34 5943200 .22 683115.88 N 70 .24996616 W 148. 52044775 11646.56 86.97 317.19 8854 .07 8919.80 3490.47 4439.45 3639.35 2228. 32 -2877 .40 2.97 5943222 .13 683094.22 N 70 .25002744 W 148. 52061843 Last Survey 11680.15 88.04 317.14 8855 .53 8921.26 3523.77 4473.01 3672.46 2252 .93 -2900 .21 3.19 5943246 .16 683070.80 N 70 .25009465 W 148. 52080282 TD (Projected) 11735.00 88.04 317.14 8857 .40 8923.13 3578.18 4527.82 3726.57 2293 .12 -2937 .50 0.00 5943285 .41 683032.54 N 70 .25020439 W 148. 52110417 Survey Type: Definitive Survey NOTES: CB GYRO MS- (Camera-based gyro multishot -- Traditional optically referenced gyro surveys run on wireline -including "level rotor" gyros and Sperry-Sun SU3. Replaces ex-BP "PGMS" model. ) INC+TREND - (Inclinometer + known azi trend -Inclination only surveys in near-vertical hole-where formation dip and experience enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. ) MWD + IFR+ MS - (In-field referenced MWD with multstation analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing IY I fftUSl Eastina IXl I ftUSI Surface : 466 FSL 959 FEL S2 T10N R14E UM 5941065.63 686025.55 BHL : 2758 FSL 3895 FEL S2 T10N R14E UM 5943285.41 683032.54 SurveyEditor Ver SP 2.1 Bld( doc40x_100) 06-21\06-21\06-21 B\06-21 B Generated 8/28/2008 12:35 PM Page 5 of 5 'ELLHEAD= FMC CTUATOR= AXELSON ' DRLG DRAFT 6 X21 B B. ELEV = 74 F.ELEV = OP = 4200' ax Angle = 64 @ 9279' alum MD = 9168' alum TV D = 8800' SS -3/8" CSG, 72#, L-80, ID = 12.347" liner top / BOT Liner Hanger dly Cemented w ith 15.8 ppg Cement and 11.5 ppg CREPE 2510' 3031' 1 9-5/8" Smith Whipstock 1 9-518" QSV F- Tubing Jet C ut ; 790' Estimated Tap of 15.8 ppg Cement ~' 4-tt2" Cement Retainer 9-5/8" CSG, 47#, L-80, ID = 8.681" 15.8 ppg Latex Cement 14.5", 12.66, 13-CR VAM TOP, 78G. 1 8676' H 4.5" HES X Landing Nipple ID=3.81: 8736' 41/2"x7" BOT S-3 Packer 8770' 4.5" HES X Landing Nipple ID=3.81 gg01 • 4.5" HES XN Land'mg hippie ID=3. 8807' 4.5" Top of Lamer (BOT HMC2XP) 8970' 7", 26#, L-80, BTC-M, Liner 11733' I-la.s",12.s#,13cx-so? PERFORATION SUMMARY REF LOG: ???? ANGLE AT TOP PERF: 990 @ 11080' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 2-718" 6 6 11080 - 11100 11540 - 11640 O O 07/31/OS 07!31 /08 = s.tsa" 9420' ~2-3/8" LNR, 4.6#, L-80 SAFET ES; ***4-112" CHROMETBG*** 141 /2" HES X LA NDING Nff', ID = 3.813" 1 GA S LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 5 3652 3652 0 KBG2 DOME BK 16 08/08/08 4 5668 5574 0 KBG2 SO BK 20 08/08!08 3 6894 6714 20 KBG2 DMY BK 0 07/30/08 2 7797 7569 20 KBG2 DMY BK 0 07/30/08 1 8640 8315 35 KBG2 DMY BK 0 07f30l08 7" MILLO UT W INDOW (06-21A) 9000' - 9005' ~ 9192'CTM MILL OUT OBSTRUCTION, ID = 1.75" AT TOP OF PERFs (04/10/07) PBTD 9466' = 1.941" I-i 950 L~ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/15/82 ORIGINAL COMPLETION 08/02/08 N7 ES SIDETRACK(06-21 B) WELL: 06-21A 07(16100 CTD SIDETRACK 08/09/08 /TLH CORRECTIONS & GLV C/O PERMfT No: 2000800 10!21/01 CH/KAK CORRECTIONS API No: 50-029-20802-01 03/02/05 JLG/TLH ADPERF SEC 2, T10N, R14E 4812' FNL & 958' FEL 04/10/07 DMS/PAG MILLED OUT OBSTRUCTION } SCHLUMBERGER Survey report Client .................... BP Exploration Alaska Field ..................... Prudhoe Bay Well ...................... 06-21B API number ................ 50-029-20802-02 Engineer .................. JHudon COUNTY :................... NSB STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS............ Mason & Taylor ----- Depth reference ---- Permanent datum........... Depth reference........... GL above permanent.......: KB above permanent.......: DF above permanent.......: -------------- Mean Sea LeVEL Drillers Depth 37.0 ft -50000.00 ft 65.73 ft ----- Vertical section origin---------------- Latitude (':_).......... 0.00 ft Departure ('_~)....... 0.00 ft ----- Platform reference point--------------- Latitude (:_).......... -999.25 ft Departure (~`)......... -999.25 ft Azimuth from Vsect Origin to target: 324.20 degrees ov 1 g ..g [(c)2008 IDEAL ID13 OC 08] 30-Jul-2008 09:32:01 Page 1 of 7 Spud date ................. 30-Jun-08 Last survey date.......... 30-Jul-08 Total accepted surveys...: 180 MD of first survey.......: 0.00 ft MD of last survey........: 11735.00 ft ----- Geomagnetic data --- Magnetic model............ Magnetic date ............. Magnetic field strength..: Magnetic dec (-).....: 23. Magnetic dip .............. ------------------ BGGM version 2007 17-Jul-08 57680.05 LAMA 21 degrees 80.91 degrees ----- MWD survey Reference Criteria --------- Reference G ............... 1002.67 meal Reference H ............... 57680.0 GAMA Reference Dip ............. 80.90 degrees Tolerance of G............ () 2.50 meal Tolerance of H............ () 300.00 LAMA Tolerance of Dip.........: () 0.45 degrees ----- Corrections --------------------------- Magnetic dec (CC).....: 23.19 degrees Grid convergence (~).: .0.00 degrees Total az corr (~')....: 23.19 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 30-Jul-2008 09:32:01 Page 2 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS S rvy Tool # depth angle angle length depth section ~ J displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) t ype (de g) --- 1 -------- 0.00 ------ 0.00 ------- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP_ UNK NOWN- Depth Only 2 28.73 0.00 0.00 28.73 28.73 0.00 0.00 0.00 0.00 0.00 0.00 BP_ UNK NOWN- Depth Only 3 91.73 0.00 180.00 63.00 91.73 0.00 0.00 0.00 0.00 0.00 0.00 BP_ CB GYRO MS 4 191.73 0.25 156.00 100.00 191.73 -0.21 -0.20 0.09 0.22 156.00 0.25 BP_ CB GYRO MS 5 291.73 0.25 165.00 100.00 291.73 -0.63 -0.61 0.23 0.65 159.00 0.04 BP_ CB GYRO MS 6 391.73 0.50 163.00 100.00 391.73 -1.25 -1.24 0.42 1.31 161.34 0.25 BP_ CB GYRO MS 7 491.73 0.25 167.00 100.00 491.72 -1.86 -1.87 0.59 1.96 162.34 0.25 BP_ CB GYRO MS 8 591.73 0.00 180.00 100.00 591.72 -2.06 -2.08 0.64 2.18 162.80 0.25 BP_ CB GYRO • MS 9 691.73 0.00 180.00 100.00 691.72 -2.06 -2.08 0.64 2.18 162.80 0.00 BP_ CB GYRO MS 10 791.73 0.00 180.00 100.00 791.72 -2.06 -2.08 0.64 2.18 162.80 0.00 BP_ CB GYRO MS 11 891.73 0.25 98.00 100.00 891.72 -2.21 -2.11 0.86 2.28 157.83 0.25 BP_ CB GYRO MS 12 991.73 0.25 51.00 100.00 991.72 -2.35 -2.00 1.25 2.36 148.13 0.20 BP_ CB GYRO MS 13 1091.73 0.25 47.00 100.00 1091.72 -2.31 -1.72 1.57 2.33 137.48 0.02 BP_ CB GYRO MS 14 1191.73 0.50 47.00 100.00 1191.72 -2.23 -1.27 2.05 2.41 121.75 0.25 BP_ CB GYRO MS 15 1291.73 0.50 26.00 100.00 1291.72 -1.97 -0.58 2.56 2.63 102.77 0.18 BP_ CB GYRO MS 16 1391.73 0.75 41.00 100.00 1391.71 -1.62 0.31 3.18 3.20 84.53 0.30 BP_ CB GYRO MS 17 1491.73 0.75 18.00 100.00 1491.70 -1.08 1.42 3.82 4.07 69.57 0.30 BP_ CB GYRO MS 18 1591.73 0.50 17.00 100.00 1591.69 -0.43 2.46 4.15 4.82 59.30 0.25 BP_ CB GYRO MS 19 1691.73 0.00 0.00 100.00 1691.69 -0.16 2.88 4.27 5.15 56.03 0.50 BP_ CB GYRO MS 20 1791.73 0.00 0.00 100.00 1791.69 -0.16 2.88 4.27 5.15 56.03 0.00 BP_ CB GYRO MS 21 1891.73 0.25 259.00 100.00 1891.69 -0.07 2.84 4.06 4.95 55.05 0.25 BP_ CB GYRO MS 22 1991.73 0.75 239.00 100.00 1991.69 0.07 2.46 3.28 4.10 53.18 0.52 BP_ CB GYRO MS • 23 2091.73 0.50 200.00 100.00 2091.68 -0.12 1.71 2.57 3.09 56.38 0.48 BP_ CB GYRO MS 24 2191.73 1.00 186.00 100.00 2191.67 -1.01 0.43 2.33 2.37 79.48 0.53 BP_ CB GYRO MS 25 2291.73 1.00 196.00 100.00 2291.66 -2.20 -1.27 2.00 2.37 122.47 0.17 BP_ CB GYRO MS 26 2391.73 0.75 170.00 100.00 2391.65 -3.33 -2.76 1..87 3.33 145.79 0.46 BP CB GYRO MS 27 2491.73 0.75 183.00 100.00 2491.64 -4.43 -4.05 1.95 4.50 154.27 0.17 _ BP_ CB GYRO MS 28 2591.73 1.00 192.-00 100.00 2591.63 -5.53 -5.56 1.74 5.83 162.65 0.28 BP_ CB GYRO MS 29 2691.73 0.75 190.00 100.00 2691.62 -6.57 -7.06 1.44 7.21 168.45 0.25 BP_ CB GYRO MS 30 2791.73 0.75 200.00 100.00 2791.61 -7.39 -8.32 1.11 8.39 172.43 0.13 BP_ CB GYRO MS [(c)2008 IDEAL ID13 OC 08] SCHLUMBERGER Survey Report 30-Jul-2008 09:32:01 Page 3 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section C ~ displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (de g) 31 2891.73 1.00 195.00 100.00 2891.60 -8.31 -9.78 0.66 9.80 176.16 0.26 BP_ CB GYRO MS 32 2991.73 1.25 205.00 100.00 2991.58 -9.40 -11.61 -0.03 11.61 180.15 0.32 BP_ CB GYRO MS 33 3091.73 1.00 182.00 100.00 3091.56 -10.62 -13.47 -0.52 13.48 182.22 0.51 BP_ CB GYRO MS 34 3191.73 1.00 186.00 100.00 3191.54 -11.96 -15.21 -0.64 15.22 182.42 0.07 BP_ CB GYRO MS 35 3291.73 1.00 195.00 100.00 3291.53 -13.16 -16.92 -0.96 16.95 183.25 0.16 BP CB GYRO MS 36 3391.73 1.00 160.00 100.00 3391.51 -14.55 -18.58 -0.89 18.60 182.74 0.60 BP_ CB GYRO MS 37 3491.73 0.75 170.00 100.00 3491.50 -15.98 -20.05 -0.48 20.05 181.36 0.29 BP_ CB GYRO MS 38 3591.73 0.75 170.00 100.00 3591.49 -17.16 -21.34 -0.25 21.34 180.67 0.00 BP_ CB GYRO MS 39 3691.73 0.75 166.00 100.00 3691.48 -18.36 -22.62 0.02 22.62 179.94 0.05 BP_ CB GYRO MS 40 3791.73 0.75 218.00 100.00 3791.48 -19.15 -23.77 -0.22 23.77 180.53 0.66 BP CB GYRO MS 41 3891.73 0.75 188.00 100.00 3891.47 -19.80 -24.93 -0.72 24.94 181.64 0.39 BP_ CB GYRO MS 42 3991.73 1.50 229.00 100.00 3991.45 -20.39 -26.44 -1.79 26.50 183.88 1.06 BP_ CB GYRO MS 43 4091.73 6.25 215.00 100.00 4091.19 -22.30 -31.76 -5.91 32.30 190.54 4.81 BP_ CB GYRO MS 44 4191.73 10.00 226.00 100.00 4190.18 -25.33 -42.25 -15.28 44.93 199.88 4.04 BP_ CB GYRO MS 45 4291.73 13.00 238.00 100.00 4288.17 -25.83 -54.25 -31.07 62.52 209.80 3.82 BP CB GYRO MS 46 4391.73 14.50 246.00 100.00 4385.31 -22.52 -65.30 -52.05 83.51 218.55 2.42 BP_ CB GYRO MS 47 4491.73 16.75 249.00 100.00 4481.61 -16.28 -75.56 -76.94 107.84 225.52 2.39 BP_ CB GYRO MS 48 4591.73 18.50 253.00 