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207-109
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU K-08B Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-109 50-029-21408-02-00 13108 Conductor Surface Liner Liner Liner 9053 2642 10358 432 746 3156 13069 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 9047 31 - 2673 29 - 10387 10133 - 10565 9988 - 10734 9951 - 13107 31 - 2673 29 - 8697 8475 - 8853 8349 - 8977 8317 - 9052 13043, 13047 2670 4760 5410 10530 11780 None 5380 6870 7240 10160 11200 11109 - 13065 5-1/2" 17# L-80 26 - 10049 9048 - 9046 Structural 80 20" x 30" 31 - 111 31 - 111 5-1/2" TIW HBBP Packer 9914 8285 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907-564-5026 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028299, 0028300, 0028303 26 - 8402 N/A N/A 201 374 19086 29910 34 228 600 650 1160 1140 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 9914, 8285 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:57 pm, Jun 24, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.24 14:13:38 - 08'00' Torin Roschinger (4662) JJL 6/30/25 RBDMS JSB 062725 ACTIVITY DATE SUMMARY 6/16/2025 CTU#1 1.5" CT. Job Scope: Mill CIBP MIRU CTU. Function Test BOP's on well. Pressure Test PCE 300psi Low / 4400psi High. Test DHCV's. Good Surface Tests. RIH w/ Baker 1.69" Milling BHA with 1.80" 3-Bladed Junk Mill. Tag high at 11280'. Mill through restriction easily. Dry Tag CIBP at 12053' ctm (12050' md). Begin milling on CIBP ***In Progress*** 6/17/2025 CTU#1 1.5" CT. Job Scope: Mill CIBP Continue Milling on CIBP at 12053' ctm (12050' md). Mill on CIBP ~ 2.5hrs before plug let go. Mill/push plug down to 13043' ctm / 13055'm. Quit making progress and seeing overpulls. Discuss w/ OE and decide to call this depth good. Pooh. Pump 133 bbls of diesel down the backside to preserve gas cap and underbalance tubing while POOH. Ball Recovered. Complete weekly BOP test. Rig down CTU. ***Job Complete*** Daily Report of Well Operations PBU K-08B 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU K-08B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-109 50-029-21408-02-00 13108 Conductor Surface Intermediate Production Liner 9053 2642 10358 432 746 3156 12050 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 9045 31 - 2673 29 - 10387 10133 - 10565 9988 - 10734 9951 - 13107 31 - 2673 29 - 8697 8475 - 8853 8349 - 8977 8317 - 9052 13000, 13047 2670 4760 5410 10530 11780 12050 5380 6870 7240 10160 11200 11109 - 13065 5-1/2" 17# L-80 26 - 10049 9048 - 9046 Structural 80 20" x 30" 31 - 111 31 - 111 5-1/2" TIW HBBP Packer 9914, 8285 9914 8285 Torin Roschinger Operations Manager Kirsty Glasheen kirsty.glasheen@hilcorp.com 907-564-5258 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028299, 0028300, 0028303 26 - 8402 N/A N/A 322 1030 32375 5023 26 468 700 550 1080 200 323-512 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 11:38 am, Jan 24, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.01.24 10:59:37 -09'00' Torin Roschinger (4662) WCB 7-3-2024 RBDMS JSB 013024 ACTIVITY DATE SUMMARY 1/16/2024 LRS CTU #1 1.5" Blue Coil Job Scope: Set CIBP and Extended Adperfs Move from F-10. MIRU. Pull Test CTC 23k. PT MHA 3600 psi. MU HAL GR/CCL. NU BOP. PT 250/4000 psi. RIH w/ NS 1.69" CTC, MHA, 4' stinger, HAL GR/CCL, 1.75" Nozzle. OAL 14.3'. Unabe to snub in w/ 2400 psi WHP. Bullhead 130 bbls 1%, 5 bbls MW, and diesel freeze protect to 2200'. WHP 650 psi. Start RIH After WHP dropped to 1800 psi. Drift to 12,200'/ Log up @ 50 fpm to 10800'. Stop and paint EOP flag @ 12,001'. Tools stopped recording at 9250' RIH. Rerun new logging BHA. Log from 12300' to 10500'. Paint flag at 12000'. POOH. Had a repeat failure. The tool failed while sitting on bottom prior to lgging the up pass. Call out READ services. Make up and RIH with READ lgging tools with 1.75" nzl drift. Log from 12300' - 10500'. Flag pipe at 12002'. POOH. Recieve good data, minus 18' correction approved by OE and GEO. Make up and RIH with NS 2-3/8" CIBP. ***Continuied on 01/17/24*** 1/17/2024 CTU LRS #1 1.5" Blue Coil Job Scope: Set CIBP and Extended Adperfs ***Cont. from 1/16/24*** Continue RIH w/ CIBP. Bullhead well kill from 5 to 4 bpm to keep WHP <2400 psi. Pumped 360 bbls 1% and 58 bbls 60/40 to FP to 2500'. SD pump and continue RIH from TOL. Tie to Corr. EOP Flag and Set 2-3/8" NS CIBP @ 12,050' Corr. MD. PT CIBP 1128 psi 10 mins - no loss. POH. Fill pipe displacement w/ 60/40. Flow check well. Start trip sheet and top fill w/ 60/40. PJSM and Well Control Drill. MU and RIH w/ 1.69" CTC, MHA, Swivel and 99.8' 1.56" Gun assy (79' loaded) OAL 103.6'. Returns to trip tank. Tie-in to 11799.4 EOP Flag. Tag CIBP @ 12050' and corr -.7' to bttm shot = 12049.3'. Park Bttm shot @ 11983' and shoot 11899 to 11953' and 11958' to 11983'. Check injectivity ~.2 bpm @ 300 psi. POH and fill pipe displacement across top w/ 60/40 Losses ~ 14 bbls/Hr. Lay down gun #1 - all shots fired. Deploy gun #2. Loss rate dropped to ~5bbl/hr. RIH with 459' of 1.56" 6SPF SLB Powerjet perf guns (248' loaded for 3 intervals). Perforated 79' 11899' - 11953' and 11958' - 11983'. 1.56" PowerJet 6 SPF 60* Phasing ***Job Continued on 1/18/2024*** 1/18/2024 CTU LRS #1 1.5" Blue Coil Job Scope: Set CIBP and Extended Adperfs ***Cont. from 1/17/24*** Continue RIH w/ 459' of 1.56" 6SPF SLB Powerjet perf guns (248' loaded for 3 intervals). Tied into flag and perforated 248'. 11109-11207, 11221-11272, & 11461- 11560 1.56" PowerJet 6 SPF 60* Phasing. POOH pumping pipe displacement. Circ out 50bbl of freeze protect to maintain overbalance. Circ 60/40 across top while LD guns losses ~8 bbls/hr. MU and RIH w/ 1.69" CTC, MHA, (2) 4' x 1.75" stingers, and 1.75" nozzle OAL 10.9'. Lay in diesel from 10800 and POH. SITP 195 psi after POH. Flow well to tank. Well showing steady production at 210bpd. Well status relayed to OPS. Decision to POP tomorrow on day shift with additional manpower (manning the well in LP). No N2 available for 24 hours. RDMO. ***Job Complete*** Daily Report of Well Operations PBU K-08B CIBP and adperf depths are correctly shown on the new WBS, below. -WCB jg( perforated 248'. 11109-11207,11221-11272, & 11461- 11560 g g@ Park Bttm shot @ 11983' and shoot 11899 to 11953' and 11958' to 11983'. Set 2-3/8" NS CIBP @ 12,050' Corr. MD 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU K-08B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-109 50-029-21408-02-00 341J ADL 0028299 13108 Conductor Surface Intermediate Production Liner 9053 2642 10358 432 746 3156 13069 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 9047 31 - 2673 29 - 10387 10133 - 10565 9988 - 10734 9951 - 13107 2616 31 - 2673 29 - 8697 8475 - 8853 8349 - 8977 8317 - 9052 13000, 13047 2670 4760 5410 10530 11780 None 5380 6870 7240 10160 11200 12120 - 13065 5-1/2" 17# L-80 26 - 100499045 - 9046 Structural 80 20" x 30" 31 - 111 31 - 111 5-1/2" TIW HBBP Packer No SSSV Installed 9914, 8285 Date: Torin Roschinger Operations Manager Kirsty Glasheen kirsty.glasheen@hilcorp.com 907-564-5258 PRUDHOE BAY 9/22/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:13 pm, Sep 08, 2023 323-512 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.09.08 12:06:29 -08'00' Torin Roschinger (4662) 10-404 , ADL0028303, ADL0028300 SFD MGR22SEP23 SFD 9/13/2023 DSR-9/12/23*&: JLC 9/22/2023 09/22/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.22 13:01:54 -08'00' RBDMS JSB 092223 CIBP & Ext AdPerf Well: K-08B Well Name:K-08B API Number:50-029-21408-02 Current Status:Operable – SI Cycle Off Pad:K-Pad Estimated Start Date:10/01/2023 Rig:CTU Reg. Approval Req’d?10-403 & 10-404 Date Reg. Approval Rec’vd:TBD Regulatory Contact:Abbie Barker Permit to Drill Number:207-109 First Call Engineer:Kirsty Glasheen Contact:907-350-4310 Current Bottom Hole Pressure:3496 psi SBHP – 5/23/2019 MPSP:2616 psi (BHP - .1psi/ft gas gradient) Bottomhole Temp:173 deg Max Dev:96 deg At 12,506’ MD Min ID:1.941” ID 3-1/2”x2-3/8” XO at 9,964’ MD Brief Well Summary: K-08B is currently a cycle well at K-Pad. The well had a mill plug job completed in November 2022 that did not improve well performance greatly. We would like to set a CIBP to shut off current production and add perforations up hole. The well was drilled within the HOT, so some of the add perfs will be within the HOT and are expected to be lower GOR than current perfs. K-08 does not have gas lift mandrels, so after the extended add perf, plan for contingent N2 lift as needed. Objective: The purpose of this procedure is to isolate current perforations and perforate uphole to increase rate and lower the well's TGOR. We may need N2 lift to kick off the well after the extended perforations are shot. NOTES: x Well does not have gas lift mandrels. It can only be kicked off by backflowing or allowing to stack out. Coil milled a CIBP on 11/4/22 and loaded the well with 275 bbls KCL. The well was able to kick off without N2 after this job. However, the perforations we are shooting during this rig up are expected to be lower GOR, so there is a risk K-08B will not kick off without the use of N2. Prepare for a contingent N2 kick off as needed. x Needs 1.5” CT. Procedure: Coil Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. Prior to MIRU coordinate with operations to roll K-08B to LP for kick off. 2. MIRU 1.5” CTU 3. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannotpull through the brass upon POOH with guns. 4. RIH with GR/CCL & 1.8” nozzle to ~12,120’. PUH and paint flag for plug/perfs depths. 