100.00 4576.92 -7.48 -85.36 -105.57 135.76 231.04 2.13 BP_ CB GYRO MS 49 4691.73 20.50 254.00 100.00 4671.18 3.56 -94.83 -137.58 167.09 235.42 2.03 BP_ CB GYRO MS 50 4791.73 22.25 255.00 100.00 4764.30 16.22 -104.56 -172.70 201.88 238.81 1.79 BP CB GYRO MS 51 4891.73 22.50 255.00 100.00 4856.77 29.74 -114.41 -209.47 238.68 241.36 0.25 BP_ CB GYRO MS 52 4991.73 22.00 256.00 100.00 4949.32 43.49 -123.89 -246.12 275.55 243.28 0.63 BP_ CB GYRO MS 53 5091.73 22.50 255.00 100.00 5041.88 57.24 -133.38 -282.78 312.66 244.75 0.63 BP_ CB GYRO MS 54 5191.73 22.50 256.00 100.00 5134.26 71.14 -142.96 -319.83 350.32 245.92 0.38 BP_ CB GYRO MS 55 5291.73 22.50 256.00 100.00 5226.65 85.35 -152.22 -356.96 388.06 246.91 0.00 BP CB GYRO MS 56 5391.73 22.25 256.00 100.00 5319.12 99.49 -161.43 -393.90 425.69 247.72 0.25 BP_ CB GYRO MS 57 5491.73 22.50 256.00 100.00 5411.60 113.62 -170.63 -430.83 463.39 248.39 0.25 BP_ CB GYRO MS 58 5591.73 22.50 256.00 100.00 5503.98 127.83 -179.89 -467.96 501.35 248.97 0.00 BP_ CB GYRO MS 59 5691.73 22.50 255.00 100.00 5596.37 141.73 -189.47 -505.01 539.39 249.43 0.38 BP_ CB GYRO MS 60 5791.73 22.25 256.00 100.00 5688.84 155.56 -199.01 -541.86 577.25 249.83 0.46 BP CB GYRO MS • • [(c)2008 IDEAL ID13 OC 08] SCHLUMBERGER Survey Report 30 -Jul-2008 09:32:01 Page 4 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section r C displ Azim (deg/ tool Cor r - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5891.73 22.50 255.00 100.00 5781.31 169.39 -208.54 -578.72 615.14 250.18 0.46 BP _CB GYRO MS 62 5991.73 22.25 255.00 100.00 5873.79 182.90 -218.39 -615.49 653.08 250.46 .0.25 BP _CB GYRO MS 63 6091.73 22.25 255.00 100.00 5966.34 196.35 -228.19 -652.06 690.84 250.71 0.00 BP _CB GYRO MS 64 6191.73 22.00 255.00 100.00 6058.98 209.72 -237.94 -688.44 728.40 250.93 0.25 BP _CB GYRO MS 65 6291.73 21.75 254.00 100.00 6151.78 222.65 -247.89 -724.34 765.59 251.11 0.45 BP CB GYRO MS 66 6391.73 21.75 254.00 100.00 6244.66 235.20 -258.11 -759.96 802.60 251.24 0.00 BP _CB GYRO MS 67 68 6491.73 6591.73 21.50 21.00 254.00 253.00 100.00 100.00 6337.62 6430.82 247.69 259.67 -268.27 -278.56 -795.39 -830.14 839.41 875.63 251.36 251.45 0.25 0.62 BP BP _CB GYRO _CB GYRO MS MS . 69 6691.73 20.75 254.00 100.00 6524.26 271.44 -288.68 -864.30 911.24 251.53 0.44 BP _CB GYRO MS 70 6791.73 20.50 253.00 100.00 6617.85 283.09 -298.68 -898.08 946.44 251.60 0.43 BP CB GYRO MS 71 6891.73 20.25 253.00 100.00 6711.59 294.31 -308.86 -931.37 981.25 251.65 0.25 BP _CB GYRO MS 72 6991.73 19.50 253.00 100.00 6805.63 305.26 -318.80 -963.88 1015.24 251.70 0.75 BP _CB GYRO MS 73 7091.73 19.00 252.00 100.00 6900.04 315.62 -328.71 -995.33 1048.20 251.72 0.60 BP _CB GYRO MS 74 7191.73 18.25 252.00 100.00 6994.80 325.38 -338.58 -1025.70 1080.14 251.73 0.75 BP _CB GYRO MS 75 7291.73 18.00 251.00 100.00 7089.84 334.64 -348.45 -1055.20 1111.24 251.73 0.40 BP CB GYRO MS 76 7293.00 18.00 251.00 1.27 7091.05 334.75 -348.58 -1055.57 1111.64 251.73 0.00 BP _CB GYRO MS 77 7307.00 19.70 251.80 14.00 7104.30 336.09 -350.02 -1059.86 1116.16 251.72 12.28 BP _BLIND 78 7346.81 16.97 253.22 39.81 7142.08 340.01 -353.79 -1071.80 1128.68 251.73 6.95 BP _INC- 79 7442.90 17.39 256.64 96.09 7233.89 350.06 -361.16 -1099.20 1157.01 251.81 1.14 BP INC'- 80 7533.36 18.10 259.88 90.46 7320.05 361.31 -366.75 -1126.18 1184.39 251.96 1.34 BP INC_ 81 7625.59 18.44 263.15 92.23 7407.63 374.58 -371.01 -1154.77 1212.91 252.19 1.17 BP INC= 82 7722.56 20.12 266.60 96.97 7499.16 390.94 -373.83 -1186.65 1244.14 252.51 2.09 BP _ INCJ • 83 7820.36 20.59 270.24 97.80 7590.86 410.08 -374.75 -1220.64 1276.87 252.93 1.38 BP _MWD-- 84 7915.99 21.38 290.14 95.63 7680.26 434.44 -368.67 -1253.86 1306.94 253.62 7.46 BP MWD.=_ 85 8012.66 22.88 305.36 96.67 7769.88 466.85 -351.71 -1285.76 1333.00 254.70 6.11 BP MWD=:= 86 8109.84 23.50 319.56 97.18 7859.28 504.07 -326.01 -1313.76 1353.60 256.06 5.78 BP _MWD-- 87 8204.63 25.02 323.36 94.79 7945.70 542.96 -295.54 -1337.98 1370.23 257.54 2.30 BP _MWD=- 88 8300.52 29.28 325.74 95.89 8031.01 586.70 -259.87 -1363.29 1387.84 259.21 4.58 BP _MWD:='_ 89 8394.94 32.99 332.42 94.42 8111.84 635.25 -217.98 -1388.21 1405.22 261.08 5.36 BP _MWD'-_ 90 8491.31 34.57 335.03 96.37 8191.94 688.08 -169.93 -1411.90 1422.09 263.14 2.23 BP MWD-'` [(c)2008 IDEAL ID13 OC 08] SCHLUMBERGER Survey Report 30-Jul-2008 09:32:01 Page 5 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section ~ r displ Azim (deg/ tool Cor r - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8586.83 33.62 334.07 95.52 8271.04 740.75 -121.58 -1434.91 1440.05 265.16 1.14 BP MWD-= 92 8682.49 35.51 336.81 95.66 8349.81 793.96 -72.22 -1457.43 1459.22 267.16 2.56 BP _ MWD'-^ 93 8777.90 36.15 334.60 95.41 8427.17 848.68 -21.33 -1480.41 1480.57 269.17 1.51 BP MWD~- 94 8872.35 35.85 334.54 94.45 8503.58 903.29 28.81 -1504.25 1504.53 271.10 0.32 BP MWD'~` 95 8910.37 35.85 335.11 38.02 8534.40 925.18 48.96 -1513.72 1514.52 271.85 0.88 BP MWD'-_' 96 9020.17 39.62 337.14 109.80 8621.22 990.89 110.41 -1540.87 1544.82 274.10 3.61 BP MWD~^~ 97 9051.98 40.16 338.86 31.81 8645.63 1010.70 129.33 -1548.51 1553.90 274.77 3.86 BP _ MWD~~ 98 9083.98 39.96 337.46 32.00 8670.12 1030.69 148.44 -1556.17 1563.23 275.45 2.88 BP MWD'~~-- • 99 9115.95 42.88 337.88 31.97 8694.09 1051.25 168.00 -1564.20 1573.20 276.13 9.17 BP _ MWD!`_ 100 9148.24 46.26 338.06 32.29 8717.09 1073.26 189.01 -1572.70 1584.02 276.85 10.47 BP MWD-'~ 101 9180.30 48.19 337.90 32.06 8738.87 1096.11 210.82 -1581.52 1595.51 277.59 6.03 BP MWD'~- 102 9211.73 52.41 338.38 31.43 8758.94 1119.58 233.26 -1590.52 1607.54 278.34 13.48 BP MWDC- 103 9243.15 56.05 338.72 31.42 8777.30 1144.27 256.99 -1599.84 1620.35 279.13 11.62 BP MWDC- 104 9274.72 56.96 33.7.22 31.57 8794.72 1169.84 281.39 -1609.72 1634.13 279.92 4.90 BP _ MWD-- 105 9306.10 60.30 335.05 31.38 8811.06 1196.05 305.88 -1620.56 1649.18 280.69 12.17 BP MWD= 106 9337.00 62.30 333.87 30.90 8825.90 1222.72 330.33 -1632.25 1665.34 281.44 7.29 BP MWD=` 107 9364.70 62.01 334.61 27.70 8838.83 1246.84 352.39 -1642.89 1680.26 282.11 2.58 BP _ MWD-- 108 9400.27 65.60 331.62 35.57 8854.54 1278.36 380.84 -1657.33 1700.53 282.94 12.60 BP _ MWD-~- 109 9433.11 67.65 332.18 32.84 8867.57 1308.23. 407.44 -1671.53 1720.47 283.70 6.44 BP MWD-- 110 9465.02 68.89 331.63 31.91 8879.38 1337.61 433.58 -1685.49 1740.37 284.43 4.20 BP _ MWD-- 111 9497.18 71.19 331.69 32.16 8890.36 1367.58 460.19 -1699.84 1761.03 285.15 7.15 BP MWD~C 112 9529.95 70.79 332.03 32.77 8901.03 1398.28 487.51 -1714.45 1782.42 285.87 1.57 BP MWD== • 113 9561.65 70.84 331.62 31.70 8911.45 1427.96 513.90 -1728.59 1803.36 286.56 1.23 BP _ MWD-- 114 9594.53 74.17 331.73 32.88 8921.33 1459.05 541.50 -1743.46 1825.62 287.25 10.13 BP _ MWD-'- 115 9626.71 76.06 332.55 32.18 8929.60 1489.85 568.99 -1758.00 1847.78 287.93 6.37 BP _ MWDJ- 116 9659.03 77.52 332.49 32.32 8936.98 1520.98 596.91 -1772.51 1870.32 288.61 4.52 BP MWD- 117 9692.00 81.79 333.22 32.97 8942.90 1553.03 625.76 -1787.31 1893.69 289.30 13.13 BP _ MWD-'-. 118 9722.03 83.76 334.53 30.03 8946.68 1582.40 652.51 -1800.42 1915.02 289.92 7.86 BP MWD-` 119 9755.27 86.23 334.53 33.24 8949.58 1614.97 682.40 -1814.66 1938.73 290.61 7.43 BP _ MWD.~'- 120 9784.74 86.89 .332.46 29.47 8951.35 1644.00 708.73 -1827.79 1960.39 291.19 7.36 BP MWD=- [(c)2008 IDEAL ID13 OC 08] SCHLUMBERGER Survey Report 30-Jul-2008 09:32:01 Page 6 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section ~ displ Azim (deg/ tool Cor r - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 9817.09 89.18 331.22 32.35 8952.46 1676.04 737.23 -1843.05 1985.03 291.80 8.05 BP MWD~- 122 9848.76 89.08 331.20 31.67 8952.94 1707.47 764.98 -1858.30 2009.59 292.37 0.32 BP MWDC 123 9880.42 89.18 331.06 31.66 8953.42 1738.90 792.70 -1873.58 2034.38 292.93 0.54 BP MWD!r' 124 9912.81 89.39 330.82 32.39 8953.82 1771.06 821.01 -1889.31 2059.99 293.49 0.98 BP MWD_-` 125 9945.01 89.29 328.96 32.20 8954.19 1803.10 848.86 -1905.47 2085.99 294.01 5.78 BP MWD~~ 126 9990.53 89.65 331.23 45.52 8954.61 1848.38 888.32 -1928.16 2122.95 294.74 5.05 BP MWD-- 127 10022.20 89.62 329.95 31.67 8954.81 1879.85 915.91 -1943.71 2148.69 295.23 4.04 BP _ MWD~- 128 10053.80 89.48 329.46 31.60 8955.06 1911.30 943.19 -1959.65 2174.82 295.70 1.61 BP MWD'-- 129 10085.70 89.58 330.07 31.90 8955.32 1943.05 970.75 -1975.71 2201.32 296.17 1.94 BP _ MWDG-' 130 10117.88 89.62 331.55 32.18 8955.55 1975.01 998.84 -1991.41 2227.86 296.64 4.60 BP _ MWDC_ 131 10150.05 89.38 330.43 32.17 8955.83 2006.96 1026.97 -2007.01 2254.49 297.10 3.56 BP MWDC:.- 132 10182.01 89.20 330.13 31.96 8956.23 2038.73 1054.73 -2022.85 2281.31 297.54 1.09 BP MWD'~'- 133 10213.75 89.31 331.81 31.74 8956.64 2070.25 1082.48 -2038.25 2307.86 297.97 5.30 BP MWD='- 134 10245.98. 89.24 331.93 32.23 8957.05 2102.19 1110.90 -2053.44 2334.68 298.41 0.43 BP _ MWD`_ 135 10277.36 89.20 331.75 31.38 8957.47 2133.29 1138.56 -2068.25 2360.93 298.83 0.59 BP MWDJ_ 136 10309.21 89.27 332.21 31.85 8957.90 2164.84 1166.67 -2083.21 2387.66 299.25 1.46 BP MWD=' 137 10341.57 89.14 331.89 32.36 8958.35 2196.89 1195.26 -2098.38 2414.92 299.67 1.07 BP _ MWD-'_ 138 10373.07. 89.03 330.91 31.50 8958.85 2228.14 1222.91 -2113.46 2441.76 300.06 3.13 BP _ MWDJ` 139 10405.33 89.03 332.29 32.26 8959.40 2260.13 1251.28 -2128.80 2469.31 300.45 4.28 BP MWD~'~ 140 10437.13 88.72 331.65 31.80 8960.02 2291.63 1279.35 -2143.74 2496.47 300.83 2.24 BP MWD-'_! 141 10468.31 88.55 330.73 31.18 8960.76 2322.57 1306.66 -2158.76 2523.41 301.19 3.00 BP MWD'~_ 142 10500.36 88.62 330.97 32.05 8961.55 2354.39 1334.64 -2174.37 2551.30 301.54 0.78 BP MWD~=` 143 10532.47 88.55 331.18 32.11 8962.35 2386.26 1362.74 -2189.89 2579.28 301.89 0.69 BP _ MWD"- 144 10564.32 88.48 330.62 31.85 8963.17 2417.88 1390.56 -2205.38 2607.17 302.23 1.77 BP _ MWDC- 145 10596.68 88.48 331.26 32.36 8964.03 2450.01 1418.83 -2221.09 2635.59 302.57 1.98 BP _ MWD-'` 146 10628.40 89.44 330.78 31.72 8964.61 2481.50 1446.58 -2236.45 2663.52 302.90 3.38 BP MWD:='= 147 10659.81 89.65 328.57 31.41 8964.86 2512.76 1473.69 -2252.31 2691.59 303.20 7.07 BP _ MWD_- 148 10692.21 90.20 329.54 32.40 8964.90 2545.05 1501.47 -2268.97 2720.78 303.49 3.44 BP MWD-- 149 10723.24 89.57 328.70 31.03 8964.96 2575.96 1528.11 -2284.90 2748.79 303.77 3.38 BP _ _MWD-- 150 10754.13 91.06 325.83 30.89 8964.79 2606.80 1554.09 -2301.60 2777.15 304.03 10.47 BP MWD-- • C~ [(c)2008 IDEAL ID13 OC 08] SCHLUMBERGER Survey Report 30 -Jul-2008 09:32:01 Page 7 of 7 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section ~~ C displ Azim (deg/ tool Cor r - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 151 10786.46 93.22 325.38 32.33 8963.58 2639.10 1580.74 -2319.85 2807.21 304.27 6.82 BP MWD-'- 152 10818.38 93.86 325.18 31.92 8961.61 2670.95 1606.93 -2337.99 2836.98 304.50 2.10 BP _ _MWD.=_ 153 10850.81 97.34 325.24 32.43 8958.45 2703.22 1633.43 -2356.41 2867.18 304.73 10.73 BP MWD-'~' 154 10883.03 97.42 325.49 32.22 8954.31 2735.16 1659.72 -2374.57 2897.11 304.95 0.81 BP _ MWD-.<J 155 10914.71 97.97 325.01 31.68 8950.07 2766.55 1685.52 -2392.46 2926.57 305.17 2.30 BP _ MWD~J~ 156 10946.45 98.56 323.21 31.74 8945.50 2797.96 1710.96 -2410.87 2956.30 305.36 5.91 BP _MWD_='` 157 10979.10 99.12 322.17 32.65 8940.49 2830.21 1736.62 -2430.43 2987.11 305.55 3.58 BP MWD^'` 158 11010.18 99.11 322.30 31.08 8935.56 2860.88 1760.88 -2449.22 3016.52 305.71 0.41 BP _ _MWD-- 159 11041.64 98.88 320.90 31.46 8930.64 2891.92 1785.23 -2468.52 3046.42 305.87 4.46 BP MWD~- 160 11073.50 98.91 320.39 31.86 8925.72 2923.34 1809.57 -2488.48 3076.87 306.02 1.58 BP _ MWD-- 161 11105.68 98.88 320.76 32.18 8920.74 2955.07 1834.13 -2508.67 3107.65 306.17 1.14 BP MWD'- 162 11137.04 98.29 320.15 31.36 8916.06 2986.01 1858.04 -2528.42 3137.71 306.31 2.69 BP _ MWD-~ 163 11169.30 95.94 318.21 32.26 8912.06 3017.89 1882.26 -2549.34 3168.92 306.44 9.42 BP _ MWD-` 164 11200.33 93.73 316.42 31.03 8909.45 3048.59 1904.99 -2570.30 3199.29 306.54 9.15 BP _ MWD'- 165 11232.64 91.33 316.38 32.31 8908.02 3080.56 1928.36 -2592.56 3231.09 306.64 7.43 BP MWD_'` 166 11264.33 89.29 314.86 31.69 8907.85 3111.90 1951.01 -2614.72 3262.39 306.73 8.03 BP MWD='=' 167 11297.09 89.62 316.14 32.76 8908.16 3144.28 1974.38 -2637.68 3294.77 306.82 4.03 BP _ MWD-~^° 168 11328.71 89.62 316.52 31.62 8908.37 3175.60 1997.25 -2659.52 3325.96 306.91 1.20 BP _ MWD~^ 169 11361.09 89.24 316.48 32.38 8908.70 3207.68 2020.73 -2681.80 3357.89 307.00 1.18 BP _ MWD-` 170 11390.42 89.24 316.42 29.33 8909.08 3236.74 2041.99 -2702.01 3386.82 307.08 0.20 BP _ MWD-'^ 171 11424.43 88.59 317.29 34.01 8909.73 3270.47 2066.80 -2725.26 3420.34 307.18 3.19 BP MWD-'-'. 172 11456.56 87.76 316.69 32.13 8910.75 3302.33 2090.28 -2747.17 3451.98 307.27 3.19 BP _ MWD- • 173 11488.19 87.63 316.77 31.63 8912.02 3333.66 2113.29 -2768.83 3483.16 307.35 0.48 BP MWD-'- 174 11519.78 87.46 316.62 31.59 8913.38 3364.96 2136.26 -2790.48 3514.31 307.44 0.72 BP _ MWD-' 175 11552.21 87.39 317.15 32.43 8914.83 3397.09 2159.91 -2812.62 3546.27 307.52 1.65 BP _ MWD-'` 176 11584.39 86.94 316.24 32.18 8916.43 3428.95 2183.30 -2834.66 3578.00 307.60 3.15 BP MWD=C 177 11615.70 86.84 316.28 31.31 8918.12 3459.92 2205.89 -2856.28 3608.91 307.68 0.34 BP _ MWD'~'- 178 11646.56 86.97 317.19 30.86 8919.79 3490.47 2228.32 -2877.40 3639.35 307.76 2.97 BP _ MWD~~' 179 11680.15 88.04 317.14 33.59 8921.25 3523.78 2252.93 -2900.21 3672.46 307.84 3.19 BP _MWD'-''J 180 11735.00 88.04 317.14 54.85 8923.13 3578.18 2293.12 -2937.50 3726.57 307.98 0.00 Pr oject to TD [(c)2008 IDEAL ID13 OC 08] Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken Well No 06-21B Date Dispatched: 31-Jul-08 Installation/Rig Nabors 7ES Dispatched By: F. Medina LWD Log Delivery V2.1, 03-06-06 Data No Of Prints No of Flo ies Surveys 2 1 ~ Received By: U Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 fGarke3@slb.com Fax: 907-561-8317 a,~~-~~~ 06-21B EZSV Plug Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 15, 2008 8:26 AM To: 'Vazquez, Eleazar' Subject: RE: 06-21 B EZSV Plug Eli, It appear that these changes should improve the planned operations. Maintaining the barriers whether permanent or temporary is important. Nothing further is needed. I will place a copy of this message in the well files. Also, please include the permit to drill numbers in the subject line of the message. In this case, it appears this message applies to both 06-21A (200-080) and 06-21B (208-099). Call or message with any questions. Tom Maunder, PE AOGCC From: Vazquez, Eleazar [mailto:vazge0@BP.com] Sent: Tuesday, July 15, 2008 7:14 AM To: Maunder, Thomas E (DOA) Subject: 06-21B EZSV Plug Good morning Tom, It is desired to run a new type of Whipstock assembly called Smith Trackmaster Plus Whipstock that does not require an EZSV plug. The EZSV plug was also planned to be used as a mechanical barrier during the ND ROPE phase to change the tubing spool and pack offs. However, a tested storm packer can be set before this operation to comply with our mechanical barriers policy. Finatly, after reviewing our drilling fluids design, it was determined that 10.4 ppg was not required to mill the 9-5/8" casing window. Instead, 9.0 ppg should be used and the system will be weighted up to 10.6 ppg at 150 - 200' above the HRZ. The kick tolerance remains infinite for this interval of the well. Please let me know if you need any additional information or if you have any questions. Thanks in advance, Eli Vazquez BP Exploration Alaska GPB Rotary Drilling Engineer Direct: 907.564.5918 Mobile 1:907.240.8137 Mobile 2: 915.346.6430 7/15/2008 S ARAH PAL/N, GOVERNOR COis-7~RO ~ ~~ 333 W. 7th AVENUE, SUITE 100 sill l.~ ois ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team header BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-21B BP Exploration Alaska Inc. ermit No: 208-099 Surface Location: 466' FSL, 959' FEL, SEC. 02, T10N, R14E, UM Bottomhole Location: 2519' FSL, 3745' FEL, SEC. 02, T10N, R14E, UM Dear Mr. Hobbs: 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). incerely, Daniel T. Seamount, Jr. ~7 Chair DATED this `day of June, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA''~~~ 8 d ~ ~/ ALAS~OIL AND GAS CONSERVATION COMMI~N ~} PERMIT TO DRILL I~f ~3.~u~ ~ ~ 200$ 20 AAC 25.005 1 a. Type of work ^ Drilt ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Speci `Tf" II s pro os d' or: ' ^ Coalbed Methane 6>~~6rates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 06-21 B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11394' TVD 8950' 12. Field /Pool(s): Prudhoe Bay Field !Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 466' FSL 959' FEL SEC 02 T10N R14E UM 7. Property Designation: ADL 028311 Pool , , . , , , Top of Productive Horizon: 893' FSL, 2627' FEL, SEC. 02, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 1, 2008 Total Depth: 2519' FSL, 3745' FEL, SEC. 02, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 37,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-686026 y-5941066 Zone-ASP4 10. KB Elevation Plan (Height above GL): 65.5 feet 15. Distance to Nearest Well Within Pool: 700' 16. Deviated Wells: Kickoff Depth: 7300 feet Maximum Hole An le: 88 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3265 Surface: 2363 18' Gasin Pr ram: S ecificatio ns _ To '- Settih De th -Bo ttom uanti of Cement cf orsacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data N/A 7" 26# L-80 BTC-M 4150' 3000' 3000' 7150' 6955' 720 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-M 1824' 7150' 6955' 8974' 8592' 343 sx Class 'G' 6-1/8" 4-1/2" 12.6# 13Cr80 VamTo 257 ' 8824' 8462' 11394' 9 15' 314 sx Class 'G' 19. PRESE NT-WELL CONDITIONS UMMARY (To be completed for Redrill and Re-.entry Operations) Total Depth MD (ft): 9503 Total Depth TVD (ft): 9103 Plugs (measured): None Effective Depth MD (ft): 9456 Effective Depth TVD (ft): 9060 Junk (measured): None Casing- Length Size Cement Volume MD TVD Conductor /Structural g0' 20" 1900# Poleset 80' 80' Surface 2510' 13-3/8" 2259 sx Fondu 400 sx Permafrost'C' 2510' 2510' Intermediate Production 8842' 9-5/8" 500 sx CI ss'G' 50 Bbls Class 'C' 8842' 8596' Liner 482' 7" 275 sx Class 'G' 8519' - 9001' 8279' - 8752' 721' 2-3/8" 54 sx LARC 8782' - 9503' 8537' - 9103' Perforation Depth MD (ft): 9190' - 9314' Perforation Oepth TVD (ft): 8886' - 8945' 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 tr a and correct. Contact EieaZar'e~r Vazquez, 564-5918 Printed Name Greg Hobb, Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4191 Date ~J .