5. POOH. CIBP & Ext AdPerf Well: K-08B 6. Bullhead ~359 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time before setting CIBP andprior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 239 bbls b. 5-1/2” Tubing/Liner – 9913’ X 0.0232bpf = 230 bbls c. 2-3/8” Liner – 3156’ X 0.0039 = 12 bbl 7. MU 2-3/8” CIBP. RIH and set at ~12,050’. PT to 1000 psi to confirm good set. POOH. If PT does not pass, it could either be LTP or CIBP that is leaking. Call OE to discuss best way to diagnose this. We may decide to move forward with perfs and troubleshoot plug/LTP later. 8. Prepare for deployment of TCP guns. 9. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 10.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 11.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule *1.56” guns were used to estimate gun weight for this job (5 ppf) *Tie-In Log: PDS Coil Flag 9/26/2010. This log is on depth with reference log. No depth shift required. Run #1 Perf Interval Perf Length Gun Length Weight of Gun (lbs) 11899’-11953’ MD 54’54’270 lbs 11953’-11958’ MD 5’25 lbs 11958’-11983’ MD 25’25’125 lbs Total 79’84’420 lbs Run #2 Perf Interval Perf Length Gun Length Weight of Gun (lbs) 11109’-11207’ MD 98’98’490 lbs 11207’-11221’ MD 14’70 lbs 11221’-11272’ MD 51’51’255 lbs 11272’-11461’ MD 189’945 lbs 11461’-11560’ MD 99’99’495 lbs Total 248’451’2255 lbs CIBP & Ext AdPerf Well: K-08B 12. RIH with perf gun and tie-in to coil flag correlation, consider tagging the CIBP if there is any discrepancy with depths. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 13. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 14. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. Attempt to minimize fluid pumped during this step to enable easier kick off. 15. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 16. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 17. RIH and circulate diesel from 10,800’ MD to surface (~234 bbls) taking returns up the back side to enable and easier kick off. 18. Coordinate with operations to POP well to LP production.Stand by while operations attempt to POP well. Allow ops to rock well as needed for kick off. 19. If Ops is not successful kicking off well, confirm injectivity to perforations (if not already done). If well has injectivity, prepare to N2 lift. a. RIH to ~1500’ pumping N2 @ ~500 scf/min. Wait for 1-2 hours while continuing to pump N2. Keep working downhole in 500’ increments until the well begins to flow. b. Do not go below ~7500’ MD with N2 to prevent a collapse scenario of the tubing. Collapse calculations are attached. c. Once we have recovered the returns volume and the WHT ~90 degrees, shut down the N2 and see if the well will continue to flow naturally. Monitor for at least 2 hours before RDMO. If the well is not flowing on its own at this point, reinstate the N2 and call OE to discuss plan forward. 20. RDMO once well is confirmed to be able to sustain natural flow. Attachments: x Current Wellbore Schematic x Proposed Wellbore Schematic x N2 Collapse Calculations x CT BOPE Schematic x Standing Orders x Equipment Layout Diagram x Tie-In Log x Sundry Change From Make up PCE. -mgr CIBP & Ext AdPerf Well: K-08B Figure 1: Current Schematic CIBP & Ext AdPerf Well: K-08B Figure 2: Proposed Schematic CIBP & Ext AdPerf Well: K-08B Figure 3: N2 Collapse Calculations CIBP & Ext AdPerf Well: K-08B Figure 4: BOP Schematic CIBP & Ext AdPerf Well: K-08B Figure 5: Extended Perforating Standing Orders CIBP & Ext AdPerf Well: K-08B Figure 6: Extended Perforating Equipment Layout CIBP & Ext AdPerf Well: K-08B Figure 7: Tie-In Log Header CIBP & Ext AdPerf Well: K-08B Figure 8: Perf Tie-In Perf 11,109’- 11,207’ MD Perf 11,221’- 11,272’ MD CIBP & Ext AdPerf Well: K-08B Figure 9: Perf Tie-In Perf 11,461’- 11,560’ MD CIBP & Ext AdPerf Well: K-08B Figure 10: Perf & CIBP Tie-In Perf 11,899’- 11,953’ MD Perf 11,958’- 11,983’ MD CIBP ~12,050’ MD Hi l c o r p N o r t h S l o p e , L L C Hi l c o r p N o r t h S l o p e , L L C Ch a n g e s t o A p p r o v e d W o r k O v e r S u n d r y P r o c e d u r e Da t e : S e p t e m b e r 8 , 2 0 2 3 Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l K - 0 8 B Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a t e d t o th e AO G C C b y t h e w o r k o v e r ( W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . St e p Pa g e Da t e P r o c e d u r e C h a n g e HNS Pr e p a r e d By ( I n i t i al s ) HN S Ap pr ov e d By ( I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e PROACTIVE DIACINGsTIC SERVICES, INC. ji S-11. WELL LL7'ta TRANSM/TTAL To: AOGCC Natural Resources Technician 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907)793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Production Profile 2) Signed Print Name: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2 — 1 900 Benson Blvd, Anchorage, AK 99508 GANCPDCC(_i USAANC hou xwh BP com and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 24-Mav-19 K-rRR rn r r• 30 94 3 RECEIVED JUL 0 3 2019 AOGCC 50-029-21408-02 Date : D V00�— PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2453952 E-MAIL: PDSANCHORAGE(M.MEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM 6Wahiv:a`MesNpemplataFiles,Templates\pisVibation\TronsmilffiIShecb,BP Tmnsmit.doox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y Anne Prysunka at 9:07 am, Nov 15, 2022 RBDMS JSB 111722 DSR-11/15/22WCB 11-26-2024 $&7,9,7<'$7(6800$5< /56&78%OXH&RLO -RE2EMHFWLYH 0LOO&,%3 0,58&780DNHXS0LOOLQJ%+$ZLWKEODGHGMXQNPLOO &RQWLQXHGRQ:65 /56&78%OXH&RLO &RQWIURP:65 -RE2EMHFWLYH 0LOO&,%3 5,+ZLWK 0LOOLQJ%+$ZLWKEODGHGMXQNPLOO%HJLQPLOOLQJ&,%3DW &70' 0' 3XVKHG&,%3WR FWP PGXVLQJ FRUUHFWLRQRIIFLESWDJ )UHH]HSURWHFWHGZLOOZLWKEEOGLHVHO -RE&RPSOHWH 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8.% CIBP fish is correctly shown on the WBS below. -WCB M 5,+ZLWK 0LOOLQJ%+$ZLWKEODGHGMXQNPLOO%HJLQPLOOLQJ&,%3DWJMJJ &70' 0' 3XVKHG&,%3WR FWP PGXVLQJ FRUUHFWLRQRIIFLESWDJ STATE OF ALASKA 6i ,.,. L 1 V ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WFI I naFReTInIdS 1. Operations Performed , Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend 111 Perforate 11W Other Stimulate ❑ -�' Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Change Lmer Top Packef0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-109 3. Address: P_O. Box 196612 Anchorage, Development 0 Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-21408-02-00 7. Property Designation (Lease Number): ADL 028299 8. Well Name and Number: PBU K-088 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Size: MD: TVD: Burst: Conductor 80 Total Depth: measured 13108 feet Plugs 9 measured 12600 feet 31-2673 true vertical 9053 feet Junk measured 13000 feet Effective Depth: measured 12600 feet Packer 7240 Liner 754 3-1/2" x 3-3/16" 9980-10734 8342-8977 10160 Liner measured 9914 feet 8317-9052 true vertical 9036 feet Packer true vertical 8285 feet Casing: Length: Size: MD: TVD: Burst: Conductor 80 20" x 30" 31 -111 31 - 111 0 Surface 2643 13-3/8" 31-2673 31-2673 5380 Intermediate 10359 9-5/8" 29-10387 29-8697 6870 Liner 446 7" 10139 -10585 8480-8870 7240 Liner 754 3-1/2" x 3-3/16" 9980-10734 8342-8977 10160 Liner 3156 2-3/8" 9951-13107 8317-9052 11200 Perforation Depth: Measured depth: 12120 - 13065 feet True vertical depth: 9045 - 9046 feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary Intervals treated (measured): descriptions including volumes used and final pressure: 5-1/2" 17# L-80 26-10049 5-1/2" TIW Packer No SSSV Installed 9914 26-8401 8285 Collapse: 2670 4760 5410 10530 11780 13. Representative Daily Average Production or Injection Data Oil -B01 Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 361 35294 0 0 1163 Subsequent to operation: 626 26316 77 0 1152 14. Attachments: (mquire per2o nnc 25.070 25.071, &25 2a3) Daily Report of Well Operations 0 Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 15. Well Class after work: Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge, Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Stone, Christopher Contact Name: Stone, Christopher Authorized Title: D 5 K Pad / GC1 Lead Petroleum Engineer Contact Email: ChnstopherStone0bp.com Authorized Signature: Date: 4111/ZoI'y Contact Phone: +1 907 564 5518 Farm 10404 ReWsetl 002017 Ate/ � Nl�(�.' .�9 13BDMSJ�2✓JUN 2 5 2019 Submit Original Only Daily Report of Well Operations PBU K -08B ACTIVITYDATF ci MAR&A ov 'WELL S/I ON ARRIVAL'(profile modification) DRIFTED TO TOP OF LTP W/ 2 7/8" DUMMY GUN, 4.50" DRIFT, AND 3.75" LIB @ 9,923' SLIM (Pic of LTP) DRIFTED TO 2 3/8" XO W/ 2.23" CENT, 8' OF STEM, 2.25" CENT, AND BAILER @ 9,950' SLM / 9,964' MD 5/22/2019 *'*CONT WSR ON 5/23/19*** `'CONTINUED FROM 5/22/19 WSR'*' (Profile modification) RAN PDS CALIPER FROM 9,947' TO 9,250' SLM (-4.5' of tbg between LTP & MOE to set plug). SET 2-7/8" XX PLUG W/ TANDEM BP SBHPS GAUGES AT 9,945' SLM / 9,952' MD. RAN 2-7/8" CHECK SET TO 2-7/8" X -LOCK AT 9,952' MD (Tool indicates good set). SET 5-1/2" RQ LOCK W/ FLOW THRU SUB AT 2,317' SLM / 2,331' MD. RAN 5-1/2" CHECK SET TO 5-1/2" RQ LOCKAT 2,331' MD (Tool indicates good set). DRAW DOWN TUBING PRESSURE TO HIGH PRESSURE HEADER (Put well in test). 