~~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: o?D O O API Number: 50-029-20802-02-00 Permit Approval See cover letter for Date: other re uirements Conditions of Approval: ~y If box is checked, well may not be used to explore for, test, or produce coalbed met1hane, gas hydrates, or gas contained shales: Lr1 Samples Req'd: ~ Yes L~0 No Mud Log Req'd: ^~lfes ~No HZS Measures: Yes ^ No Directional Survey Req'd: ~ Yes ^ No Other: ~SC~® I~S • ~~~ ~S~ APPROVED BY THE COMMISSION Date ,COMMISSIONER .0 Form 10-40`1 Revised 12/2005 ~ ~ Submit In Duplicate ~~~~~L ba To: Alaska Oil & Gas Conservation Commission From: Eli Vazquez, ODE Date: June 4, 2008 Re: 06-21B Sidetrack Permit to Drill The 06-21B well is scheduled to be drilled by Nabors Rig 7ES which is currently scheduled to move onto the location ~08/O1/08. The plan is to exit the parent 06-21A wellbore from the 9-5/8" casing at 7300' MD with an 8-1/2" BHA. The 8-1/2" hole will then be drilled to the top of the Sag River formation where a 7" drilling liner will be run and cemented. The production hole will be drilled with a 6-1/8" BHA building to horizontal with 10 degree doglegs. The well will then run horizontally through Zone 2B/2C to TD at 11,394' MD. The liner will be a 4-1/2" Cr solid liner and the tubing will be 4-1/2" chrome, tied into the top of the production liner. Please note the following Well Summary as detailed on the next few pages: 06-21 B Permit to Drill Application Page 1 Well Name: 06-21 B Planned Well Summary Sidetrack / Target Zone Well 06-21 B Well Type Horizontal Producer Objective 2B/2C API Number: 50-029-20802-02 Current Status 06-21A Shut-In and P&A Procedures commencing Estimated Start Date: 01-Au -2008 Time to Com lete: 27 Da s Surface Northin Eastin Offsets TRS Location 5941065.63 686025.55 4813' FNL / 4320' FWL 10 N, 14 E, 2 Northin Eastin Offsets TRS Target 5941452 684347 FWL FNL / 2652 4386 14 E 2 10 N L i ; ; , , ons ocat 5942570 683665 3252 FNL / 1999 FWL 10 N, 14 E, 2 Bottom Northin Eastin Offsets TRS Location 5943050 683188 2760' FNL / 1534' FWL 10 N, 14 E, 2 Planned KOP: 7300'MD / 7032'TVDss Planned TD: 11,394'MD / 8,950' TVDss Ri Nabors 7ES BFE: 37' RTE: 65.5' Directional A roved Well Ian: Schlumber er P6 Exit oint: 7300' MD / 7097' TVD Maximum Hole Inclination: Original well bore is vertical building to ~18° at KOP. Horizontal interval is ~83°-88° from 9,675' to TD. Proximity Issues: Two faults expected in the Kingak and the lateral. The perforatable wellbore should maintain 100' standoff from any fault or fault tips that are deemed to be a conduit for earl as ent Surve Pro ram: Standard MWD+IIFR+MS Nearest Well: Well 06-24A located 700' away, center to center, in the reservoir zone Nearest Property Line 37,000' (North) Contacts Drilling Engineer Geologist Pad Engineer Name Phone # E-mail Eli Vazquez 564-5918 vazgeOC«~bp.com Doug Stoner 564-5852 Doug.StonerC~bp.com Ana Maria Seltenright 564-4418 Ana.SeltenrightC~3bp.com 06-21 B Permit to Drill Application Page 2 • Formation Markers 06-21 B (eased cn soR) Est. Formation To s Uncertain Commercial Hydrocarbo n Bearin Est. Pore Press. Formation (TVDss) eet) (Yes/No) (Psi) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re aired from surface to TD for all new wells Base Permefrost -1920 SV2 -3769 SVl -4154 UG4 -4494 UG3 -4664 UGl -5233 WS2 -5828 WSl -6047 CM3 -6281 CM2 -6782 KOP -7024 CMl -7523 THRZ -7875 BHRZ/TKUP -8028 TJC/LCU -$087 TJB -8323 TJA -8432 TSGR -8525 ±20 Yes TSHU -8524 ±20 Yes TSAD -8624 ±20 Yes TCGL -8810 ±20 Yes 3265 si BCGL -8881 ±20 Yes POWC -8886 ±20 Yes 23SB -8922 ±20 Yes 22TS -8970 ±20 Yes HOT -8980 ±20 Yes 21TS -9017 ±20 Yes Casina/Tubina Proaram Hole Size Casing / Tubing Size Wt. Grade Connect ion Length Top MD / TVD Bottom and / tvd Scab Liner 7" 26# L-80 BTC-M 4150' 3000' / 3000' 7150' / 6955' 8-1 /2" 7" 26# L-80 BTC-M -1824' 7150' / 6955' 8974' / 8592' 6-1/8" 4-1/2" 12.6# 13Cr-80 VamTo -2570' 8824' / 8462' 11394' / 9015' Tubin 4-1/2" 12.6# 13Cr-80 VamTo 8821' Surface 8821' / 8461' 06-21 B Permit to Drill Application Page 3 Mud Proaram Hole Section / O eration: Drillin Intermediate Interval C«3 7,300 - 8,974' T e Densit PV YP 10 sec el 10 min el H Fluid Loss LSND 10.4-10.8 8-15 24-30 5-15 <30 9.0-9.5 6-12cc Hole Section / O eration: Drillin Production Interval C«3 8,974 - 11,395' T e Densit PV YP 10 sec el 10 min el H Fluid Loss FloProSF 8.4-8.5 6-12 22-28 12-15 <30 9.0-9.5 6-8cc Loaaina Proaram Hole Section: Required Sensors /Service 8-1/2" Production: DIR/GR/RES/PWD throu hout the interval. Sam le catcher -None. Cased Hole: None tanned O en Hole: None tanned Hole Section: Required Sensors /Service DIR/GR/RES throughout the interval all in real-time mode to define oil/water contacts. Neutron and Density tools will be picked up for lateral section. MAD pass build 6-1/8" Production: section in `up' direction before drilling the lateral section. Send MWD log and directional data(e-mail) to PDC and town geologist ASAP after reaching TD. Sample catcher - As directed b wellsite eolo ist. Cased Hole: None tanned O en Hole: None tanned Cement Proaram Casin Strin 7", 26#, L-80, BTC-M intermediate liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 1674' of 7" X 8-1/2" annulus with 40% excess, plus 80' of 7", 26# shoe track, lus 150' of 7" x 9-5/8" liner la lus 200' of 9-5/8" X 4" drill i e annulus. S acer 30 bbls MudPUSH II at 13.3 Fluids Sequence / Lead Slur None tanned Volume: Tail Slur 71.4 bbl / 401 cu ft / 343 sks of 15.8 Class `G'; 1.17 ft /sk. BHST: 193° BHCT: TBD by Schlumber er Cement will be batch mixed before pumping Casin Strin 7", 26#, L-80, BTC-M scab liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 4300' of 7" X 9-5/8" annulus with 25 bbls excess, plus 80' of 7", 26# shoe track, lus 200' of 9-5/8" X 4" drill i e annulus. S acer 30 bbls MudPUSH II at 13.3 Fluids Sequence / Lead Slur None tanned Volume: Tail Slur 150 bbl / 842 cu ft / 720 sks of 15.8 Class `G'; 1.17 ft /sk. BHST: 86° BHCT: TBD by Schlumber er Cement will be batch mixed before pumping 06-21 B Permit to Drill Application .. Page 4 • r Casin Strin 4-1/2", 12.6#, 13Cr-80, Vam To Liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 2420' of 4-1/2" X 6-1/8" annulus with 40% excess, plus 80; of 4-1/2", 12.6# shoe track, plus 150 of 4-1/2 x 7 liner lap, plus 200 of 7 X 4 drill pipe annulus. S acer 30 bbls MudPUSH II at 11.7 Fluids Sequence / Lead Slur None tanned Volume: Tail Slur 65.3 bbl / 367 cu ft / 314 sks of 15.8 Class `G'; 1.17 ft /sk. BHST: 208° BHCT: TBD by Schlumber er Cement will be batch mixed before pumping Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. Close Approach Shut-in Wells: All wells pass major risk criteria. Hydrogen Sulfide DS 06 is an H2S site. Recent H2S data from the pad is as follows: Date of Well Name H2S Level Readin #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility 06-20 15 m 3/5/2002 06-03 15 m 6/18/2007 06-16 10 m 11/4/2007 06-24A 25 m 11 /3/2007 06-13 250 m 1/9/2004 Faults The planned well will cross a small fault in the Kingak section at approximately 8550 ft MD. After landing, the well will perpendicularly cross another small fault in Zone 2C near 10520 ft MD. Risk of loss circulation for the proposed 06-21 B well is low. Formation Where Fault is MD TVDSS Est. Throw Uncertainty Encountered Intersect Intersect Throw Direction Fault #1 -Kin ak 8555 -8225 10 ft U thrown +/- 150 ft Fault #2 -Zone 2C 10520 -8905 10 ft U thrown +/- 100 ft 06-21 B Permit to Drill Application Page 5 Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8-1/2" intermediate section Maximum antici ated BHP: 3,163 si at 8,592' TVDss Maximum surface ressure: 2,304 si based u on BHP and a full column of as from TD C~ 0.10 si/ft Calculated kick tolerance: Infinite with 10.4 EMW FIT FIT to 12.0 EMW Planned BOPE test ressure: 250psi low / 3,500psi high - 7 day test cycle until a window is milled in 9- 5/8" casin . Once a window is milled a 14 da test c cle can commence. Well Interval: 6-1/8" roduction liner section Maximum antici ated BHP: 3,265 si at 8,810' TVDss Maximum surface ressure: 2,363 si based u on BHP and a full column of as from TD ~ 0.10 si/ft Calculated kick tolerance: Infinite with 8.4 EMW FIT FIT to 10.1 EMW Planned com letion fluid: 8.5 seawater with 2200' diesel Planned BOPE test ressure: 250 si low / 3,500 si hi h -14 da test c cle. Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 06-21 B Permit to Drill Application Page 6 i Drilling Hazards and Contin POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be pressured at 7.1 ppg EMW. This pressure is estimated based on offset well pressures. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation/Breathing A. The planned well will cross a small fault in the Kingak section at approximately 8550 ft MD. After landing, the well will perpendicularly cross another small fault in Zone 2C near 10520 ft MD. B. Lost circulation events from nearby wells include 200 barrels at 06-04 in the Kingak, 1179 barrels at Zone 2 and 316 barrels at the Sag River in the 06-14A well, and 4000 barrels of fluid at Zone 4 in the 14-04A well. Well T e Loss bbl MD SSTVD Formation Fault? 06-04 Ri 200 8657 -8334 Kin ak Yes casin 06-14A Ri 316 9496 -8600 Sa River Yes 06-14A Ri 1179 .9975 -8966 Zone 2 No 14-04A Coil 4000 12340 -8721 Zone 4 No III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for both the intermediate and production hole sections is infinite with planned mud weights. The FIT will prove up adequate formation strength for expected ECD's. B. Inte rit Testin Test Test Point Test Type Test pressure 9-5/8" window 20' be and mid-window FIT 12.0 EMW 7" shoe 20' be and shoe FIT 10.1 EMW IV. Stuck Pipe A. Significant directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide DS 06 is an H2S site. The highest H2S level recorded on the pad was 250 ppm on 1/9/2004 on 06-13. Follow procedures for high H2S levels. VII. Faults A. The proposed 06-21 B well lies in a high risk province of the field for lost circulation at faults. However, only 4 loss circulation events were encountered in the Sadlerochit and Kingak sections in 3 of the surrounding 19 wells (16%). See Section II on lost circulation for more details. Formation Where TVDSS Fault is Encountered MD Intersect Intersect Est. Throw Throw Direction Uncertainty Fault #1 -Kin ak 8555 -8225 10 ft U thrown +/- 150 ft Fault #2 -Zone 2C 10520 -8905 10 ft U thrown +/- 100 ft VIII. Anti-Collision Issues B. All wells pass major risk criteria for close approach. 