5/23/2019 ***JOB IN PROGRESS, CONTINUED ON 5/24/19 WSR'** "*CONTINUED FROM 5/23/19 WSR**' (Profile modification) DRAW DOWN TEST FAILED ON 2-7/8" XX PLUG IN PTSA AT 9,944' SLM / 9,952' MD. PULL 5-1/2" RQ LOCK W/ FLOW THRU SUB FROM 2,317' SLM / 2,331' MD. RAN PDS STP LDL FROM THE TOP OF 2-7/8" XX PLUG TO 9,800' SLM (Two passes). LEAK APPEARS TO BE -1' ABOVE 2-7/8" XX PLUG (Upper PTSA seals not stung in). PULLED 2-7/8" XX PLUG WITH GAUGES FROM 9952' MD (Gauges show plug holding). JAR ONE HOUR ON BKR 55KB PACKER W/ SNAP LATCH AT 9,918' SLM / 9,933' MD. 5/24/2019 ***JOB IN PROGRESS, CONTINUED ON 5/25/19 WSR"* "*CONTINUED FROM 5/24/19 WSR*** (Profile modification) PULLED BKR 55KB PACKER (One element spring missing) W/ SNAP LATCH ASSEMBLY FROM 9,933' MD (9918' SLIM). PULLED SEAL RECEPTACLE W/ SNAP LATCH ASSEMBLY FROM 9,933' SLM. PULLED SEAL RECEPTACLE W/ PTSA (Third seal up torn) FROM 9,939' SLM / 9,958' MD. 5/25/2019 '**JOB IN PROGRESS, CONTINUED ON 5/26/19 WSR*** *"CONTINUED FROM 5/25/19 WSR*" (Profile modification) RAN DUMMY 55 KB PACKER, SPACER, DUMMY PTSA TO 9,940' SLM (Ring on TT lugs). SET 5-1/2" HES EVO-TRIEVE AT 9,930' SLM / 9,951' MD. SET 5-1/2" RQ LOCK W/ FLOW THRU SUB AT 2,317' SLM / 2,331' MD. RAN 5-1/2" CHECK SET TO 5-1/2" RQ -LOCK AT 2,331' MD (Tool indicates good set). DRAW DOWN TEST ON 5-1/2" HES EVO-TRIEVE FAILED (-60 psi gain every 15 minutes). PULL 5-1/2" RQ LOCK W/ FLOW THRU SUB FROM 2,317' SLM / 2,331' MD. EQUALIZE & PULL 5-1/2" HES EVO-TRIEVE FROM 9,951' MD. SET 4.50" BAKER SNAP LATCH RECEPTACLE, 2-7/8" SPACER, PTSAAT 9,915' SLM. 5/26/2019 '**JOB IN PROGRESS, CONTINUED ON 5/27/19 WSR'** 'CONTINUED FROM 5/26/19 WSR*** (Profile modification) SET BKR 55KB PACKER, 3.50" SPACER, BAKER SNAP LATCH ASSEMBLY AT 9,913' MD (9,915' MOE). PULL 2-7/8" RETRIEVABLE SEAL GUIDE FROM 2-7/8" X -NIPPLE INSIDE LTP AT 9,946' SLM / 9,961' MD. SET 2-7/8" XX PLUG IN 2-7/8" X -NIPPLE IN LTP/PTSA @ 9,946' SLM / 9,961' MD. RAN 2-7/8" CHECK SET TO 2-7/8" X -LOCK AT 9,946' SLM (Tool indicates good set). SET 5-1/2" RQ -LOCK W/ FLOW THROUGH SUB AT 2,317' SLM / 2,331' MD. RAN 5-1/2" CHECK SET TO 5-1/2" RQ -LOCK @ 2,331' MD (Tool indicates good set). PERFORM SUCCESSFUL DRAW DOWN TEST ON 2-7/8" XX PLUG IN PTSA. PULL 5-1/2" RQ -LOCK W/ FLOW THROUGH SUB FROM 2,317' SLM / 2,331' MD. RAN 2-7/8" EQ. PRONG W/ TT SLV (Eq. device off seat) TO 2-7/8" XX PLUG AT 9,961' MD. CURRENTLY HANGING JUST ABOVE 55KB LTP W/ 2-7/8" GR (Tubing still equalizing). ***JOB IN PROGRESS, CONTINUED ON 5/28/19 WSR*** 5/27/2019 NOTE: -2.08' BETWEEN 2.313" X -NIPPLE & 2-3/8" LINER Not enough room to shift x -line- Run in control **'CONTINUED FROM 5/27/19 WSR*** (Profile modification) UNABLE TO LATCH 2-7/8" XX PLUG BODYAT 9,946' SLM (Sand in tools). BAIL -1 QUART OF IPC / SAND OFF OF 2-7/8" XX PLUG BODYAT 9,946' SLM. PULL 2-7/8" XX PLUG BODY FROM X -NIPPLE AT 9,946' SLM / 9,961' MD. 5/28/2019 "'WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS**' Tim= 6-3/8' CIW FLS WF3'HEAD= MCEVOY ACTUATOR= BAKERC OKB. ELLV = 56.3V REF BLEV = 66.35' BE EFEV = 275' KW = 3496' 30' X 20' NSUL CONDR, —[ Max Angle = 96• @ 12506 #, DatumMD= 10569' D DetumTVD= 8800'SS 13-3/8' CSG, M. L-80, D =12.347'2W, Minimum ID =1.941" @ 9964' 3-112" X 2-316" XO �TOPOF 3 -1/2'x3 -3/16"x2 -7B" LNR I--] 9998' I 3-12' LNR 8.81#, L-80, .0087 bpf, D=2.992" 11 10099' 5-12" TBG, 17#, L-80, .0232 bpf, D=4.892' TOP OF 7" LNR 17- LNR 260, L-80, .0383 bpf, D = 6276" 1 PERFORATION SUMMARY REF LOG: MCNUGPICCL 11/06/07 ANGLE AT TOP FERP 91' @1212V Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnGW DATE DATE 156' 6 12120-12500 O 11/06/07 11A16/07 1.56' 6 12700-13065 C 11/06107 11/06/07 K_p g g SAFETY NOTES: WELL ANGLE> 70'@ 10820"' 15-12' OTIS ROY SSSV LAND NP. D = 4562' I 15-12' OTIS XA SLD SLV. D=4.562' 1 —ITBGS5ALASSY MY 5-12'BOTKBLTPw/PMA,D=2.31'(05/27/19) 9914' 9-5B"X5-12•TWHBBPMD=4.75' 05/14/15 MUP TBGCORRl�TDN-MLLOUrA 7-5/8" MLLOUT EXTENSION, D=6.00' a"`•� 9961' 7-58" X 5-12" XO, D = 4.89Y BTT C2 SETING SLV, D = 995V BOT3.70'DIPLOYMB4TSLV,D=3.00(525119) 9961' 2-7/8' X NP, D = 2.31' (NSDE BOT LTP/ 9964 3-12" X 2-34Y XO. D =1.941" 998-13-lr-rmtDEpLOYSLV,D=3.0' 999Tj3-lrr HEsxw.0=2913' BEHIND CT LNR X 3-3/16" XO, D = 2.766- OTIS XN NP, D = 4.455' BEHIND MEG. ID = 4 75-1 CT LNR MLLOUr1MNDDw(IFO88) 10734'-10739' FT3TD 130' 10 STL, .0039 bpf, D =1.995' DATE REV BY I COhMBJTS DATE REV BY COM ENTS 10113165 ORIGINAL COM PLUTON 05/07/15 MX%PJC RILL KB LTP 09113103 JLMMK CTDSIDETRACK(K-08A) 05/14/15 MUP TBGCORRl�TDN-MLLOUrA 11108107 C CTD SIDETRACK (K -MB) 058/17 Urd PJC SET 103 LTPw/ PISA w00( PLUG 1126/12 FtCr/JMD RILURMET'Ht PKi(11/19-2(112) 07/09/15 DJS/JI.D RILLFD)XR_l1G(06/17/15) 12IOM13 DUJMO TFB3= C/O (1123/13) 06/18/19 15NJMD ADD® 0103, RIB=, BF & COND NFO 12/07/13 RKT/PJC RILU RESET: KB UP (12/04113) 06/18/19 DDVJMD RJLLED&SETLTP FISH - CBP MLLED/ RUSH®(09/25/10) PRUDHOE BAY UNIT - - WEI-L: K 08B PEFWIT No: 2071090 AR No: 50-029-21408-02-00 SEC 4, T11 N, R14E, 1830' FNL & 411' FKL BP Exploration (Alaska) STATE OF ALASKA RECEIVED SKA OIL AND GAS CONSERVATION COMn,,,..SION REPORT OF SUNDRY WELL OPERATIONS JUN 16 2015 1 Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull TubinElli AOGGIGnin ❑ Performed Suspend ❑ Perforate Other Stimulate ❑ Alter Caw' I Change Approved Program E Plug for Rednll n'erforate New Pool n Repair Well ❑ Re-enter Susp Well n Other Pull/Set LTP n 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development Q Exploratory ❑ 207-109-0 3 Address P O Box 196612 Stratigraphic ❑ Service ❑ 6 API Number Anchorage,AK 99519-6612 50-029-21408-02-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028299 PBU K-08B 9 Logs(List logs and submit electronic and printed data per 20AAC25 071). 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 13107 5 feet Plugs measured See Attachment feet true vertical 9052.52 feet Junk measured 13000 feet Effective Depth measured 9952 feet Packer measured See Attachment feet true vertical 8317 69 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20"x30" 292-1112 292-1112 0 0 Surface 2645 13-3/8"72#L-80 33 12-2678 12 33 12-2678 08 4930 2670 Intermediate 10360 9-5/8"47#L-80 33 3-10393 3 33 3-8702 07 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12120-12500 feet 12700-13065 feet True Vertical depth 9044 51-9040 13 feet 9041 45-9046 31 feet .� i . 7 f j h 111� __ 1 ., Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer - None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 411 25800 3 0 1253 Subsequent to operation 0 0 0 0 0 14 Attachments(required per 20 AAC 25 070 25 071,8 25 283) 15 Well Class after work Daily Report of Well Operations E Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A I Contact Nita Summerhays Email Nita.Summerhaysabp.com Printed Name Nita Summerhay Title Data Manager Signatur- /� %/�;;' ft,'±-_/ Phone 564-4035 Date 6/16/2015 yr t._ 7-/ 1 J/ RBDMS \-- JUN 1 7 2015 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028299 ***WELL S/I ON ARRIVAL***(Profile modification) PULL 5-1/2"x 18.42'WFD ER LINER TOP PACKER FROM 9,916'SLM/9,936' MD. SLIPS&STINGER SEALS INTACT BUT MISSING 1/4 OF THE ER PACKER ELEMENT. CURRENTLY RIH W1 4-1/2"BRUSH,4.50"3- PRONG WIRE GRAB. 5/7/2015 ***JOB IN PROGRESS, CONTINUED ON 5/8/15 WSR*** ***CONTINUED FROM 5/7/15 WSR*** (Profile modification) TAG BTT C2 SLEEVE AT 9,951' MD W/4-1/2"BLB,4.50"3-PRONG WIRE GRAB (No recovery). RAN 5-1/2"DUMMY LINER TOP PACKER TO 3.00"POLISH BORE AT 9,939' SLM. UNABLE TO ENTER C2 SETTING SLEEVE AT 9,932' SLM W/DUMMY 45 KB LTP (Made 2 attempts). DRIFT TO 3-1/2"x 2-3/8"XO AT 9,944' SLM/9,964' MD W/2.85"CENT(No issues). TAG 3.00"POLISH BORE AT 9,939' SLM W/3.70"x 67" DUMMY LTP W/STINGER ASSEMBLY (No issues). SET 3.00"SEAL ASSEMBLY W/2.313"X-NIPPLE BUILT IN (Oal=69"- Min id =2.313")AT 9,937' SLM. 5/8/2015 ***JOB IN PROGRESS, CONTINUED ON 5/9/15 WSR*** ***CONTINUED FROM 5/8/15 WSR***(Profile modification) SET BAKER 55 KB LINER TOP PACKER W/SNAP LATCH INTO SEAL ASSEMBLY AT 9,938' SLM (Top of packer 9,941' MD). 55 KB LINER TOP PACKER W/SNAP LATCH= 16'6-1/2"&STINGER ASSEMBLY=5'9". (If pulled together 21.05'). NOTE: BOTH 55 KB LINER TOP PACKER&STINGER ASSEMBLY PULL W/4-1/2"GS. LRS LOADED TUBING WITH 290 BBLS OF CRUDE. SET 2-7/8"X-SELECTIVE TEST TOOL INTO SEAL ASSEMBLY AT 9,943' SLM/9,962' MD. LRS ATTEMPTED TO PRESSURE TEST 55 KB LTP TO 2500 PSI (Able to reach test pressure but falls off rapidly). PULL 2-7/8"X-SELECTIVE TEST TOOL&SET 2-7/8"XX PLUG AT 9,962' MD. LRS ATTEMPTED TO PRESSURE TEST AGAIN WITH SAME RESULTS. 5/9/2015 ***JOB IN PROGRESS, CONTINUED ON 5/10/15 WSR*** T/I/O=2445/367/0. Assist SL, Load and Test. Pumped 5 bbls meth spear and 290 bbls crude to Load TBG. Pumped 19 bbls crude to attempt 2 tests, both Failed. Started 3d test just before 5/9/2015 midnight. No test beyond 5 minutes due to pressure losses. ****Continues on 5-10-15**** ***CONTINUED FROM 5/9/15 WSR***(Profile modification) EQUALIZE&PULL 2-7/8"XX PLUG BODY AT 9,943' SLM/9,962' MD. JAR FOR 6 HRS ON BAKER 55 KB LTP AT 9,917' SLM (Appears to be on C2 setting sleeve not in seal assembly). CURRENTLY PULLING OUT OF HOLE W/SHEARED 4-1/2"GS FROM 9,917'SLM. 5/10/2015 ***JOB IN PROGRESS, CONTINUED ON 5/11/15 WSR*** ****Continued from 5-9-15****Attempted MIT-T to 2500 psi, ****FAIL****after 5 minutes. Pumped 1 bbl crude to reach test pressure. Well under SL control at LRS departure. IA/OA=OTG. 5/10/2015 FWHP=192/387/0 ***CONTINUED FROM 5/10/15 WSR***(Profile modification) RECOVERED COMPLETE 55 KB LINER TOP PACKER W/SNAP LATCH FROM 9,917' SLM. BOTTOM OF SNAP LATCH HAS LIGHT DAMAGE FROM TRYING TO ENTER C2 SETTING SLEEVE. TAG C2 SETTING SLEEVE AT 9,933'SLM (Flag wire)W/4.50" L.I.B. (Impression of setting sleeve). CURRENTLY RUNNING IN HOLE W/3.85"CENT, 3.50" L.I.B.TO TAG SEAL ASSEMBLY. 5/11/2015 ***JOB IN PROGRESS, CONTINUED ON 5/12/15 WSR*** Daily Report of Well Operations ADL0028299 ***CONTINUED FROM 5/11/15 WSR*** (Profile modification) TAG PTSAASSEMBLYAT 9,937' SLM W/3.50" L.I.B. (Impression of fish neck). RAN SEVERAL VARIATIONS OF DUMMY 55 KB LTP TO 9,932' SLM (Unable to enter C2 setting sleeve). CURRENTLY RIH W/SWIVEL, 3.48" DECENTRALIZER,4.50"L.I.B. 5/12/2015 ***JOB IN PROGRESS, CONTINUED ON 5/13/15 WSR*** ***CONTINUED FROM 5/12/15 WSR***(Profile modification) TAG C2 SETTING SLV AT 9,932' SLM W/3.48"DECENTRALIZER,4.50"LIB (Impression of setting sly). DRIFT TO 10,400'SLM W/1.75"S-BAILER (Hop into setting sleeve w/little effort). MADE TWO PASSES FROM 10,050'TO 9,750' SLM W/PDS 24 ARM CALIPER(Extended reach, Good data). RAN SEVERAL VARIATIONS OF DUMMY SNAP LATCH RECEPTACLE TO 9,932' SLM (Unable to enter C2 setting sleeve). 5/13/2015 ***JOB IN PROGRESS, CONTINUED ON 5/14/15 WSR*** ***CONTINUED FROM 5/13/15 WSR***(Profile modification) RAN 4 1/2"SNAP LATCH RECEPTACLE,4.00"CENT,45"SPACER, 3.90"CENT, 3.00"S-BLR INTO SETTING SLEEVE @ 9,937' SLM RAN 4 1/2"SNAP LATCH RECEPTACLE,4.00"CENT, 45"SPACER, 3.90"CENT, DUMMY SNAP LATCH ASSEMBLY INTO SETTING SLEEVE© 9,937' SLM SET 4 1/2"SNAP LATCH RECEPTACLE, 4.00"CENT,45"SPACER, 3.90"CENT, SNAP LATCH ASSEMBLY IN SETTING SLEEVE @ 9,937' SLM (110"oal,top @ 9,928' slm) 5/14/2015 ***GO ON WEATHER TICKET*** 5/15/2015 ***STANDBY FOR WINDS*** ***CONT FROM 5/14/2015 WSR*** SET KB 55 LINER TOP PACKER @ 9937' SLM.(9933' MD) LRS LOADED TUBING WITH 290 BBLS OF CRUDE. 5/16/2015 ***CONTINUED ON 5-17-15 WSR*** T/I/O=2466/367/vac S/L ASSIST MIT-T to 2500 psi ( IN PROGRESS) Pumped 5 bbls Neat 5/16/2015 Meth spear, 290 bbls Crude down Tubing to load **JOB CONTINUED ON WSR 05-17-15** **JOB CONTINUED FROM WSR 05-16-15** T/I/O= 1193/418/vac S/L ASSIST M.I.T-T to 2500 psi ( FAILED-MULTIPLE ATTEMPTS)Pumped a total of 73 bbls Crude down Tubing to attempt M.I.T-T to 2500 psi Tubing keep losing more than 250 psi in 1st 5 min of all tests Established LLR of— .13 bbls/min @ 2500 psi for 5 min S/L in control of well upon departure FWHP's= 5/17/2015 300/377/vac ***CONTINUED FROM 5-16-15 WSR***(profile modification) SET 2 7/8"XX PLUG BODY IN X-NIPPLE @ 9943'SLM.(9952' MD) LRS ATTEMPTED MIT T TO 2500 PSI. **FAIL**(LLR of.13bpm @ 2500psi) PULLED 2 7/8"XX-PLUG FROM 9,943' SLM. SET AND PULLED 2 7/8"X-SELECTIVE TEST TOOL IN X-NIPPLE @ 9943'SLM (Irs gets LLR of .12bpm @ 2500psi) SET AND PULLED 55KB LTTP FROM TOP OF PACKER @ 9,918' SLM (Irs unable to catch pressure) SET 2-7/8"XX PLUG IN X-NIPPLE @ 9,943' SLM, LRS UNABLE TO EXCEED 2000psi @ 1 bpm PULLED AND RESET 2-7/8"XX-PLUG IN X-NIPPLE IN PTSA @ 9,943' SLM LRS ATTEMPTED MIT-T TO 2500psi **FAIL** (LLR of.15bpm @ 2500psi) 5/17/2015 ***CONT WSR 5/18/15*** ***CONT WSR FROM 5/17/15***(profile modification) RD SWCP 4516 SLICKLINE UNIT 5/18/2015 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** FLUIDS PUMPED BBLS 10METH Daily Report of Well Operations ADL0028299 3 DIESEL 673 CRUDE 686 TOTAL • CC) o Om _O o 0 0 Q V O N O Ln N CO A 0 O o 0 0 () 00.4-L O O O V co CO 3 CO r N r N O) r N- m CO Or N CO N- N- LU N N- N CO CO N. NO O V r V O) N- O LU - N CO N O (A of CO CO ✓ O N LU CO N CO N N O ✓ I� CO O CO O CO N CO V CO CO O) CO CA CO CO N CO I I I I I I I I I H N 'Cr r N N CO N 0.) CO O N r LO M N 00 N (fl O r r (fl 00 N 'X CO I- N M N N N M co co co co d N CO (0 (0 (0 (0 (0 (0 CO N- CO CO LO CO CA r O) O O CO �f r M r O (A LU co co co O r O O M 0 0 0 O) N O r r r r r r 4-1 QQd O c 0 0 N O) CO Ln O CO O M •t co CO co QN co CA O) CA C) 0 CO M N N N O CA CS) CA � Q Q Q 0 0 0 co U) CO ao 00 00 C9 J p J p CO J J J J c0 CO J = CUco N N N N N X (7) CA *k Cn .N .(7) (O - CA r N CO N () N cn 0\O N N U N � � M � � r 0 C z = M O M N M cY) (V ce) LU rr M CO CO CO LC) N c co M CO CO O V' t N N O CO CS) d N O J r r W CA W CD2efg00 U O cc cc cc > LL Z Z zwwwwwwwctmm Q Z Z Z Z Z J j D j 0 z J J J J J (n Cn Packers and SSV's Attachment ADL0028299 SW Name Type MD TVD Depscription K-08B PACKER 9899.25 8272.23 5-1/2" TIW Packer K-08B PACKER 9942 8309.06 5-1/2" WFD ER Packer K-08B 207-109-0 Plugs Attachement SW Name Date MD Description K-08B 9/27/2010 12600 2-7/8" CIBP K-08B 5/17/2015 9952 2-7/8" XX Plug TREE= 6-3/8"CAN FLS WH.LFEAD= MCEVOY K-O 8 B I SA NOTES: WELL ANGLE>70°@ 10820'"*". ACRIATOR= BAKER C KB.ELEV= 56.40' I BF.REV= 27.85' -KOP= 3496 2331' J—{5-112"O11S RQY SSSV LAND(A',D=4.562" Max Angle= 96°@ 12506 _... CO TOR Illial 0 J Datum kV= 10569' #, Catum ND= 8800'SS D= ' 13-3/8"CSG,72#,L-80,D=12.347" H 2673' 9840' 1—{5-1/2"OTIS XA SLD SLV,D=4.562" I Minimum ID = 1.941" @ 9964' ' 9899' --j1BGSEAL ASSY 3-1/2" X 2-318" XO x 9914' —9-5/8"X 5-1/2'TNV HBB PKR D=4.75" - L, ) 9925' —17-518"Mt LOUT WINDOW,D=6.00" ...._9932' H7-5/8"X 5-1/2"XO,D=4.892" 9933' —5-1/2"BKR KB LTP w/PISA,D=2.36'(05/16/15) 9951' —1 BTT C2 SEfTIKG SLV,D=4.00" ..7" 9952' —{2-7/8"X ham,D=2.31"(NSDE KB LIP) TOP OF 2-318"LNR 9951' 9952 42-7/8"XX PLUG"(05/17/15) 9964' —3-112"X 2-3/8"XO,Co=1.941" I ' { 9966' H5-1/2"OTIS X MP,D=4.562' TOP OF 3-1/2"x 3-3/16'x 2-7/8" LNR H 9951' 9988' —I3-1/2"BKR DEPLOY SLV,D=3.0' 9997' H3-1/2"HES X NP,D=2.813' BEHIND CT LNR 3-1/2"LNR 8.81#,L-80,_0087 bpf,ID=2.992" —{ 10008' ( 10008' —{3-112"X 33116"XO,D=2.786" I 10009' H5-1/2"OTIS XN NP,D=4.455' BEHIND 5-1/2"TBG,17#,L-80,.0232 bpf,ID=4.892" 10049' C T LNR / \ 10049' —15-1/2"WLEG,ID=4.75" TOP OF 7"LNR —1 10133' 10051' —j ELMO TT LOGGED 11/22/85 10341' --17"MARKER JOINT 9-5/8"CSG,47#,L-80,D=8.681" H 1038T , 7'LNR 26#,L-80,.0383 bpf,0=6.276" —1 1098T MLLOUT WIDOW(K-088) 10734"-10739' PERFORATION SUMMARY 1114. REF LOG:NICNIJGRKxL 11/06/07 ., ANGLE AT TOP PERF: 91" @ 12117' w-44 Note:Refer to Ptoduction DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE DATE 12600' H2-7/8'BOT CBP(09f26110) 1.56" 6 12117-12497 0 11/06/07 11/06/07 1.56" 6 12697-13062 C 11/06/07 11/06/07 ` 13000' —FISH-CSP MLLED I )f ` PUSH(09/25/10) aitrz3-3/16"WWSTOC1(w/RA TAG @ 10740' — 10734' 444�1���1���'�. 3-3/16"LNR 6.2#,L-80 T(1,.0076 bpf,D=2.80" —{ 10734' F TI?H 13069' •4 2-3/8"LAR 4.7#,L-80 SIL,.0039 bpf,D=1.995" —1 13107' DATE REV BY` COMMENTS NITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/13/85 ORIGINAL COMPLETION 05/07/15 MIC/PJC PULL KB LTP WELL: K-08B 09/13/03 JLM/KK CTD SIDETRACK(K-08A) 05/14/15 MIG PJC TBG CORRECTION-MLLOUT ADOBJ PERMT No:"2071090 11/08/07NORDIC 1 CTD SIDETRACK(K-08B) 058/17 MJC/PJC SET KB LTPw/PTSA w/XX PLUG API No: 50-029-21408-02-00 11/26/12 RCT/JM}RUJR SET"ER"PKR(11/19-20/12) SEC 4,T11 N,R14E 1830'FM..&411'F W 12/04/1i DU/JML TREE 00(11/23/13) 12/07/13 RKT/PJC RAL/RESET KB LTP(12/04/13) BP Exploration(Alaska) • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. O~~ ~ - 1 ~ ~' WeN History File Identifier Organizing (done) ^ Two-sided III 11111111 III II III ^ Rescan Needed RE AN DIGITAL DATA Color Items: ~skettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria Date: Project Proofing BY OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: 510 ~ lSl Date: I ~l iiiiuuuiuiuii P ~n P Scanning Preparation _~ x 30 = 3 d + ~ =TOTAL PAGES (Count does nat include cover sheet) BY: Maria Date: ' ~./ ~S o g /s/ Production Scanning Stage 1 Page Count from Scanned Fite: (Count does include cover sheet) . Page Count. Matches Number in Scanning Preparation: _~ YES NO BY: Maria Date: !~//S D ~ /s/ f ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO {/ BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II II I II II I I ~~~ ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc • RECEIVED STATE OF ALASKA • AL ,CA OIL AND GAS CONSERVATION COMML..,iON JAN 0 2 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate UOther9tCLP Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ElRe-enterSuspended Well❑ !/L 5724111. 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development0 Exploratory ❑ x 207-109-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 . 50-029-21408-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028299 , PBU K-08B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured . 13107.5 feet Plugs measured 12600 feet true vertical 9052.52 feet Junk measured 13000 feet Effective Depth measured . 12600 feet Packer measured See Attachment feet true vertical 9035.52 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 82 20"x 30" 29-111 29-111 0 0 Surface 2645 13-3/8"72#L-80 28-2673 28-2672.96 4930 2670 Intermediate None None None None None None Production 10360 9-5/8"47#L-80 27-10387 27-8696.54 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 121,20-12500 feet 12700-13065 feet True Vertical depth 9044.51-9040.13 feet 9041.45-9046.31 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMS MAY 16 2014 Treatment descriptions including volumes used and final pressure: NED JUL 1 0 201 4 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 386 28440 24 0 1577 Subsequent to operation: 660 19692 28 0 1404 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 Li WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.CatronABP.Com Printed Name Garry Catron Title PDC PE Signature .)iGiA +dam — ` Phone 564-4424 Date 1/2/2014 1 VLF 5--/z41I'F Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028299 SW Name Type MD TVD Depscription K-08B PACKER 9914 8228.53 5-1/2"TIW Packer K-08B PACKER 9942 8252.66 5-1/2"WFD ER Packer d W O O PCD O O O O ND al T- CAD IsN00 OT- o N- (0 0 N 0 T- T- � L0 NI- CO +" OD D 00 000 • N o N CO OM) 4" N Tr u) N N Tr CO CO h- CD Nr O 00 O) LC) N- O) U) • 00 N (O CO O) (O cr N O r- V4 N tf) (O N- (O O) N N- N O M O M O) O (O N OD d' CO O) 00 00 CO 00 O N O N Tr CO N- M M 000 OOOI-- M O) 0000T- (OO) NT- 03QD00 CV T- N NrCp N N N N N N M M M M Nr N O 00 00 00 00 00 T- 0Tr T- CO O ol 1�M vim' 00 CD S • M O O O O CD N N O T CO z Q Nv o cn UD CO 03 o M o op N N CD CD CD O O N 03 N op N N C O 3 > H QO a) OOOC,O oO OD Oo O ao ao ao J o o , - J J J co J J 00 J • M4k *k4t 4* pg *k N N X N • N (O 1� . fA - O) Tr O) (ONI- U) -- O) O N W 00 N (V U (NJ kV• M117 0QC'? N M N Mc O N C U) r U) 40 t M d• O M N h- Tr O Tr co N O Z O w N > > wUCDCD � oCLCLCLc c o LLLZZ V Z W W W W W O w cc m m O Z Z Z Z Z CCJ D D O 0JJJJJ0_ U) U) HH O co J U) U) Z (o (B O N CO rn co o -0W a N 0 0 W N O CO F-- D a Cr) _ 2 0 ti V) z 2 o J 2 Z O O c) N N Z N O a 2 O N U) Q > cmCC 2 N °' -0 O OF- = 0 O 0 N 0) F II Q I- W op CD o 00 W > 20 CD i. Q � O (JUJ 0 � w m Cl .." cj o - W Lo o oa 2 J 0 N U) `n O I O C) W' O Q co Z 0 '4- 0 O 2 w N rn F- 2 � _J � � Z � O 211 p N U) Q * _ Z _CO 2 Cr) reA N U) N - U crin LL Q Q ° N Zi. 