06-24A is the closest well located 700' away, center to center, in the reservoir zone. CONSULT THE DS 06 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 06-21 B Permit to Drill Application Page 7 Operations Summary WELL STATUS / CMIT-T x IA Passed to 3000 psi 11/14/05 / CTU tag TD C~ 9437' with 1.688" motor and mill 04/09/07 / CTU drifted to 9220' with no problems 04/10/07 / Caliper 5-1/2" tubing 4/22/07 / MIT-IA Passed 3000 psi 10/16/07 / MIT-OA Passed to 2000 psi 10/16/07 / 06-21 A is currently shut-in due to extremely high GOR. PRE-RIG OPERATIONS 1. S: RU, drift for cement retainer and jet cutter. 2. S: Pull DSSSV C«~ 2153' 3. O: Fluid pack the tubing and inner annulus w/seawater/diesel. 4. C: Set a cement retainer inside the 4-1/2" at 8700' and squeeze --10 bbls of cement into perfs and fill the tubing from 9,466' up to 8,700'. Un-sting and lay 100' of cement (-- 1.5 bbls) of cement on top of retainer. i. 15.8 ppg class G cement calculations: i. 2-3/8" liner = 9,466' - 8,782', 684' X .0039 = 2.7 bbls ii. 4-1/2" tubing below cement retainer = 8,782'-8700', 82' x 0.0152 = 1.2 bbls iii. 4-1 /2" tubing above cement retainer = 100' x 0.0152 = 1.5 bbls iv. Cement squeezed into perfs = 10 bbls v. Total (with 0.6 bbls excess) = 16 bbls 5. F: Test to 3500 psi. 6. S: Tag TOC 7. E: Jet cut the 5-1/2" tubing in the middle of a full joint at 7800' MD. 8. F: CMIT - T x IA to 3,500 psi for 30 minutes. MIT - OA to 2,000 psi for 30 minutes. 9. F: Circulate the well to sea water and freeze protect with diesel to 2,200' MD. 10. F: Bleed all casing and annulus pressures to zero psi. 11. W: Function all tubing and casing lock down screws. Repair and replace as necessary. PPPOT - IC and PPPOT - T. 12. W: Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well preparation cost on the handover form. RIG OPERATIONS: 1. MI / RU Nabors rig 7ES 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. 3. Pressure test MIT-OA to 2,000 psi for 30 minutes. 4. Set BPV using a T-bar and test from below to 1,000 psi for 30 minutes. 5. Nipple down tree. Nipple up and test BOPE to 3,500 psi. Pull TWC. • Note on barriers during ND Tree / NU BOP • Tubing -Tested cement plug (P&A perfs), kill weight fluid and a BPV. • IA -Tested cement plug (P&A perfs), kill weight fluid, tested pack-offs) and annulus valves. • OA -MIT-OA and annular valve. 6. RU and pull the 5-1/2" TBG-IPC, 17#, L-80 tubing from the pre-rig jet cut at 7800' MD. Spool up the control lines. 7. RU E-line. MU 8-1/2" gauge ring /junk basket /casing collar locator (CCL). RIH and tag tubing stump at 7800' MD to confirm access to run an EZSV. If gauge ring /junk basket indicates a scraper run is needed, PU 4" drillpipe and 9-5/8" clean-out assembly and clean-out well to 7450' MD. POOH. 06-21 B Permit to Drill Application Page 8 8. On E-line, RIH with HES EZSV. Set bride plug at 7325' MD, as re uired to avoid cutting a casing collar while milling the window. POOH. R/D E-line. 9. Pressure-test the 9-5/8" casing to 3,500 psi for 30 charted minutes. 10. Bleed 9-5/8" annulus pressure. 11. Change 9-5/8" pack-off (the mandral pack-off can be pulled through the BOP stack without nippling down). 12. Test pack-off to 5,000 psi or as recommended by FMC Rep. 13. ND BOPE and set back. • Note on barriers during ND BOPE • Tubing has been pulled • IA -Tested cement plug (P&A perfs), tested EZSV plug • OA -cemented 9-5/8" x 13-3/8" annulus and a passing MIT-OA. `,,..~'~ 14. ND and remove the tubing spool. ~~ 15. Change tubing spool and test to 5,000 psi or as recommended by FMC Rep. 16. NU and test BOP. 17. P/U and RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly on 4" drill pipe. Orient whipstock per Schlumberger Rep and set on bridge plug. Shear off the whipstock. 18. Displace the well to 10.4 ppg LSND based milling fluid. Completely displace the well prior to beainnina the millino operations. 19. Mill window in 9-5/8" casing at ± 7,300'MD, plus approximately ZO' beyond middle or wmaow. Circulate well bore clean. 20. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg. POOH. I 21. M/U 8-'/z" GR/RES/PWD/MWD assembly. RIH, kick off and drill the 8'/z" intermediate section with I 10.4 - 10.8 ppg LSND drilling fluid. ~~~~' I~~ ~ 22. Drill ahead to the 7" liner point at top of the Sag River, as per the directional plan. Circulate the POOH hi h d d l l h i THRZ ~,~. . or g er as nee e . wel ean, s ort tr p to c " v~R 23. Change out to 7 rams, and test. i\ 24. MU and run 1,753' of 7", 26#, L-80, BTC-M liner to bottom on drill pipe. Circulate and condition the hole. 25. Cement the entire 7" liner through the 8-1/2" hole and back 150' into the 9-5/8" casing at 7,150' MD. Set the hanger and packer, displace cement with mud. 26. Circulate bottoms up, POOH, UD liner running tool (LRT). 27. Run a 7" scab liner from the top of the 7" liner to 3000' MD. Fully cement the scab liner. Stab into the 7" liner tieback receptacle, and set the packer. 28. Pressure test the 7" tieback to 3500 psi for 30 minutes after sufficient compressive strength is \ obtained. ~' c~r~L~~a~~~jC4~Oe~lv~~~ 29. M/U the first 6-%8" Dir/GR/Res assembly with a roller cone bit and RIH. Wash down to the cement ~r",~I`G~ " ~y plug in the 7 liner. 30. Test the liner to 3,500 psi for 30 charted minutes. 31. Displace to 8.4 ppg Flo Pro Fluid. 32. Drill out of cement and float equipment to shoe. 33. Drill out the 7" shoe plus ~20' new formation, pull up into the shoe and conduct an FIT to 10.1 PPg• 34. Drill the 6-1/8" production interval as per directional plan to end of the build section. 35. POOH for PDC bit. 36. POOH, PU second 6-1/8" Neu/Den/GR/Res BHA with PDC. 37. RIH, drill ahead to TD. 38. POOH. UD BHA. 39. Run and fully cement 2,570' of 4-1/2", 12.6#, L-80 solid liner. This will include 150' liner lap inside the 7" drilling liner. Cement the liner. A pert pill will be left in the 4-1/2" liner. 40. Set liner top packer and displace well to clean seawater above the liner top. 41. POOH, UD LRT. 42. Pressure test casing and liner to 3,500 psi for 30 minutes. 43. RU DPC pert guns, RIH and perforate. Perf intervals to be supplied by asset. 44. R/U and run a 4'/z", 12.6#, 13Cr, VamTop tubing completion, stinging into the 4-1/2" liner tie back sleeve. 06-21 B Permit to Drill Application Page 9 45. Space out and make up tubing hanger per Cameron Rep. 46. Land the tubing hanger, and run in lock down screws. 47. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 48. Set a BPV. 49. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. • Note on barriers during the ND BOPE / NU Tree • Tubing -Kill weight fluid on a RHC plug with ball & rod and a TWC. • IA -Kill weight fluid, tested annulus and annular valve. 50. Freeze protect the well to 2,200' TVD. Secure the well. 51. RD and Move Off. • Note on barriers during the RDMO • Tubing -Kill weight fluid on a RCH plug with ball & rod and a BPV. • IA -Kill weight fluid, tested annulus and annular valve. POST-RIG OPERATIONS 1. MI / RU slick line. Pull the ball and rod /RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. Estimated Pre-rig Start Date: 07/15/2008 Estimated Spud Date: 08/01/2008 06-21 B Permit to Drill Application Page 10 I TREE _ ' 5-1 /8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = KOP = 4200' Max Angle = 64 @ 9279' Datum MD = 9168' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2510' Minimum ID =1.75" @ 9192' CTM 2-7/8" LINER 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~--~ $434' 9-5/8" X 7" BKR LNR HGR, ID = ? 3-1/2" X 2-3/8" LNR XO, ID = 1.910" ~~ 8787' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-~ 8842' 4-1/2" TBG-PC, 12.6#, .0152 bpf, ID = 3.958" 8923' 15.8 ppg Latex Cement 3-1/2" TTP-PC, 9.3 #, .0087 bpf, ID = 2.992" PERFORATION SUMMARY REF LOG: SWS CNL MEMORY LOG 09/18/00 ANGLE AT TOP PERF: 61 @ 9190' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 9190 - 9240 O 02/14/05 1-11/16" 6 9250 - 9270 O 12/05/03 1-11/16" 4 9270 - 9286 O 10/20/01 1-11/16" 4 9286 - 9296 O 04/17/01 1-11/16" 4 9296 - 9306 O 02/24/01 1-11/16" 4 9306 - 9314 O 11/23/00 1-11/16" 4 9306 - 9314 O 09/28/00 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 0~6~-21 A II !=~ 5-1/2" CAMCO BAL-O SSSVN, ID = 4.562" WITH DSSSV, ID = 2.75" (04/23/07) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2908 2834 0 MMIG DMY RK 0 10/15/07 2 4781 4681 20 MMIG DMY RK 0 10/15/07 3 6186 5980 23 MMIG DMY RK 0 10/15/07 4 7127 6860 18 MMIG DMY RK 0 07/16/00 5 7631 7340 18 MMIG DMY RK 0 07/16/00 6 7706 7412 16 MMIG DMY RK 0 07/16/00 7 8020 7714 14 MMIG DMY RK 0 07/16/00 8 8099 7791 14 MMIG DMY RK 0 07/16/00 9 8293 7982 8 MMIG DMY RK 0 10/15/07 10 8369 8057 11 MMIG DMY* RK 0 08/24/02 'UM Y tiAS t:JC I tJVUtU t'K(a 8406' 5-1/2" CAMCO SLD SLV, ID = 4.50" $434' S-1/2" BKR PBRASSY, ID = ? $44$' 9-5/8" X 5-1 /2" BKR FHL PKR, ID = ? 