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CD CD M> -.-- - j: S0CD CD � CDO _ < ( 3C � FEW -' � � N _i J- d d ~ Z Z ~ T O Z ~ N H Z Z I- N = O2 H Z Z ~ 5 00 W Z Z 0 J wJ 1- 001- w00 _, 1- E- 0 0 � � cHF- 0 0E- c 00aw J J W U U u' O 0 U J O W 0 U W Z 0 - u' U U W Z 2 H W' O U Z > 4, DD W' * 4, MU) * * DM N * M * * Q' Q2' QOE * 4, BOJ W D * * a * * 0- a- 0 : * 0U) * * a0 � 0 * Ow' m00 * * 01YU) () U * * w' *0C) C) M M C) I c0 _ _ _ _ _ O O O O O N N N N N N O N M V T N N N N N r r r r TREE= 6-3/8"CNVFLS 8 SAF. DOTES: WELL ANGLE>70°@ 10820 4. V LI-EAD= MCEVOY K-O B '***ORIGINAL& K-08A WELLBORES NOT SHOWN ACTUATOR= BAKER BELOW WHIPSTOCK*** KB.B EV= 56.40' I I BF.ELEV= 27.85' KOP= 3496' O 2331' H 5-1/2"OTIS ROY SSSV LAND NIP,D=4.562" Max Angie= 96°@ 12506' Datum MD= 10569' Datum ND= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" H 2673' I ' 9840' --15-1/2"OTIS XA SLUNG SLV,D=4.562" — 9899' HTBG SEAL ASSY Minimum ID = 1.941" @ 9964' Z x 9914' -19-5/8"X 5-112.ToryFEBPKR,D=4.75" 3-1/2" X 2-3/8" XO 1:Z1 9936' -I 5-1/2"WFD"ER PKR,D=2.30"(12/04/13) 1/ P9951' —I BTT C2 SUING SLV,13=4.00" 9964' —13-1/2"X 2-3/8"XO,D=1.941" I ,I 9966' —i5-1/2"OTIS X NP,D=4.562" 9988' H3-1/2"BKR DEPLOY SLV,D=3.0" ' 9997' H3-1/2"FES xMP,D=2.813" BEHIND CT LNR 3-1/2"LNR,8.81#,L-80,.0087 bpf,D=2.992" —i 10008' � . 10008 3-1/2-X 3-3/16"XO,D=2.786" I I 10009' —15-1/2"OTIS XN ,D=4.455" BEHIND 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892" H 10049' / \-- I 10049' —15-1/2"TBG TAIL,D=4.89") CT LNR TOP OF 7"LNR —1 10133' — 10051' H am)TT LOGGED 11/22/85 • 10341' —17*MARKER DONT 9-5/8"CSG,47#,L-80,D=8.681" — 10387' • ' 7"LNR,26#,L-80,.0383 bpf,D=6.276" —1 10987' PERFORATION St1Av4ARY `, MILOUT WINDOW(K-08B) 10734"-10739' FIEF LOG:MCNUGR/OCL 11/06/07 ' I/I ANGLE AT TOP PERF: 91° @ 12117' w' Note:Feer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE 12600' -12-7/8"BOT CEP(09/26/10) 1.56" 6 12117-12497 O 11/06/07 1.56" 6 12697-13062 C 11/06/07 ` � 13000' —1F15H-CEP MIL®/ AI ` PUSHED(09/25/10) 3-3/16"WHIPSTOCK w/RA TAG @ 10740' —1 10734' �� 13069' •'♦•''�'�♦1�'����. 3-3/16"LNR,6.2#,L-80 TC,.0076 bpf,D=2.80" — 10734' 2-3/8"LN,4.7#,L-80 STL,.0039 bpf,D=1.995" —1 13107'7 DATE REV BY COM ENTS DATE REV BY COIVIMENTS FRUDHOE BAY till 10/13/85 ORIGINAL COMPLETION 11/26/12 RCT/DMD PULURESET"Eft"FCR(11/19-20/12) WELL: K-08B 09/13/03 JLM/KK CTD SIDETRACK(K-08A) 12/04/13 DUJMD TREE GO(11/23/13) PERMIT ND:'071090 11/08/07 NORDIC 1 CTD SIDETRACK(K-08B) 12/07/13 RKT/PJC PULU RESET KB LIP(12104/13) API No: 50-029-21408-02-00 11/13/09 AW/DMD DRLG DRAFT CORRECTIONS SEC 4,T11 N,R14E, 1830'FNL&411'FW,. 07/13/10 RM-VSV FISH(COP)(07/13/10) 09/27/10 DBANPJC PUJ/RESET CEP(09/25-26/10) BP Exploration(Alaska) RECEIVED STATE OF ALASKA AO<A OIL AND GAS CONSERVATION COMMON DEC 3 1 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well L Plug Perforations LJ Perforate L. j Other I I r it LT►' Performed: Alter Casing ❑ Pull TubingJ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ vL 13 /13 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development IO Exploratory ❑ 207 -109 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 , 50- 029 - 21408 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028299 . PBU K -08B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 13107.5 feet Plugs measured 12600 feet true vertical 9052.52 feet Junk measured 13000 feet Effective Depth measured 12600 feet Packer measured See Attachment feet true vertical 9035.52 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" x 30" 29 - 111 29 - 111 0 0 Surface 2645 13-3/F 72# L -80 28 - 2673 28 - 2672.96 4930 2670 Intermediate None None None None None None 1 Production 10360 9 -5/8" 47# L -80 2 7 - 10387 27 - 8696.54 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12120 - 12500 feet 12700 - 13065 feet True Vertical depth 9044.51 - 9040.13 feet 9041.45 - 9046.31 feet Tubing (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 26 - 10049 26 - 8401.57 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: FEB 2 4i1� SCANNED 2 L0 3 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 440 33994 27 0 1180 Subsequent to operation: 1051 20346 23 0 1584 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorLj Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , 0 Gas ❑ WDSPIJJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry.C Printed Name Garry Catron Title PDC PE Signature kid l.A — 7 Phone 564 -4424 Date 12/28/2012 REIMS JAN 0 2 2013 L't `� 2 , it g3) i Form 10-404 Revised 10/2012 Submit Original Only t • • Packers and SSV's Attachment ADL0028299 SW Name Type MD TVD Depscription K -08B PACKER 9914 8228.53 5 -1/2" TIW Packer K -08B PACKER 9942 8252.66 5 -1/2" WFD ER Packer I • • Packer Count = 2 SSSV Count = 0 Casing / Tubing Attachment ADL0028299 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20" x 30" 29 - 111 29 - 111 LINER 13 3 -1/2" 9.2# L -80 9951 - 9964 8316.82 - 8328.04 10160 10530 LINER 3143 2 -3/8" 4.7# L -80 9964 - 13107 8328.04 - 9052.45 11200 11780 LINER 28 3 -1/2" 9.2# L -80 9980 - 10008 8341.86 - 8366.07 10160 10530 LINER 726 3- 3/16" 6.2# L -80 10008 - 10734 8366.07 - 8976.81 LINER 446 7" 26# L -80 10139 - 10585 8479.73 - 8869.92 7240 5410 PRODUCTION 10360 9 -5/8" 47# L -80 27 - 10387 27 - 8696.54 6870 4760 • SURFACE 2645 13 -3/8" 72# L -80 28 - 2673 28 - 2672.96 4930 2670 TUBING 10023 5 -1/2" 17# L -80 26 - 10049 26 - 8401.57 7740 6280 I • • Daily Report of Well Operations ADL0028299 SUMMARY ** *WELL SHUT -IN ON AR ' prod e-mod RIG UP SWCP 4519 TO PULL LTP 11/18/2012 ** *CONT. WSR ON 11- 19 -12 * ** ** *CONT. WSR FROM 11- 18 -12 * ** ( profile -mod) RUN RETREIVA D RELEASING TOOL LATCH UP @ 9941' MD RUN RELEASABLE SPEAR. ENGAGE RETREIVA D LTP @ 9941' MD PULL RETREIVA D LTP @ 9941' MD (elements missing) MADE MULTIPLE ATTEMPTS TO FISH ELEMENTS 11/19/2012 * * *CONT. WSR ON 11- 20 -12 * ** - * *CONY WSR FROM 11- 19 -12 * ** ( profile -mod) SET 5 -1/2" WFD ER LINER TOP PACKER AT 9,923' SLM (9,942' MD) 11/20/2012 ** *WELL LEFT SHUT -IN ON DEPARTURE, PAD OP NOTIFIED * ** 'TREE= 6" MCEVOY • — 9 - AA4OTES: WELL ANGLE > 70° @ 10820 WELLHEAD= MCEVOY K -08 B "**ORIGINAL & K-08A WELLBORES NOT SHOWN ACTUATOR- OTIS BELOW WHIPSTOCK*** KB. 13.B/ = 56.40' I BF. ELEV = 27.85' 1 : KOP= 3496' 2331' I OTIS ROY SSSV LAM) IMP, 0 = 4.562" I Max Angle = 96 @ 12 506--'' 0 Dabs» he = 10569' Dab= TVD = 8800 SS I 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2673' 1 9840' --I 5-1/2" OTIS XA SLUNG SLV, ID = 4.562" I I ,.. x L 9899' H TBG SEAL ASSY 1, Minimum ID =1.941" @9964' 9914° H9-518" X 5-1/2" TM/1138 PKR, ID = 4.75" I MA ler, I I 3-1/2" X 2-3/8" XO WFD -Efr PKR, I) = 2.363" I 0 1J 9951' H BTT C2 SETThIG SLV, ID = 4.00" I 9964' H3-1/2" X 2-3/8" XO, 0= 1.941" 9966' --I 5-1/2" OM X NP, ID = 4.562" 9988' H3-1/2" BKR DEPLOY SLV, ID = 3.0" I 999T H3-1/2" HES X NP, D = 2.813" (3-1/2* LNR, 8.81#, L-80, .0087 bpf, ID= 2.992" H 10008' I 10008' H3-1/2" X 3-3/16" XO, V = 2.786" I 10009* . H 5-1/2" ans XN NP, 0 = 4 455" I I 5-1/2" TBG, 17#, L-80, .0232 bpf, D = 4.892' H 10049' I I 10049' - 15 - 1/2" TBG TAIL, D = 4.89°) BENNO PIPE TOP OF 7" LW( H 10133' I *a E 1 0061 ' - BAD TT LOGGED 11/22/85 I • 10341' --I MARKER JOINT I 9-5/8' CSG, 47#, L-80, D = 8.681" H 10387' _I ■ I 7" LW, 26#, L-80, .0383 bpf, ID = 6 276" H 10987' 4.• ■IAINIIIL TION WOMAIVA MILLOUT WICOW(K 10734" - 10739" PEF!FORA SLIMIvIARY VIOAVIA VINAIIIA REF LOG: fir13N./GR/CCL 11/06/07 ,IMOIVA -maws vgl" ANGLE AT TOP PERE: 91° @12117 Note. Refer to Production DB for historical pert data I 12600' - 12 - 7/8" BOT CIBP (09/26/10) SIZE SFF INTERVAL Opn/Sqz DATE 1.56" 6 12117 - 12497 0 11/06/07 1.56" 6 12697 - 13062 C 11/06/07 0, ,, , ,. ,..t.,... 111 0114ft ior 13000' - FISH - CEP NILLED / 'M IIPSTOCK H 10734' )( Plikr PUSFED (09/25/10) 04 4 4 4 4',N 13-3/16" LW, 6.2#, L-80 Tat, .0076 bpf, 0 = 2.80" I--I 10734' ' 4 04 44.• I FBTD H 13069' IRA TAG H 10740' 2-3/8" LNR, 4.7#, L-80 STL, .0039 bpf, ID= 1.995" H 13107' DATE REV BY COMMENTS DATE REV BY COMMINTS PRUDHOE BAY MET 10113185 ORIGINAL COMPLETION 11/26/12 RCT/JMD PULL "D" PKR/SET "ER" PKR (11/19-20/1 VVI3LL: K-08B 09/13/03 JLM/KK ' CTD SIDETRACK (K-08A) PEAT No: '2071090 11108/07 NORDIC 1 CTD SIDETRACK (K-08B) AR No: 50-029-21408-02-00 11/13/09 AW/JVD DRLG DRAFT CORRECTIONS SEC 4, T11N, R14E, 1830' FM. & 411 FWL 07/13/10 RhitilSV FISH (CEP) (07/13/10) 09127/10 ' DBIWRIC FULU RESET CIBP (09125 - 26/10) BP Exploration (Alaska) • ~ ~ ~,,, ~ , ,~ -.e. .. .~ ~~3~ -T~~ ~~ g ~~k ~~ ~y ~~_ .MICROFILMED. 6!30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: ChristineMahnken~ ,~~~~ ~ ~ ~ ~ ~~~~ Reference: K-08B _-___.__ .__~__~.