8457' 5-1/2" X 4-1/2" XO, ID = 3.958" 8782' 3.70" BKR DEPLOY SLV, ID = 3.00" 8924' 4-1/2" X 3-1/2" XO, ID = 2.992" 8930' 4-1/2" X 3-1/2" BKR FB-1 PKR 8939' 3-1/2" CAMCO NO-GO NIPI BEHIND LINER 895~~ 3-1/2" WLEG, ID = 2.992" 8956' ELMD TT LOGGED ON 04/28/83 7" MILLOUT WINDOW (06-21A) 9000' - 9005' I 9192'CTM MILL OUT OBSTRUCTION, ID = 1.75" AT TOP OF PERFs (04/10/07) PBTD 9466' 2-3/8" LNR, 4.6#, L-80, .0039 bpf, ID = 1.941" ~-~ 9503' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/15/82 ORIGINAL COMPLETION 04/10/07 DMS/PAG MILLED OUT OBSTRUCTION 07/16/00 CTD SIDETRACK 04/23/07 SPF/TLH DSSSV C/O 8 UPDATE 10/21/01 CHlKAK CORRECTIONS 10/15/07 TEL/PJC GLV C/O 03/02/05 JLG/TLH ADPERF 05/01/08 EV 2-3/8' LNR CEMENT 09/24/05 EZL/PJC WANER SFTY NOTE DELETED 12/04/05 DAV/TLH GLV C/O PRUDHOE B WELL: O6 PERMIT No: X20 API No: 50 f10N,R14E 4E BP Exploratio TREE=' 5-1/8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = KOP = 4200' Max Angle = 64 @ 9279' Datum MD = 9168' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-j 2510' 7" scab liner top ! BOT Liner Hanger 3000' FuIM Cemented w ith 15.8 ppq Cement -3000' • 06-21 B PROPOSED 9-5/8" BOT Whipstock 11 7322 9-5/8" EZSV Plug 7325' Jet c ut H 7800• Estimated Top of 15.8 ppg Cement ~ 8600' 4-i(2" Cement Retainer -8700' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ $$42' 15.8 ppg Latex Cement PERFORATION SUMMARY REF LOG: SWS CNL MEMORY LOG 09/18/00 A NGLE AT TOP PERF: 61 @ 9190' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 9190 - 9240 O 02/14/05 1-11/16" 6 9250 - 9270 O 12/05/03 1-11/16" 4 9270 - 9286 O 10/20/01 1-11/16" 4 9286 - 9296 O 04/17/01 1-11/16" 4 9296 - 9306 O 02/24/01 1-11 /16" 4 9306 - 9314 O 11 /23/00 1-11/16" 4 9306 - 9314 O 09/28/00 2-3/8" bpf, ID = 1.941" SAFETY: SAFETY NOTES: BKR FHL PKRS HAVER TEST PRESS. LIMITS. CALL WIE @X5102 PRIOR TO ANY PT WORK. DON'T PULL DGLV #10 -REQUIRES EXT. PKG FOR ANN COMM PROBLEM. 2100' 4-1/2" HES X LANDING NIP, ID=3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 6 5 4 3 2 1 ~ 7150' ~ yT', 26il, L-80, BTGM, Scab Liner 7150' T' LNR Top Packer (BOT HCM2XP) 7300' KOP /Top 9-518" Window 4.5", 12.6#, 13-CR, VAM TOP, TBG. Fully Cemented Liner 15.8 ppg Class G $729' 4.5" HES X Landing Nipple X3.813" 8745' S" x T' BOT S-3 Packer 8770' 4.5" HES X Landing Nipple ID~3.813" 8813' 4.5" HES XN Landing N~ple X3.75" gg24' 4.5" LNR Top Facker (BOT HCMbZXP/ ~ ,° 8974' T', 26#, L-80, BTGM, Liner 11394' I~4.5", 12.6#, 13Cr-80, VamTop, Later ( 7"MILLOUTWINDOW (06-21A) 9000'-9005' ' 9192'CTM MILL OUT OBSTRUCTION, ID = 1.75" AT TOP OF PERFs (04/10/07) .~:: PBTD 9466' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/15/82 ORIGINAL COMPLETION 04/10/07 DMS/PAG MILLED OUT OBSTRUCTION 07/16/00 CTD SIDETRACK 04/23/07 SPF/TLH DSSSV C/O & UPDATE 10/21/01 CHIKAK CORRECTIONS 10/15/07 TE1/PJC GLV C/O 03/02/05 JLG/TLH ADPERF 02/25/08 EV 06-21B PROPOSED 09/24/05 EZL/PJC WAIVER SFTY NOTE DELETED ~.I%b4?l.t~ i^'s,~~~~J=/ j i -±I ~'L ;;i'd.: PRUDHOE BAY UNIT WELL: 06-21 A PERMff No: ~Z000800 API No: 50-029-20802-01 SEC 2, T10N, R14E 4812' FNL & 958' FEL BP Exploration (Alaska) by DS06-21 B (P6) Pro Report Date: April 24, 2008 Client: BP Exploration Alaska Field: Prudhoe Bay Unit.- EOA Structure 1 Slot: Well: DS-O6 / 06-21 06-21 ~ Borehole: Ov Plan 06-21B ~ ~~ UWIIAPtp: 5000292080202 p Survey Name 1 Date: 06-21 B (P6) /April 24, 2008 Tort 1 AHD I DDI 1 ERD retio: 150.811 ° / 4178.52 ft / 5.901 10.463 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.24394129, W 148.49737372 location Grid NIE YIX: N 5941065.630 ftUS, E 686025.550 ftUS Grid Convergence Angle: +1.41421924° ,osa~ Schlumberger Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 324.200° Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 65.50 ft relative to MSL Sea Bed 1 Ground Level Elevation: 37.00 ft relative to MSL Magnetic Declination: 23.200° Total Field Strength: 57680.363 nT Magnetic Dip: 80.908° Declina0on Date: July 24, 2008 Magnetic Declination Model: BGGM 2007 North Reference: TNe North Total Corr Mag North a True North: +23.200° • Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW MaglGrav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft h ft ft f! de de 1100 ft Index ftUS ftUS Ile-In sUNey /L`J1.bU IC.VV LDI.UV /VL4.-IL /UByAL 334.03 -J90.9J -IVJO.GV IVO.//f[ JJ.YV Y.i I J~YVV.7 LLl VVY.7l ~.JY IY /V.LYLJVJ IJ YY IYU .JVJVJJ IL Top Whipstock 7300.00 17.94 251.08 7032.20 7097.70 335.39 -349.30 -1057.68 45.OOR 0.82 4.71 5940690.36 684976.88 N 70.24298682 W 148 .50591514 Base Whipstock 7316.00 19.34 255.18 7047.36 7112.86 337.06 -350.78 -1062.57 -- 12.00 4.73 5940688.76 684972.02 N 70.24298279 W 148 .50595465 KOP CN 4/100 7329.00 19.34 255.18 7059.63 7125.13 338.60 -351.88 -1066.74 107.79R 0.00 4.73 5940687.56 684967.89 N 70.24297978 W 148 .50598826 7400.00 18.66 263.66 7126.77 7192.27 348.40 -356.14 -1089.39 99.78R 4.00 4.77 5940682.74 684945.34 N 70.24296813 W 148 .50617124 7500.00 18.39 276.25 7221.63 7287.13 366.84 -356.19 -1120.99 87.84R 4.00 4.82 5940681.91 684913.76 N 70.24296798 W 148 .50642641 7600.00 18.96 288.64 7316.40 7381.90 390.63 -349.28 -1152.08 76.10R 4.00 4.86 5940688.05 684882.51 N 70.24298684 W 148 .50667747 7700.00 20.28 299.90 7410.63 7476.13 419.65 -335.44 -1182.50 65.48R 4.00 4.90 5940701.13 684851.76 N 70.24302463 W 148 .50692318 7800.00 22.23 309.56 7503.85 7569.35 453.76 -314.75 -1212.12 56.47R 4.00 4.94 5940721.08 684821.64 N 70.24308115 W 148 .50716236 CM1 7820.72 22.69 311.35 7523.00 7588.50 461.45 -309.61 -1218.14 54.82R 4.00 4.95 5940726.07 684815.50 N 70.24309518 W 148. 50721100 7900.00 24.65 317.58 7595.62 7661.12 492.79 -287.30 -1240.78 49.12R 4.00 4.98 5940747.82 684792.32 N 70.24315613 W 148 .585 8000.00 27.42 324.15 7685.48 7750.98 536.55 -253.22 -1268.34 43.21 R 4.00 5.02 5940781.20 684763.92 N 70.24324921 W 148 .5 50 8100.00 30.45 329.56 7772.99 7838.49 584.83 -212.69 -1294.68 38.47R 4.00 5.06 5940821.07 684736.59 N 70.24335993 W 148 .50782925 End CN 8103.19 30.55 329.72 7775.74 7841.24 586.44 -211.30 -1295.50 --- 4.00 5.06 5940822.44 684735.74 N 70.24336374 W 148 .50783585 THRZ 8160.39 30.55 329.72 7825.00 7890.50 615.38 -186.18 -1310.16 -- 0.00 5.07 5940847.18 684720.46 N 70.24343233 W 148. 50795431 BHRZ/TKUP 8396.12 30.55 329.72 8028.00 8093.50 734.66 -82.70 -1370.59 --- 0.00 5.10 5940949.13 684657.50 N 70.24371501 W 148. 50844250 TJC/LCU 8464.63 30.55 329.72 8087.00 8152.50 769.33 -52.63 -1388.16 --- 0.00 5.11 5940978.76 684639.20 N 70.24379716 W 148. 50858439 TJB 8738.68 30.55 329.72 8323.00 8388.50 908.00 67.67 -1458.41 -- 0.00 5.15 5941097.29 684566.00 N 70.24412578 W 148. 50915197 TJA 8865.26 30.55 329.72 8432.00 8497.50 972.04 123.23 -1490.86 --- 0.00 5.17 5941152.03 684532.19 N 70.24427756 W 148. 50941411 TSAG 8973.25 30.55 329.72 8525.00 8590.50 1026.69 170.64 -1518.55 --- 0.00 5.18 5941198.73 684503.35 N 70.24440706 W 148. 50963778 7" Csg Pt 8974.42 30.55 329.72 8526.00 8591.50 1027.28 171.15 -1518.85 -- 0.00 5.18 5941199.24 684503.04 N 70.24440845 W 148. 50964019 CN 10/100 9030.48 30.55 329.72 8574.28 8639.78 1055.65 195.76 -1533.22 HS 0.00 5.19 5941223.48 684488.06 N 70.24447568 W 148 .50975632 WeIlDesign Ver SP 2.1 Bld( doc40x_100) 06-21\06-21\Plan 06-21 B\06-216 (P6) Generated 6/5/2008 2:20 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Magl Grav DLS Directional Northing Fasting Latitude Longitude Depth Section Tool Face Difficulty n de de ft ft ft ft fi de de 1100 ft Index ftUS ftUS ISAU yVyU. 76 36.bZ 3ZY./7 C6L4.UV UOS'J.OV 7vCC.47 LC4.LL -704J.09 na Iv.uv a.w oyYlc~l.~c ooYY/v./Y /v /V.LYYJVJY/ YY /YO.:JV.700VV.`1 9100. 00 37.51 329.71 8631.86 8697.36 1094.35 229.34 -1552.83 HS 10.00 5.23 5941256.56 684467.63 N 70 .24456738 W 148. 50991474 9200. 00 47.51 329.70 8705.49 8770.99 1161.51 287.60 -1586.87 HS 10.00 5.30 5941313.96 684432.16 N 70 .24472654 W 148. 51018977 9300. 00 57.51 329.69 8766.28 8831.78 1240.39 356.01 -1626.86 HS 10.00 5.36 5941381.36 684390.51 N 70 .24491342 W 148. 51051280 TCGL 9393. 82 66.89 329.69 8809.99 8875.49 1322.90 427.58 -1668.69 HS 10.00 5.42 5941451.87 684346.92 N 70. 24510890 W 148. 51085078 Crv 6/100 9393. 85 66.89 329.69 8810.00 8875.50 1322.93 427.60 -1668.70 1.10R 10.00 5.42 5941451.89 684346.91 N 70 .24510896 W 148. 51085089 9400. 00 67.26 329.70 8812.40 8877.90 1328.57 432.49 -1671.56 1.10R 6.00 5.42 5941456.71 684343.93 N 70 .24512233 W 148. 51087400 9500. 00 73.26 329.82 8846.16 8911.66 1422.21 513.77 -1718.94 1.06R 6.00 5.46 5941536.79 684294.56 N 70 .24534434 W 148. 51125683 9600. 00 79.26 329.93 8869.91 8935.41 1518.83 597.75 -1767.67 1.03R 6.00 5.51 5941619.53 684243.77 N 70 .24557374 W 148. 51165057 BCGL 9675. 18 83.77 330.01 8881.00 8946.50 1592.79 662.11 -1804.88 1.02R 6.00 5.54 5941682.96 684205.00 N 70. 24574955 W 148. 51195117 9700. 00 85.26 330.04 8883.37 8948.87 1617.37 683.51 -1817.22 1.02R 6.00 5.55 5941704.04 684192.13 N 70 .24580800 W 148. 512 PO WC 9743. 97 87.89 330.08 8886.00 8951.50 1661.03 721.54 -1839.12 1.01 R 6.00 5.57 5941741.52 684169.29 N 70. 24591189 W 148. 512 End Crv 9744. 63 87.93 330.09 8886.02 8951.52 1661.68 722.11 -1839.45 -- 6.00 5.57 5941742.08 684168.96 N 70 .24591343 W 148. 51223051 Tgt 2 /Crv 6/100 10714. 56 87.93 330.09 8921.00 8986.50 2625.87 1562.27 -2322.85 91.90E 0.00 5.75 5942570.00 683665.00 N 70 .24820834 W 148. 51613691 2358 10741. 88 87.88 328.45 8922.00 8987.50 2653.07 1585.74 -2336.80 91.84E 6.00 5.76 5942593.12 683650.47 N 70. 24827245 W 148. 51624969 10800. 00 87.77 324.96 8924.21 8989.71 2711.08 1634.27 -2368.68 91.71 L 6.00 5.78 5942640.85 683617.41 N 70 .24840501 W 148. 51650731 10900. 00 87.60 318.96 8928.24 8993.74 2810.87 1712.93 -2430.23 91.47E 6.00 5.81 5942717.95 683553.94 N 70 .24861984 W 148. 51700468 End Crv 10998 .41 87.47 313.05 8932.48 8997.98 2908.14 1783.62 -2498.49 -- 6.00 5.84 5942786.93 683483.96 N 70 .24881290 W 148. 