___,_~~ __.. ~a Contains the following: '~ 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) -~ 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) ,t i I 4 LAC Job#: 1639492 ~e~- roq r~59G Sent by: Catrina Guidry Date: 02/1 ~~ i ~ ~~~ Received by: Date: ~, _~ ;~ ; ~ ~j :3 PLEASE ACKNOWLEDGE RECEIPT BY `~ ~ TURNING OR FAXING YOUR COPY FAX (907) 267-6623 ~~~ 1#1/liNES INTEQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ;~~~~~8 ~ 2oc M~6M~S Baker Atlas PRINT DISTRIBUTION LIST CUMYANY 13Y EXYLUKA'1'lUN (ALASKA) 1NC CUUNTY NUR'l'H 5LUY1/ BURUUGH WELL NAME. K-08B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 2/17/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1639492 Copies of Copies Digital Copies of Copies Digital Each Log 2 of Film Data ,,. - Company BP EXPLORATION (ALASKA) INC Each Log 1 of Film Data Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIltKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated B :BAKER ATLAS-PDC 17015 Aldine Westfield Houston Texas 77073 This Distribution List Completed Bv: ~o-~-~aq Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071090 Well Name/No. PRUDHOE BAY UNIT K-086 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21408-02-00 MD 13108 TVD 9053 Completion Date 11/8/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, RACLX, RACHX, RPCLX, RPCHX , Memory CNL, G Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No D Asc Directional Survey ' pt Directional Survey og Neutron 5 Blu 1 C Lis 15880 Gamma Ray ~ D C Las 15911 Induction/Resistivity (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 10711 13107 Open 11/21/2007 10711 13107 Open 11/21/2007 9790 13051 Open 1/22/2008 MCNL Lee, GR, CCL 6- Nov-2007 9811 13053 Open 1/22/2008 LIS Veri, GR, CNT 10334 13107 Open 1/24/2008 LAS ATR, RPM, GR, RAM, ROP, RPD in PDF form graphics Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / Chips Received? 1~FPI, Analysis N / N Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? V~ N Formation Tops ~ N Comments: Directional Survey Compliance Reviewed By: Date: by Date 01-24-2008 Transmittal Number:92926 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv questions, please contact Douglas Dortch at the PDC at 564-4973 Contents ~O'~-lad ~~Sglo K-08A JOB- lUg ~ t541~ K-14A c'~C~`~'rto2 ~l$°t/8 NGI-13A ~JZC.,ao~--1 t~( '~ ! 5S(3 X-20A ifs ~ eo'~- - ! 13 '~ ~'Sz3 t Y V Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~°a w.:.' ~~~J ~ ?00 ;'a~~~ l~~? Gas Can,. G~ttrr~i;~r~; ~r~~~a~~;g~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 01 /11 /08 NO.4547 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell 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 Field: P.Bay, Milne Pt. Wcll .Inh ~! 1 nn Ilocrrin4inn fl~4n RI (:nlnr rn Z-06 11594523 STATIC TEMP LOG - 09/09107 1 14-18B 11975743 SBHP SURVEY 12/08/07 1 14-02C 11767144 SBHP LOG 11/02/07 1 H-24A 11963073 MEM CBL - ~ 11130107 1 C-35A 11624351 CEMENT BOND & GRAVEL PACK ~-a 11/03/07 1 MPH-19 11982423 USIT - (p ~ 12/10/07 1 1 E-03A 11628773 MEM PROD PROFILE - l 05109/07 1 E-11B 11434760 OH LDWG EDIT (DSI) - L ~ 10/29106 1 1 G-06A 11209587 MCNL - (~ ~-~ 02/25/06 1 1 D-07B 11162822 MCNL - J 12/04/05 1 1 G-10C 11209607 MCNL Q(,p- a 06115106 1 1 G-096 11649989 MCNL Q ~- ~ l l ~j`bf 09/11/07 1 1 K-088 11745243 MCNL 9 '~ f ~ 11/06/07 1 1 V-07 11978425 COMPOSITE CBL 12/06/07 1 V-07 11978425 USIT - ( 12/06/07 1 L2-33 11970801 RST j - V ~ 07/07/07 1 1 03-14A 40013340 OH MWD/LWD EDIT ~ ( 04/23/06 2 1 ~~ PLEASt ACKNOWLEDGE REGEIPI BY SIGNING AND RETURNING ONE DOPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ° ,~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ' " ' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: .. STATE OF ALASKA ~~ -~ ALASKA O1L AND GAS CONSERVATION COMMISSION ~~c o ~ ~aa~ WELL COMPLETION OR RECOMPLETION REPORT A& ~~~ fans, Camft~i~it~n ,~~~.~~ j.zz-~ Anahar~ge 1 a. Well Status: Oil ^ Gas ^ Plugged. andoned ^ Suspended zoAACZS.,os zoaACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ®Development• ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 11/8/2007 12. Permit to Drill Number 207-109- 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded o~~3~r~~ 07 p / Z2<s$ 13. API Number 50-029-21408-02-00 ° 4a. Location of Well (Governmental Section): Surface: ' ' ' 7. Date T.D. Reached 11/3/2007 ~ 14. Well Name and Number: PBU K-08B~ EWL, SEC. 04, 711 N R14E, UM 1830 FNL, 410 Top of Productive Horizon: ~~~~3~~ 2576' FSL, 5056' FEL, SEC. 3~ 712 R14E, UM 8. KB (ft above MSL): 56.4' i Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: ~~"~~ X2140' FSL, 1298' FEL, SEC. 3 T12N, R14E, UM 9. Plug Back Depth (MD+TVp) 13069' 9047' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 670676 ` y- 5975372 ~ Zone- ASP4' 10. Total Depth (MD+TVD) ~ 13108' 9053' 16. Property Designation: ADL 028299 TPI: x- 670377 y- 5979773 Zone- ASP4 Total Depth: x- 668867 - y- 5979303 ~ Zone- ASP4 11. SSSV DeN A(MD+TVD) 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic nd rinted information er 20 AAC 25.050 19. Water depth, if offshore NIA ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): d~ uro to73'f' MWD, GR, ROP, RACLX, RACHX, RPCLX, RPCHX, Memory CNL, GR, CCL, RES ,~ i-z2~o X97?" 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTHTVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 30" x 20" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2673' Surface 2673' 17-112" 3254 cu ft PF'E' 465 cu ft PF 9-5/8" 47# L-80 Surface 10387' Surface 8697' 12-1/4" 1946 cu ft Class 'G', 230 cu ft Class'G' 7" 26# L-80 10139' 10565' 8480' 8852' 8-1 /2" 280 cu ft Class 'G' a-vz° x 3-3/16" x zaia° a.ain ~ s.zn r s.,sa L-80 9980' 10734' 8342' 9039' 3- /4" 118 cu ft Class 'G' 2-3/8" 6.2# L-80 9941' 13107' 8308' 9052' 3" 56 cu ft Class'G' 23. Open to production or inject ion? ®Yes ^ No ~/ 24.. TURING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Slze and Number): SIZE DEPTH SET MD PACKER SET MD 1.56" Gun Diameter 6 SPF 5-1/2", 17#, L-80 10049' 9914' , MD TVD MD TVD 1211 T - 12497 9045' - 9040' 25` ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12697' - 13062' 9041'- 9046' DEPTH INTERVAL MD AMOUNT S~ KIND OF MATERIAL USED Freeze Protected 108 Bbls Diesel with 10 Bbls of McOH on top 26. PRODUCTION TEST Date First Production: November 21, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 11/24/2007 HOUrS Tested: $ PRODUCTION FOR TEST PERIOD OIL-BBL: 1223 GAS-MCF: 7723 WATER-BBL: 27 CHOKE SIZE: 65 GAS-OIL RATIO: 6317 Flow Tubing Press. 580 Casing Press: 100 CALCULATED 24-HOUR 12ATE• OIL-BBL: 3668 ~ GAS-MCF: 23170 WATER-BBL: 81 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical r s Its per 20 250.071. S ~°~. ~~1~>~ D~~T None ,,,A`y ;~ ~ tD~~ ~I•S•D~ ~D ±Il ~~~ !. ~ ~ t ~~~ yC~~k ^D Form 10-407 R2VISed 02/2007 CONTINUED ON REVERSE SIDE ~~'1~ 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. 23S6 /Top of Zone 2B 10573' 8860' None 22TS 10625' 8903' 21TS /Top of Zone 2A 10798' 9010' Top of Zone 1 B 10817' 9016' TDF !Top of Zone 1A 11202' 9052' MHO /HOT 11125' 9049' MHO /HOT {Inverted) 11150' 9050' TDF /Top of Zone 1A (Inverted) 12293' 9040' Top of Zone 1 B (Inverted) 12534' 9037' Formation at Total Depth (Name): Top of Zone 1 B 12534' 9037' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forergoing is true and correct to the best of my knowledge. Signed Sondr Stewman Title Drilling Technologist Date PBU K-08B 207-109 Prepared ByName/Number. SondraSfewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: gbby Higbie, 564-5480 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Satt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only TREE = 6" MCEV OY WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 56.40' BF. ELEV = 27.85' KOP = 3496' Max Angle = 50 C?D 7420' Datum MD = 10569' Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2673 Minimum ID = 2.377" @ 10916' TOP OF 2-7/8" LNR Baker Retrieva D packer 9940. 3-1 /2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID= 4.892" TOP OF 7" LNR ~ 10133' 9-5/8" CSG, 47#, L-80, ID = 8.681 ~ 10387' TOP OF WHIPSTOCK 10560 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10987' PERFORATION SUMMARY REF LOG. ANGLE AT TOP PERF: 91 ^a 12117' Note: Refer to Production DB for historical perf data S¢E SPF INTERVAL Opn/Sqz DATE 1.56" 6 12117-12497 '1107/07 1.56" 6 12697-13062 spec X1/07107 LNR, 6.2#, L-80, .0076 bpf, D = 2.805" ~ 10916' ISH- PDS MEMORY LOGGING TOOL 11542 CT ~ 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" ~ K-08B CTD Sidetrack O i5-112" OTIS ROY SSSV LA ND NIP, ID=4.562" ~~ 9~~5-1/2" OTIS XA SLIDING SLV, ID = 4.562" 9899' TBG SEAL ASSY 9914' ~ 9-5/8" X 5-1 /2" TM/ HBB PKR, ID = 4.75" 9966 5-1/2" OTIS X NIP, ID = 4.562" 9950' C2 Deployment sleeve 9988' 3-1/2" BKR DEPLOY SLV, ID = 3.0" 9997 3-112" HES X NIP, ID = 2.813" 10008' 3-1/2" X 3-3/16" XO, ID = 2.786" 10009 5-1/2" OTIS XN NIP, ID = 4.455" BEHIND 10049' S-1/2" TBG TAIL, ID = 4.89") PIPE 10051' ELMD TT LOGGED 11/22/85 10341' MARKER JOINT MILLOUT WINDOW (K- OA) 10565' - 10571' 11000' Top of Cement ~ 2-3/8" cmfed and perfed 13107' SAFETY NOTES: 10734' -jNlech Packer WS w R/A tags i 10916' 3-3/16" X 2-7/8" XO, ID = 2.377" 11050' 2-7/8" BKR CIBP (03/26/07) (1/1a PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 10113185 ORIGINAL COMPLETION 11/08/07 RBL Pbst Skletrack 09/13103 JLMIKK CTDSIDETRACK(K-08A) 01!21/06 KCF/PAG CIBP(01/14/O6 05/31/06 CO/DTM TREE CORRECTION (6/13/04) 03/28/07 AHWPJC FISH 8 SET CIBP @ 11050' 03/28/07 AHWPJC PERFORATION PRUDHOE BAY UNIT WELL: K-08A PERMfr No:'2031400 API No: 50-029-21408-01 SEC 4, T11 N, R14E, 1830' FNL 8 410' FWL BP Exploration (Alaska) ~ ~ BP EXPLORATION Page 1 of 10 Operations. Summary Report Legal Well Name: K-08 Common Well Name: K-OS Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/26/2007 05:00 - 00:00 19.00 MOB N WAIT PRE WOW. Wind at 20-38 mph. Wait for 20 mph wind to lay down wind walls for derrick down rig move. 20 deg F, 2 deg Wind chill. 