51755630 TD / 4-1/2" Lnr 11394. 79 87.47 313.05 8950.00 9015.50 3296.66 2053.93 -2787.89 --- 0.00 5.90 5943050.00 683188.00 N 70 .24955109 W 148. 51989479 Legal Description: Northing (Y) fftUSl Eastinn (Xl fftUSl Surface : 466 FSL 959 FEL S2 T10N R14E UM 5941065.63 686025.55 Target 1 : 893 FSL 2628 FEL S2 T10N R14E UM 5941451.89 684346.91 Target 2 : 2027 FS L 3281 FEL S2 T10N R14E UM 5942570.00 683665.00 TD / BHL : 2519 FS L 3745 FEL S2 T10N R14E UM 5943050.00 683188.00 WeIlDesign Ver SP 2.1 Bld( doc40x_100) 06-21\06-21\Plan 06-21 B\06-21 B (P6) Generated 6/5/2008 2:20 PM Page 2 of 2 by Schlumberger WELL FIELD STRUCTURE 06 DS DS06-21B (P6) Prudhoe Bay Unit - EOA - Ma0ne1~ Parae'~elers Surface Loweon NAD2i AlasYa 51a1e Planes. Zme 04, US Feel Mismllaneous Motley. BGGM 2f;~~] Dip 60.908° Dale: July 24, 1008 Lat N10 !a 38.169 NM111LIg'. 594106663 M1US Gntl OpnV: .1 <t411914° SIO1: 0611 TVO ReI: Rotary TaEle (fi550fla6ova MSL) Mag Dec: X23.100° FS'. 516804 nT Lon. W 148 29 50.545 Easeng: 666025.551105 Scale Fact 0.9999393111 Plan: 06116 (Pfi) Srvy Oala'. A°N 14. 2008 0 500 1000 1500 2000 2500 3000 3500 7000 7500 ~_ O O c 5000 u a~ m U 8500 9000 Tie-1n Survay ...............:. .... top Whipstock....................................................:...................................y..................................i..................................i..................................:............. ......................... :Base Whipstock KOP Crv 41100 t ..;. _.._.._.._..r.._.._.._.._.._.._. _.. ~~._.._.._.._.._.._.._.._;_.._.._.._.._.._.._.._..:._.._.._.._.._.._.._.._. _.._.._.._.._.._.._.._ _.._.._.._.._.._.._.._ ._.._.._.._.._.._.._.._ _ ._.._.._ End Crv r, ar. _.. _.. _. ._.._.._ _ ._.._.._.._.._.._. _ _ _ ._.._.._ ~~.~~.A_ _.._.._.._.._.._.._.._. _ _.._.._.._.._.._.._.._. _.._.._.._.._.._.._.._ _.._.._.._.._.._.._.. _ ._.._..=••_.._.._.._.._ _ ._.._.._ . _.. _.._ .F.._.._..-.._..-..-.. .i_ ._.._.._.. .TJB -a-..-....._.._.._.. _.._.._i. .. _.. _..-..-..-..... _.. ~.. ..-.._..-.. _..-.....- .-..-....._..-.....-.._.. ..y..-.. _..-..-..-....._.. .i- ._.._.. • TJA 7" Csg Pt i ~ - cry tonoo E _ ._.._ _ ._.._.._.._.._.._.._.._ _ ._.._.._ TSAG .._.. _.._..:.. _.._.._.._.. _.._.._.. :_.._.._.._.._.. _.._..-TSAR .. .._.._.._.._.._.._.. _:._.. _.._.. _.. _.._.._.._. _ _.._.._.._.._.._.. _.._ _.. _.. _.. _.. _.._.._.._ _ ._.._.._.. _.._.._.._.._ _ ._.._.._ Crv 61'f00 End Crv Tgt 2l Crv 61100 ~ TD 14112" Enr End Crv .......................... ......... ...... •:.»:. ..... .....::.::..::..::..:c.:. . 6-21 B (P6)i 6-21A 6-21 7000 • 7500 5000 8500 9000 0 500 1000 1500 2000 2500 3000 3500 Vertical Section (ft) Azim = 324.2°, Scale = 1(in):500(ft) Origin = 0 N/-S, 0 E/-V by ° ~ Schlumberger WELL FIELD STRUCTURE DS06-21B (P6) Prudhoe Bay Unit - EOA DS-06 Magnallc Parameters Surface LOCatgn NAD21 Kaska Stale Planes, ZOr~e 04.05 Feel Miscellaneous Mobel'. BGGM 200] Olp'. 60900' Dale: July 24. 3006 LaI: N)0 f430.t09 Norlbing 69410fibfi30U5 GnO GOnV' •161421924° Slot - TVD Rei: Rotary Table 165.500above MSL) Mag Dec'. •23.200° fS: 0ifi804 nT Lon: W1402950.040 Easlkg 60001555 ttU5 Scale Facl'09999393t t] 062 tB (Pfi) Srvy Dale. Apn124. 2000 '2800 -2400 -2000 -1600 '1200 2400 2000 1600 n 1200 n Z 0 0 C II a00 N (4 U V V V 400 0 -400 l00 100 )00 ?00 ~0 00 400 -2800 -2400 -2000 -1600 -1200 c« W Scale = 1(in):400(ft) E »> • Field: Prudhoe Bav -- Site: PB DS 06 Well: 06-21 Wellpath: Plan 06-21B ~,~_ ~., 0 IODo 2~0~ 3000 ~ooo 500 • 06-21/Plan 06-21B 600 ,~ ~ooo ~ ,, o jl goo _ - ~ - / l... \`~ q0~o -~., ~~~~0 i ~ ~o°° J. ,zo~° `- \OO~ O 06-21 106.2U - !?6-:1106-?IA1 _ Plan 06,?It3 -- ~O v0 ~G' O,-. ~~ -_~ CHK. CI(~'9d~jMAVif SZATE 714/62 soe NO. ~.r- • ~: T w ~~,v~sw~q~` ~- t~ ;•' •• '9 ~1 ''~ : ~+3 t rz ~ ~ • ~!~aarrN~y~ys~~sN•.~~•~•• ~ i Z'a tir~ ~~"~ ~ Xt'..~s-r~..s ~ e F'~,.r.+~~. {/ (~Af:Y A. CRENSNAIY : O F~ 4r~-~~p/R Ns. 1277-5 j~{t~~~v~ dd ~6~ b~~.N~.+~ r ~~~ESSJOt'l~l ~~ _ _ i _ - - ~ i i i- _ F, .' f ri ~ !'. C '-; i_. !_ ~~ T r '•{' i'1 .. i i _ ~ [ ~ +..i T - ~ - i 5 `! _ _ i _. -f y ~" :.~ ., _~ r . _ - - ! L T t_: E f•~ '=r E 7~~ f 1 Y' ~. f~ ~1 i 1 is C !"~ ;'': I-; L~~~•~ss=14i: ~:•~ ~~c~. =•,sr: _ __,'., :__~. = 37-OC TfaTG s -_ + - : ~ =-;ii=~~;E;'1~~+~ Ire '"4E ' , _ ~ } { ~ ( rfLF!=''.+1 lN~~1 L- T~HT Tr7L•J r'~['T - - `i~~t'i _~ 1~ ^~r~ .... }r _-;_ '."`: '1_rt'E'_-C;? 'ie{ H:_i-cuILT - _ ~ = r; ~ - •? '~ - . : , ~. r:• ~ _~ _. ~ ~ - 37. pG . -: s i i-' ~.' ~ ~°1;~ L+ E i - ti ~i E ~: ^I''i L~ T ~: E i_ i `. _ ~ i ::: _ _ L H _~ y 1 `_: i i ~_' r' k~ . ~ •-; T i t Fi : Fi t-~4 Li -i t-' Y T `i L ilt•1t~='=+:? _'~ - ... r;1;•!t<~-1'<<~~.•; 4; t•{[f ~~ T HEM' i.+~Tt=1?L`• ` H~'E ~_t=s~~=:ECT, i~~_ C+E ~ 7f27f82 L ; ~ :.} i~ = i '~' i= .: _" _. i '_" ~ _'a i _. =~ :. = :.. _ - ~ 7.05 _ {' ~.~:= ~:.: . ~ ~+.- - - - ~ .37.12 . -_.- ';'i .y ._. r= ,'LHt-~E ~' ~t~E ~• ... t,,T` -L_" ~ Y ~ r_- _ _ _ _ - . r•+1 ~_ _~' _;T+:"ire+r_:. Nr:E 'c•;_:r-a=~;_~ y SHEET :aN~~t~'~e3R ,~4•~5urt.T p.~S. rm/~!-2~• E ~r0 DIY ~Ir R ' '"-w ~ SuhSid~~r~ of Atlcsntic Richfield GomGony NORTH SLOP£ DRILLINCs-PRtif3HAE $AY LOGA'(kO fN PRO1trAGTE~' SBGS, 2tlt~'f fC~N~F{14r~ UMW'f M1RiD:~~N -____~It~IC6~11S1fT-~ trl~j3UI'~__- -- Company: BP Amoco Date: 6/5/2008 Time: 14:48:49 Page: 1 Field: Prudhoe Bay True Nortb 06-21 Well' di NI+; R f ~ __ , erence: . nate( ) e o-or i Reference-Site: PB DS 06 Reference We1L 06-21 Vertical (TVD) Reference: 06-216 Plan 65.5 Reference Wellpath: Plan 06-21 B Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are [T~iiHneells in thisilhiidlpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Itang~300~~ ot'Yt39~79-ft-- _ Scan 1Vfeth~d:- TTav Cylirrd~r Rtort~ - - Maximum Radius: 1336.63 ft Error Surface: Ellipse + Casing Survey Program for DeSnifive Wellpath Date: 6/26/2006 Validated: No Version: 1 _.__ i PlannEd~a'9tn-T-0-__.___.__S{IXyg 7 _____- Tnnlrndg __. T~nl Nang __ - ~ ' ft ft _ - _ _ __ ---- - 91.50 __ 7291.50 __ 1 : Camera based~c yro multisho CB_GYRO-MS ____ Camera based gvro multishot_ _ ~ _ 7291.50 7600.00 Planned: Plan #6 06-21 B V1 BLIND Blind drilling 7600.00 8910.00 Planned: Plan #6 06-21 B V1 MWD+IFR+MS MWD +IFR + Multi Station -- 811$00- 1 X394-.7~~r~.,••ned._Plan ucro 00 ~fi6-~fi MWD'-'r~, o_„o~~"ec._ MAID-}IFR+ MultiStatien Casing Points - _ _,._ _ NID TVD Diameter Hole Size Name ft ft in in - - _ 2501.50 2501.41 13.375 17.500 13 3/8" 7300.00 7097.70 9.625 12.250 9 5/8" _.._-88935852F~01..__._.7:000 8.500- 7" - -- ~ - 11394.79 9015.50 4.500 6.125 4 1 /2" _ __ _ ummary <----- Offset Wellpath -> Reference Offset Ctr-Ctr No-Go Allowable -- _ ~ Site Well Wellpath MD MD Distance Arcs Deviation Warning -- tt ft ft ft ft - -PB DS o^^~~~6-01-- _. _ --06-01-V1 - - OuLef range- - -- PB DS 06 06-02 06-02 V1 Out of range PB DS 06 06-03 06-03 V1 Out of range PB DS 06 06-03A 06-03A V1 Out of range PB DS 06 06-04 06-04 V1 7300.00 7460.00 1201.84 257.49 944.36 Pass: Ma or Risk Risk __' 10 ___ - 7300.00_.. 7465.00 __1202.50 257.56 944.94 n _ ge Out of ra PB DS 06 06-05 06-OS V1 !, PB DS 06 06-06 06-06 V16 Out of range B-DS ^~~06~6- 06-06/~~3----- ---__- - Oe-t~range--~ _ PB DS 06 06-06 06-066 V4 Out of range PB DS 06 06-06 06-066P61 V8 Out of range ' __ PB DS0606=07 _ --- U6=07 V7 u o range - PB DS 06 06-08 06-08 V1 Out of range PB DS 06 06-08A 06-08A V1 Out of range PB DS 06 06-11 06-11 V10 Out of range j PB DS 06 06-12 06-12 V7 Out of range _ _ - B-0S 06- 06 '- ~ ~-_ ._--~6-'F2 n ~,.s„~ -- - but oFrange PB DS 06 06-13 06-13 V2 Out of range PB DS 06 06-13 06-13A V3 Out of range - -- ~ PBDS 0~-0G=fi3 __-- _-06=fi3APBfiV13 _ _- ~utofrange _ I PB DS 06 06-14 06-14 V1 Out of range i 06_14A V1 -_ __ _ Out of_range 06 06-14A PB D$ fi_ _ ___ -___ - PB DS 06 06-14 Plan 06-14B VO Plan: P Out of range PB DS 06 06-15 06-15 V1 7300.06 7550.00 1250.22 180.89 1069.33 Pass: Major Risk it - 6 E3S-06 ~6-'I6 -___ 06-16 V'~ -X1087.28 9940~~1'FO7:5^0 ~0°:°8597:52 ~a°^: "~~ -~o ajor °is~- - - _ PB DS 06 06-16 Plan 06-16A Contingenc 11297.94 9450.00 814.78 68.64 746.14 Pass: Major Risk ~ '' PB DS 06 06-16 Plan 06-16A VO Plan: 0 11297.94 9450.00 814.78 68.64 746.14 Pass: Major Risk PB DS 06 06-17 06-17 V11 Out of range PB DS 06 06-18 06-18 V8 Out of range PB DS 06 06-19 ____ 0t-19 V2 Out of range__ _ - _- -- ---- ___ PB DS 06 06-19 Plan 06-19A V3 Plan: P Out of range T PB DS 06 06-20 06-20 V3 Out of range _ PB a~06~6-2a -- - os-28A-u~--- _ -- - - su~~fatge- - PB DS 06 06-21 06-21 V5 7311.50 7320.00 0.14 67.09 -66.95 FAIL: Minor 1/200 PB DS 06 06-21 06-21A V6 7311.50 7320.00 0.14 67.09 -66.95 FAIL: Minor 1/200 ! _ _ _ _ -06_ -06=2T _-- 06-12/1._ Ou o range -_ PB DS 06 06-22A 06-22A V1 Out of range 06-23 V1 Out of range I PB DS 06 06-23 ~ _ ___ - - - - - - - - - -- PB DS O6 06-23 06 23A V1 Out of range _ ___- _.. --_- -- __ __- ~ IS1IITr~~1IIi'~-- -_ _- - ---- -- Company: Field: Reference Site: BP Amoco Prudhoe Bay PBDS O6 Date: 6/5/2008 Time: 14:48:49 Page: 2 Co-ordinate(NF,) Reference: WeIC 06-21, True North - -- --- Reference Well: 06-21 Reference Wellpath: Plan 06-21 B Vertical ('l'VD) Reference: 06-21 B Plan 65.5 Ub: Orade - - Summar~~ <~ -- _ Site PB DS 06 PB DS 06 _-P-B nc na _._.. PB DS O6 PB DS 06 -~_ PB~1~ _ Offset Wellpath Well 06-23 06-23 __- na_23 06-24 06-24 ~i4=33 -> Wellpath 06-236 V2 06-236P61 V1 __ __~Iar~4r06-23C., a/n~ ? 06-24 V1 06-24A V1 __~~33 err- Reference -.Offset Ctr-Ctr No-Go Allowable - MD MD Distance Area Deviation Warning ft ft ft ft ft _ _ _ _ Out of range Out of range !an --- -- - ---___~ut of.range _...- 10850.00 9510.00 846.95 406.68 440.28 Pass: Major Risk 11300.75 9780.00 701.69 380.76 320.93 Pass: Major Risk - - -©ur~trar,~~ - --- _ - - -, i ~ -- '_ _ --- -r --- - -- -- FieldPrudhoe Bay; ____ ~' ~ SitePB DS 06 i We11:06-21 Wellu~thPlan~~2. - -- i - --- - -- ~ ! From KOP to TD ~ - - _. -~ - can inter- va~ ~00-~~~-- i ~Scale 1:100 -- ---- -- ~ -- 31 3 0 300 300 3 0 200 200 3 0 0 100 100 0 2 75 9U 76 77 78 100 1g~ 2 0 7s 20 so 200 2 0 81 2 5U 82 300 300 ~ ~ .3--__ -0-fr 2-~l~} Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre ______ _._.-bite: P~b~~_ X1.:5101.1 n1 ~.L.LUl~~.- - -- ._____ - ~ a~ ~onf.: 95°T _ - - -- on: anne grogram escnphon: ertlca ept a ow can ea eve ap o mg: T74~.00 ~ - Local +NTS:-722.03 ff - -_- --- atltu e: ongltu e: _.. -~ Ygon X-ft - - _ - ~f~ _- __ -- -Map E ~ ~1CIap ITT ~ r.. - -- 2 --- -~ -- -- -- -72.30 -38fr8C~ -- _ - --_ -5257 _ - 474.96 ~0~88 ~i8473~6~ - 684085.00 6£~3%000- - -----394T23~60 5942215.00 -~942fr35:00 - _-- __4 __-_ ~06T~ ~385:~6_. -__. _ ~3~0~6 3~433T0.~~ _.__.~- --X08595-- ----____-L335~3~_-_ __ .68303x:60 ~9~3076:06--- -. - -~ ~'70~~ _ _ 76735 _ ~83380.0~ -- ~942493.0~ - - _-~ -13~6~ _ _ - ~T:79 - ~846T~6~ ~~3~I78~ 0~ ___~_ -~~3~~- _ -7203_.- -- - b84310~0~ ~4102~~0~ -, - . -- I60 ~--2~0- 0 0 0 0 0 -- _ - _ ~I - 2000 -~00 - -800 0 Alaska Department of Natural~ources Land Administration System Page 1 of ~ ~ y- .~ _ ,..,..,_,. ,, ~ rz ~G~r~;a, ~.....rr;h State Cabans tt1 ~ ~['~~s _. A[a~a DNR aye Summary 1..AS Menu I Case Abstract I Case Detail I Land Abstract ~, Filer: ADL 28311 Search fir Stratus Plat updates As of 0(,` 12 2Oi1S Cnslonaer: 000107377 L3P EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 966 1 2 Case Type: 7€ ~ O(L & GAS LEASE COMP DNR Unit. 780 O[L AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 fSSUED Status Date: 08/19/1965 TotulAcr~es: 2560.000 Dute Initiated: 05/28/1965 Office of Pf~in7ar.v Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case S'ubhpe: i NORTH SLOPE Last Tj~uras~action: AA-NRB ASSIGNMENT APPROVED 1Vferidiarz: U Toti~nship: O l ON IZcmge~ 014E Section: O 1 Section ~cr, ~_~ 640 iearch Plats ~l'Leridicrn: U Totirjz~~l~i~>.~ OION Ran~r~.~ OI-~L. Section: 02 ti~~~~~~ion'flcres: 640 l~leridrni.~ l_I Tot~rrr~/rr~~. OION R~nic.~ 014E 5~~~~rion: 11 ti~~~~iion acres: 640 ~Llcridic«r.~ l~ To~rn~~hii>: OION l~~n~~c~: 014E .~~°~~lirut~ 12 ti'c~~iiortAcres: 640 Legal Description 0?-Z~S'-1 J6? ***SALEa'`OTICELEG<1LDl.'S'C'RIPTIOA'*** C1-i-132 lONIdE UM 1, 2.11,12.260.00 ~~'-3-7 Last updated on 06/12/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28311 &... 6/12/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~/~~ O,~ ~l~ PTD# 0~0~0~' 90 ~Developmetrt~ Service Exploratory Stratigraphic Test Non-Conventional Weil FIELD: f.el/D.~DE ~s~y POOL: _ f ~~E' _~,Qy 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. AP[ 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 contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed me~liane is not allowed for (name of welt) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Company Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 1/112008 WELL PERRNIT CHECKLIST Field & Pool PRUDHOE BAY, PRUGHOE OIL -640150 Wefl Name: PRUDHOE BAY UNIT 06-21A Program DEV Welf bore seg ^ PTD#:2080990 Company BP EXPLORATION (ALASKA) INC Initial Classll'ype DEV I PEND GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Permit feeatiached---- ----------- -- - --- --- ---- NA--- -- -- - -- ---------- - - - - --- ------ --------- 2 Lease numberappropn;3te - -- - -- -- -- -- -- --- -Yes---- - -- -- - ----- - - -- --- - - - - 3 Unique well-name and number------------ - -- -- -- ---- - Yes-- -- ------------ - - - -- ------------- - - - ------------- 4 WelUocatedin.a-de__finedpgol - ---------- ---- -- -- -- -Yes--- - - - - - ---- ----- -- -- -- ------ - 5 WelUocatedptoperdistancef[omdrillingunit_boundary_______________ _________Yes-_--_ --__-------____--_- ------------------------------------------------- 6 Well locatedptoperdistancefromotherwells__-____--_--.----- --- Yes----- ---------------------------------------------------------- _---- 7 Sufficient acreageayailableindrillingunit_________________-___- -______--Yes----- --2564acres.__-----_---_--__---_______--__-__--__--_____--_______-- 8 If-deviated,iswellboreplat_included----------- - ------ ---- --------Yes----- -- -- - - --------- - - - - -- - 9 Opetatorgntyaffectedparq~----- -- --- --------- - - -- -------Yes ---- -- -- - ----------- - -- -- -- ----- - 10 Opetatorbas_appropriatebo_ndinfQrge______-_.__._--.______ _______Yes_.___ ._BlanketBond#6184193.____---..-. 11 PermitcanbeissUedwltboutgonsa~YatignordQr- -- ------ -- ------ Yes -- - - - ~--- --- -- -- ----- -- -- -- --- -- -- -- -- -- Appr Date 12 Permitcanbaissuedwfihoutadministtative_approval_-_------------ ---------Yes----- ----------------------.----------------------------------------____-- ACS 611212008 13 Can permit beapRroved4efgre15-day-unit---------------------- ---------Yes----- ------------------------------------.-------.----------------------- 14 Well located within area and strataauthgrizedbyinjectionOrder#(put_10#in_commenis~(For-.NA.___ ------------------------___--_----______-__--__--___------_--_--- 15 AilwelJs-withinll4-mileateaofreyietividentifiad(ForserviceaieUgnly)_____ _________ NA______ ____--_.-___-______--______-___---_--,_----------_ ------------------ 16 Pte-producedinlectgr; duration ofpre,produotionlessthan3months-(Forservicawellonly)_-_NA____ _________________________-_---______________-__--_---._._-.___.--- 17 Nonconyen,gas-cgnfgrmstoAS31,05.03Q(L.1.A)~(1~2.A•D) -- --- -- --- --- ~------ --- -- -- - -- - ---- --------- -- - -- -- --- ---- Engineering 16 Conductorsuing-prgvided-------------------------------- --------- NA_____- __ConductorsetinpS06.21(1$~•127).----------------,--------------------____-- 19 SudacecasingprotectsallknquvnU$DWS--------.--.------- ------.-NA-_---- --NOaquifers,A1046,_conrlusion5,______________________________________________ 20 CMTvoladequate_tqGrculateon_cgnductgr8surf-csg_______________ _________ NA---_-- -_SurfacecasingSetin06r21,__-___-___,___-______--__.-_--_--------------_-- 21 CMT vol adegUate_tq tie-in long siring to surf csg- - - - - - - - - - - - - - - - NA_ - _ Production_casing set in 06,21._ _ - _ _ . _ - _ _ - _ , 22 CMTwipooyeraNkoownproductivehonzons-------------____- _--_-___Yes----- ---------------------------...-----------------------------.-- .. 23 Casingdes~nsadequatefo[C,T,i3&_permafLost------------------ ---------Yes----- - - ----------..-_- -- --------------------------------------------------- 24 Adequate tankage_orreserye pii - - - - - - - - - - - -- - - - _ - - - - - - - - - - - - - - - - -Yes - - _ - - - _ Rig equipped with steel pits, No reserve pit planned.- All wasle_to approved disposalwell(s), - - - _ - - - - - - _ - - 25 Ifa_re~lriil,has_a'10.403torabandonmeatbeenapproved------------ -------Yes---- --308,177---------------------,---------------------------------- 26 Adequake_wellkor@ separationpropgsed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - _ - - - _ Proximity analysis performed, Nearest segment is P$~A pgrti4n of 06.21A and_paths diverge. _ _ _ _ - _ _ _ _ _ _ _ _ 27 If diverfQr_raquirad, does itmeet reg4latigns- - - - - - - - - - - - - - - - - - - - - - - - - - - -NA- . _ _ - _ _ BQP staCk_wiil al[eady-be in place, _ .. - _ - _ _ _ _ - _ _ - Appr Date 1 28 Drilling f)uid program schematic_$equip listadequate- - - - - - - - - - - - - - - - - - - - - - - - -Yes - - _ - _ _ -Maximum expected fo[mation pressure 7,1_EMW.- Planned MW 1Q.$ ppg in $-112" hole and_8.5 ppg in zone.- TE 611312008 29 ROPES, dotheymeetregulation__.-------------------- -----__--Yes----- ---------------------------------------------------------- ___-- 30 BODE-press rating appropriate; test to_(puf prig in_cgmmgnts)- - - - - - - - - - - - - - - - - - - -Yes - - _ - - _ - MASP calculated at 2363psL 3500_psi_BOP testplanned. - - - - - _ - - - - - - - - - - _ - - - . _ - 31 Chgke-manifcldgomRlieswlAPl_RP-53(May$4)----------- - ---- -Yes - -- -- ----- ----- - - ------ ---------- _- 32 Work will occur withqutoperalonshutdown____-____-______ __- Yes----- --------------------------------------------------------_----____-- 33 Is presence of H2$ gas prgbable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - - _ _ - H2S is repgrlad_at DS 6. Mud shouki_preclude H2S on rig. Rig has sensors and alamis, _ _ - - _ - . _ _ _ - - _ - _ 34 lulechanical condition of wells within AQR verified (Fqr service well gnty) _ _ _ _ _ _ _ _ _ _ _ _ _ _ tJA- _ ---- ---------------------------------------------------------------------- Geology 35 Pe[mitcanb8issuedwlohydrogansulfidameasures________________ ___-____ No-___-_ -Maxl.eyelH2SonPad150ppmforwellOCr13_(~19104j,___________-__-_-_-_-______________ 36 Data.Rrasenfedonpotentialgverpressutezones------------------- ---------Yes----- --------------.----------------------------------------------------- Appr Date 37 Seismic analysisofshallgwgaszones___________-____--__- __---__-- NA------ -------------------------------------___--- ------------------------- ACS 611212008 38 Seabed.cgnditionsun_rev-{if4~-sho[e)----------------------- -------- NA------ ---------- 39 Contactnamelphoneforweekly_prop.rasa[epgrts[exploratorygntyj________ _________Yes-_--_ --Eleazar"Eli"-Vazquez-564-591$.-___-__-___-__________-------------_---_-_-.-- Geologic Engineering D : Date t Date Commissioner: a e Co missioner. om is er ~ ~ ~3 ~ ~-~3-a8' ~-