10/27/2007 00:00 - 18:30 18.50 MOB N WAIT PRE WOW. Wind at 20-40 mph. Wait for 20 mph wind to lay down wind walls for derrick down rig move. 18 deg F, 0 deg Wind chill. Moved rig off well. Parked 30' in front and secured BOP stack. Prep derrick for laying down, lower derrick cylinders, pinned in place, LD bails, hooked bridle line to wind walls, RD gas buster stack H2S DRILL 04:30 HRS 18:30 - 19:00 0.50 MOB N WAIT PRE Wind gusts dropped below 20 mph. Monitor winds for 30 min. 19:00 - 19:30 0.50 MOB P PRE SAFETY MEETING. Reviewed procedure, hazards and mitigation for UD windwalls and lowering derrick into pipeshed. 19:30 - 00:00 4.50 MOB P PRE RD guide line cables, LD wind walls, loosen guide lines, RU Hydraulic hoses, filling holding tank with hydraulic fluid, scope down derrick, LD and secure traveling block on rig floor, secure all cables on roof. 10/28/2007 00:00 - 01:30 1.50 MOB P PRE Continue w/ derrick down procedure. Open pipeshed roof, UD derrick, close pipeshed roof. 01:30 - 02:00 0.50 MOB P PRE SAFETY MEETING. Reviewed procedure, hazards and mitigation for rig move. Conducted safety meeting w/ security escort and Central Power Station. 02:00 - 09:30 7.50 MOB P PRE Move rig to K Pad, stage on side of K-08. 09:30 - 15:30 6.00 RIGU N WAIT PRE WOW. Wait for winds to drop below 20 mph to raise wind walls. 15:30 - 17:15 1.75 RIGU P PRE Wind gusts dropped below 20 mph. PJSM. Open pipeshed roof, raise derrick, close pipshed roof. Scope derrick up. 17:15 - 17:30 0.25 RIGU P PRE SAFETY MEETING. Reviewed procedure, hazards and mitigation for raising wind walls. 17:30 - 22:00 4.50 RIGU P PRE Hooked bridle line to windwalls, raise and secure windwalls. Secured guide line cables, disconnected and lowered bridle line to floor. Raise and secure derrick cylinders. 22:00 - 22:15 0.25 MOB P PRE SAFETY MEETING. Reviewed procedure, hazards and mitigation for moving rig over well, K-08. 22:15 - 23:00 0.75 MOB P PRE Position rig over K-08 and set rig down. 23:00 - 00:00 1.00 BOPSU P PRE RIG ACCEPT 23:00 HRS 10/28/2007 N/U BOP stack 10/29/2007 00:00 - 02:30 2.50 BOPSU P PRE Continue to N/U BOP stack P/U pipe straightener from rig floor and R/U to injector. R/U tiger tank and hardline. PT hardline. Fill rig pits with 290 bbl 2# Biozan. 02:30 - 08:30 6.00 BOPSU P PRE Pressure test BOPE. Witness waived by AOGCC inspecter, Bob Noble. Send BOPE test report to AOGCC. 08:30 - 12:45 4.25 RIGU P PRE Pick up injecter head from pipe bay. M/U guide arch onto injecter head. 12:45 - 13:00 0.25 RIGU P PRE SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil stub to injecter. 13:00 - 16:00 3.00 RIGU P PRE Pull coil to injecter. Cap end of E-line. Cap well and pump thru kill line and choke line to shaker at 3.8 bpm, to clean any Printed: 12/4/2007 8:53:16 AM ~ ~ BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: K-08 Common Well Name: K-08 Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/29/2007 13:00 - 16:00 3.00 RIGU P PRE debris from kill line. 16:00 - 16:15 0.25 BOPSU P 16:15 - 19:15 3.00 BOPSU P 19:15 - 19:30 0.25 RIGU P 19:30 - 22:45 3.25 RIGU P 22:45-23:00 I 0.251 WHIP IP 23:00 - 00:00 I 1.00 I WHIP I P 110/30/2007 100:00 - 02:15 I 2.251 WHIP I P 02:15 - 03:15 I 1.001 WHIP I P 03:15 - 04:30 I 1.251 WHIP I P 04:30-07:001 2.50~WHIP ~P 07:00 - 07:15 I 0.251 WHIP I P 07:15 - 08:30 I 1.251 STWHIPI P 08:30 - 09:00 0.50 STWHIP P 09:00 - 09:20 0.33 STWHIP P 09:20 - 11:00 I 1.671 STWHIPI P 11:00 - 13:00 I 2.001 STWHIPI P M/U injector lubricator and perform slack management on E-Line. Reverse circ at 3.0 bpm, 4000 psi. Heard E-Line move two times. Press test inner reel valve. Chart test. PRE SAFETY MEETING. Review procedure, hazards and mitigation for pulling BP valve. PRE Rig up BPV lubricator and press test. Pull BPV. Rig down lubricator. PRE SAFETY MEETING. Review procedure, hazards and mitigation for cutting coil to expose eline. PRE R/U hydraulic pipe cutter to bottom of injector. Cut 55' of coil to expose eline. M/U SLB Kendall CTC, Re-head eline. Tested at 48 ohms. PT to 4000 psi. WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for M/U whipstock packer BHA. WEXIT M/U BTT Whipstock BHA #1. Mechanical WS Packer, Baker #10'J' Hyd setting tool, BHI CoilTrak. Overall BHA length = 67.55' WEXIT Open EDC. RIH w/ whipstock BHA #1. Pump at min rate. Well on vac. Returns were all gas, take to tiger tank. WEXIT Log GR tie-in to PDC log from 10350'-10390'. -21' correction. Check RA tag depth at 10,570' from K-08A. On depth. Tied-in depth is corrected to top of whipstock tray. RIH to 10,734' top of whipstock. Orient TF to 135ROHS. WEXIT To of Whi stock at 10,734'-Close EDC. Began pumping at 0.5 bpm. Pumped 7 bbls, Increase rate to 0.8 bpm. Saw pressure spike at 1200 psi. Could have been WS setting, but did not get clear indication of release. WS designed to set at 2800 psi. Pump 40 bbls at 1 bpm w/out seeing any pressure build. Shut off pumps, RIH slow, set down 3K. P/U clean. Open EDC, pump at 2 bpm, 2550 psi, filling wellbore with 2ppb biozan KCL. WEXIT POOH to check WS BHA while circ at 2 bpm, 2580 psi, filling wellbore, send gas returns to tiger tank. Started getting KCL returns to surface after pumping wellbore volume. Full returns. WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for laying out Whipstock running BHA. WEXIT L/O Whipstock running BHA. All tools looked OK. M/U Window milling BHA #2 with 2.74" HCC Daimond Window mill, String mill, BTT Extreme straight motor, 2 jts 2-1/16" CSH and Coiltrak tools. OAL = 99.62'. WEXIT RIH with to 1000'. Good returns. WEXIT Pressure test against Packer Whipstock. 1955 psi for 15 min. Lost 10 psi. Very good test. WEXIT RIH with BHA #2. Circ at min. rate. Tag whipstock at 10756'. Correct -22' to top of whipstock at 10,734'. WEXIT Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2600-2900 psi, full returns, 1.5K WOB, 0.5 FPH. Milled to 10735'. Printed: 12/4/2007 8:53:16 AM ~ ~ BP EXPLORATION Page 3 of 10 Operatiolns Summary Report Legal Well Name: K-08 Common Well Name: K-08 Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hotars Task Code NPT Phase Description of Operations 10/30/2007 13:00 - 15:00 2.00 STWHIP P WEXIT Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2500-2800 psi, 15:00 - 18:00 I 3.001 STWHIPI P I I WEXIT 18:00 - 19:25 1.42 STWHIP P WEXIT 19:25 - 20:30 1.08 STWHIP P WEXIT 20:30 - 21:20 0.83 STWHIP P WEXIT 21:20 - 22:30 1.17 STWHIP P WEXIT 22:30 - 00:00 1.50 STWHIP P WEXIT 10/31/2007 00:00 - 01:00 1.00 STWHIP P WEXIT 01:00 - 02:00 1.00 DRILL P PROD1 02:00 - 04;15 2.25 DRILL P PROD1 04:15 - 05;00 0.75 DRILL P PROD1 05:00 - 05:15 0.25 DRILL P PROD1 05:15 - 07:00 _ 1.75 DRILL P 07:00 - 08:00 I 1.001 DRILL I P I I PROD1 010:030 - 10:45 I 0.251 DRILL P I I PROD1 10:45 - 12:30 I 1.751 DRILL I P I I PROD1 12:30 - 14:30 2.00 DRILL P PROD1 14:30 - 14:45 0.25 DRILL P PROD1 14:45 - 15:10 0.42 DRILL P PROD1 15:10 - 16:30 1.33 DRILL P PROD1 16:30 - 16:50 I 0.331 DRILL I P ( I PROD1 17:10 - 18:30 10.331 DRILL I P I I PROD1 18:30 - 19:00 0.50 DRILL P PROD1 19:00 - 20:15 1.25 DRILL P PROD1 20:15 - 20:40 0.42 DRILL P PROD1 20:40 - 21:00 0.33 DRILL P PROD1 full returns, 1-1.5K WOB, 0.5 FPH. Milled to 10736'.. Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2500-2800 psi, full retums, 1-1.5K WOB, 0.5 FPH. Milled to 10739'. Exit liner at 10,739'. 5' long window. Mill at 1' per hour to 10,740'. Mill 10' rat hole.1.4/1.4 bpm @ 2570 psi. Drill to 10750 Adjust counter wheel. Circulating new Flo Pro to bit. Ream window while circulating new mud to bit. Window clean. Dry tag No problem. POH. Open EDC. Circulate 1.67bpm @ 2730 psi. POH. to surface. LD milling BHA. Window mill gauged 2.72 NO GO string mill 2.73N0 GO. PU 2.7 Build assy. RIH to 10340' - Log tie-in. Correction +18 MWD SLB +2.5'. MWD has new counter wheel. RIH. tag at 10751.6' n mg wpm x_31 psi = psi, , ECD 9.29, ROP 90, TF 90R Drilled to 10,950'r Drill Z1 tum section, 1.75 bpm, 3500 - 4000 psi, 1 K wob, 9.4 ECD, 90 fph, 120R TF, Finished build section. Drilled to 10,985'. POH for Lateral /RES BHA. Open EDC above window and circ at 1.9 bpm while POH. SAFETY MEETING. Review procedure, hazards and mitigation for laying down the build BHA and picking up the lateral BHA. L/O buld BHA. Bit was in good shape. Graded bit at (1,1,1 ). M/U Lateral /RES BHA #4 with HCC BC bit #2, 1.2 deg motor and RES tool. BHA OAL = 67.83'. RIH with Lat /RES BHA #4, circ at min. rate, 0.2 bpm, 960 psi. Log GR tie-in, -1' CTD. Log RES MAD pass from window to bottom. Clean hole. Drill Z1 lateral, 1.65 bpm, 3550 - 4000 psi, 120R TF, 84 incl, 2K WOB, 90 fph, 9.4 ecd, Drilled to 11,110'. Drill Z1 lateral, 1.60 bpm, 3350 - 4000 psi, 90R TF, 86 incl, 1- 2K WOB, 140 fph, 9.4 ecd, Drilled to 11,150'. Wiper trip to window. RIH clean to bottom. Drill Z1 lateral, 1.60 bpm, 3350 - 4000 psi, 90R TF, 90 incl, 1- 2K WOB, 140 fph, 9.4 ecd, Drilled to 11300'. Wiper trip to window. ,Drill Z1 lateral 1.59/1.6 bpm @ 3400psi. 120 R TF,89 inch, .6K W06,136 fph,9.45 ECD. No evidence of 11400 fault. Wiper to10750 Log tie-in correction +2'. Printed: 12/4/2007 8:53:16 AM B'P EXPLORATION Page 4 of 10 Operatiolns Summary Report Legal Well Name: K-08 Common Well Name: K-08 Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2007 .Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task. Code NPT Phase Description of Operations ,10/31/2007 21:00 - 21:25 0.42 DRILL P PROD1 RIH 21:25 - 22:45 1.33 DRILL P PROD1 Drill Z1 1.57/1.62 @ 3400 psi , 3070 psi FS, 120R tf,88.6 Inc, 22:45 - 23:30 0.75 DRILL P 23:30 - 00:00 0.50 DRILL P 11/1/2007 00:00 - 01:30 1.50 DRILL P 01:30 - 02:20 0.83 DRILL P 02:20 - 04:00 1.67 DRILL P 04:00 - 05:00 1.00 DRILL P 05:00 - 05:20 0.33 DRILL P 05:20 - 06:00 0.67 DRILL P 06:00 - 08:00 2.00 DRILL P 08:00 - 08:40 0.67 DRILL P 08:40 - 10:00 1.33 DRILL P 10:00 - 11:30 1.50 DRILL P 11:30 - 13:15 13:15 - 15:45 15:45 - 16:00 16:00 - 18:00 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 2.501 DRILL N I DFAL I PROD1 0.251 DRILL I N I DFAL I PROD1 2.001 DRILL I N I DFAL I PROD1 18:00 - 20:10 2.17 DRILL N DFAL PROD1 20:10 - 20:40 0.50 DRILL N DFAL PROD1 20:40 - 21:30 0.83 DRILL N DFAL PROD1 21:30 - 22:30 1.00 DRILL P PROD1 22:30 - 00:00 1.50 DRILL N DFAL PROD1 11/2/2007 00:00 - 00:45 0.75 DRILL N DFAL PROD1 00:45 - 02:50 2.08 DRILL N DFAL I PROD1 02:50 - 05:00 2.17 DRILL N DFAL PROD1 1.2K wob, 133 ROP, 9.52 ECD Wiper clean trip. Drill 1.53/1.53 bpm @ 3380 psi, 3070 psi FS, 120 R, 88.8 Inc, ECD 9.57 ppg, 140 ROP, WOB 1.4K, Drill 1.5/1.5 bpm @ 3311 psi, 3070 psi., 270 R, 90.4 Inc, ECD 9.57 ppg, 90 ROP, WOB 1.5K, Fault at 11655 ID'd by irradic tool face. No Losses. Wiper clean trip. Pump 15 bbl sweep. @ 11768 Start losing .5 bpm Drill 1.5/1.5 bpm @ 3311 psi, 3070 psi..,, 320 R, 90.3 Inc, ECD 9.60 ppg, 90 ROP, WOB 1.5K, Drill to 11768' started losing returns.PT 324 bbl. Lost 7 bbl to stabalize loss at .4 bpm. Continue to drill 1.57/1.18 bpm @ 3410 psi, 270R TF, WOB 1.41, 91 INC, ROP 125, ECD 9.52, Wiper to wiindow. Log tie-in correction +3'. RIH (Returns from sweep about twice normal) Drill lateral, 1.8 bpm, 1,4 bpm returns, 3400-3900 psi, 120R TF, 1.5K wob, 9.6 ecd, 60 fph, Drilled to 12,000'. Drill lateral, 1.8 bpm, 1.4 bpm returns, 3400-3900 psi, 120R TF, 1.5K wob, 9.6 ecd, 40 fph, Pump 12 bbl high vis sweep. Stacking wt. Drilled to 12,022'. Wiper trip to window. Clean hole. RIH clean to bottom. Drill lateral, 1.8 bpm, 1.4 bpm returns, 3400-3900 psi, 110R TF, 1.5K wob, 9.7 ecd, 20 fph, Stacking wt. Swap to new FloPro. Drilled to 12,053'. Drill lateral, 1.8 bpm, 1.5 bpm returns, 3400-3900 psi, 110R TF, 0.5-1.5K wob, 9.4 ecd, 40 fph, Drilled to 12,108'. POH for BHI directional tools. Circ at max rate of 1.8 bpm, while POH to surface. SAFETY MEETING. Review procedure, hazards and mitigation for changing out the BHA. UO complete BHA, Bit#2 was graded [1,1,1]. C/O Coiltrak DGS M/U Lateral BHA #5 with HCC re-build Bit #3, new 1.1 deg motor, vibrator, Coiltrak with RES tool. RIH with Lateral /RES /Vibrator BHA #5. EDC open circulate at 2bpm. Tie-in log. Correction +10' MWD RIH Drill at 1.59 / 1.37 @ 3816 psi ,3350 psi FS, 90 R TF, WOB 1.6K ,ROP 80, 1NC 90.6, Unable to get survey .DGS failure. POH MWD failure. POOH for DGS. Azimuth reading 20? off previous sensor. G-Totals appear normal but MDIP appears high. Suspect magnetometer failure. Tool did not match readings at previous survey stations. Change out failed DGS. Surface testing tools. Baker had 2 new DGSs arrive evening of previous day. Static loss 10 bph. RIH to 10750. Printed: 12/4/2007 8:53:16 AM BP EXPLORATION Page 5 of 1U Operations Summary Report Legal Well Name: K-08 Common Well Name: K-08 Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2007 Rig Name: NORDIC 1 Rig Number: N1 i Date From - To Hours Task Code NPT Phase 11/2/2007 05:00 - 05:15 0.25 DRILL N DFAL PROD1 05:15 - 06:00 0.75 DRILL N DFAL PROD1 06:00 - 07:20 1.33 DRILL P PROD1 07:20 - 08:00 I 0.671 DRILL I P I I PROD1 08:00 - 09:30 1.50 DRILL P PROD1 09:30 - 10:35 1.08 DRILL P PROD1 12:00 - 13:05 I 1.251 DRILL P I I PROD1 13:15 - 14:00 0.75 DRILL P PROD1 14:00 - 14:30 0.50 DRILL P PROD1 14:30 - 15:15 0.75 DRILL P PROD1 15:15 - 15:30 0.25 DRILL P PROD1 18:15 - 20:00 I 1.75 ~ DRILL I N DFAL I PROD1 20:00 - 20:45 0.751 DRILL N I DFAL I PROD1 20:45 - 21:20 0.58 DRILL N DFAL PROD1 21:20 - 23:15 1.92 DRILL N DFAL PROD1 Description of Operations Log tie-in. Correction +11.5'. RIH Resurvey at 12057 & 12087. AZ @ 12087 corrolated. Drill 1.59 / 1.34 bpm @ 3580psi, 3350 psi, FS, 1.5K wob, 110R tt, 100 fph, 9.2 ecd, Drilled to 12,200'. Drill Z1 B lateral, 1.7 bpm, 1.4 bpm returns, 3500 - 3900 psi, 90L TF, 91 deg incl, 100 fph, 9.3 ecd, Drilled clean sand to 12,300'. Wiper trip to 11,000'. Clean hole. RIH clean to bottom. Drill Z1 B lateral, 1.7 bpm, 1.5 bpm returns, 3500 - 3900 psi, 100E TF, 89 deg incl, 100 fph, 9.3 ecd, Drilled clean sand to 12,448'. Wiper trip to 11,000'. Clean hole. RIH clean to bottom. Drill Z1 B lateral, 1.7 bpm, 1.5 bpm returns, 3500 - 3900 psi, 110R TF, 91 deg incl, 100 fph, 9.4 ecd, Drilled clean sand to 12,600'. Wiper trip to window. Clean hole. Log GR tie-in with RA tag. add 1.5'. RIH clean to bottom. Drill lateral. drilled 8 tt and dill press across BHA increased to 1800 psi, either plugged ports on bit, vibrator or motor failure. POH for 8HA failure. LD BHA Bit had rubber in noaels, Motor wouldn't turn, Agitator plugged. Replace Middle traction cylinder on injector MU BHA7. Static loss rate 10 bph. RIH 23:15 - 23:30 0.25 DRILL N DFAL PROD1 23:30 - 00:00 0.50 DRILL N DFAL PROD1 11/3/2007 00:00 - 00:15 0.25 DRILL N DFAL PROD1 00:15 - 00:30 0.25 DRILL N DFAL PROD1 00:30 - 01:50 1.33 DRILL P PROD1 01:50 - 04:15 2.42 DRILL P PROD1 04:15 - 06:05 1.83 DRILL P PROD1 06:05 - 09:00 2.92 DRILL N STUC PROD1 09:00 - 10:30 I 1.501 DRILL I N I STUC I PROD1 10:30 - 12:30 I 2.001 DRILL I P I I PROD1 12:30 - 13:30 I 1.001 DRILL I P I I PROD1 Log tie-in. Correction +6'. RIH Finish RIH to 12,444 Orient and work through shale at 12,444, run to bottom 12,608 Drill approximately 120'/hr to 12,750 Wiper trip to window .Baubles at 12465 & 12488. Continue to RIH to 12750'. Drill 1.49 /1.3 bpm @ 3387 psi. 3200 psi FS, TF 60L, WOB 1.1K, inc 86.3, ECD 9.47 ppg, No pull to bit. Work pipe. Pull 70K. Stop pump and let downhole pressure relax for 20 min. Pull to 70K and hold pull. Order dead crude. Ann press = 3894 psi. Circ. 26 bbl new high vis FloPro pill at 1.85 bpm into open hole. Stop pump and relax hole. Work coil to 70K. No luck. Wait on crude. Pump 25 bbl dead crude. Spot 15 bbl out bit. Let hole relax 15 min. Stack -5K, coil slid down hole. Pick up free at 381<, no overpull. Circ out the rest of crude. Wiper trip to 11,000'. RIH, set down in shale at 12450', ream thru it and RIH clean to bottom. Drill Z16 lateral, 1.6 bpm, 1.4 bpm returns, 3300-3800 psi, 120R TF, 9.5 ecd, 70 fph, Stacking wt. Not sliding back to bottom. Printed: 12/4/2007 8:53:16 AM BP EXPLORATION Page 6 of 10 Operations Sumlmary Report Legal Well Name: K-08 Common Well Name: K-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code 11/3/2007 12:30 - 13:30 1.00 DRILL P 13:30 - 14:45 1.25 DRILL P 14:45 - 15:15 0.50 DRILL P 15:15 - 16:15 1.00 DRILL P 16:15 - 17:40 I 1.421 DRILL I P 17:40 - 19:20 I 1.671 DRILL I P 19:20 - 23:45 I 4.421 DRILL I P 23:45 - 00:00 0.25 DRILL P 11/4/2007 00:00 - 01:15 1.25 DRILL P 01:15 - 02:00 0.75 DRILL P 02:00 - 03:15 1.25 DRILL P 03:15 - 04:00 0.75 DRILL P 04:00 - 05:00 1.00 DRILL N 05:00 - 05:15 0.25 CASE P 05:15 - 08:15 3.00 CASE P 08:15 - 08:30 I 0.251 CASE I P 08:30 - 10:45 2.25 CASE P 10:45 - 11:00 0.25 CASE P 11:00 - 12:45 I 1.751 CASE I P 12:45 - 13:00 I 0.251 CASE I P 13:00 - 17:45 4.75 CASE P 17:45 - 18:00 0.25 CASE P 18:00 - 22:15 I 4.251 CASE I P 22:15 - 22:35 I 0.331 CASE I P Spud Date: 9/24/1985 Start: 10/24/2007 End: 11/8/2007 Rig Release: 11/8/2007 Rig Number: N1 NPT Phase Description of Operations PROD1 Drilled clean sand to 12,950'. PROD1 Wiper trip to window. PROD1 Log GR tie-in at RA tag. -2.5' CTD. PROD1 RIH to bottom. Set down in shale at 12460'. Ream thru OK, RIH to bottom. PROD1 Drill Z2 lateral, 1.7 bpm, 1.5 bpm returns, 3600-4100 psi, 170R TF, 9.5 ecd, 70 fph, Drilled to 13025'. PROD1 Drill Z2 lateral, 1.7 bpm, 1.5 bpm retums, 3600-4100 psi, 150 -180R TF, 9.5 ecd, 20 fph, 89 deg incl. Continued to try to drop angle with little success until the last 60' where we dropped 11? in the last 60'. Drilled to TD 13,110. PROD1 POOH at 550 ft/hour for MADD pass. Just a little motor work at 12,445. No overpulis. PROD1 Log tie-in. Correction -4'. PROD1 RIH .Slight bauble at 12450. Set down and work thru 13043 -13055. RIH to TD 13107. Circulate liner pill 31bb1 with beads. PROD1 POH spot Liner pill with beads. See over pull 8K at 12300. PROD1 Daylight savings time change. Fall back 1 hr.Continue to POH. PROD1 LD BHA WAIT PROD1 Clear floor. Wait on N2 RUNPRD PJSM for N2 blow down. RUNPRD Circulate CT. Pump 30 bbl Safe Surv pill, 40bb1 H2O,15bb1 inhibitor and 5 bbl MEOH. RU N2 Blow down with N2 to the tiger tank. Bleed down press. Rig down hardline inside E-Coil. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil to reel and securing it for the reel swap. RUNPRD Cut off CTC. Install internal grapple and pull test. Pull coil stub to reel and secure coil on reel. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for swapping reels with bridge crane. RUNPRD Lower E-Coil to Veco trailer. Pick up E-Free coil off of trailer. Set in reel stand and M/U internal grapple. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil to injecter head. RUNPRD Pull test grapple. Remove cross bar. Pull coil to injecter head and stab pipe. M/U BTT CTC. M/U hardline inside reel. Pull test CTC with 30K. Fill coil with 4 bbl MEOH and FloPro. Press test hardline in reel. Insert dart and displace dart with FloPro. 2.5 bpm at 2800 psi. Dart on seat at 40.9 bbls. Press test CTC. Set back injecter head. Prep rig floor to run liner. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running 2-3/8" Liner. RUNPRD M/U BTT float equipment and 2-3/8" Liner, drift the first 5 connections after makeup with 1.87" drift. Continue RIH with 2-3/8" liner. RUNPRD PU injector ,MU liner running tools and stab onto well. Printed: 12/4/2007 8:53:16 AM ;~ Legal Well Name: K-08 Common Well Name: K-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code NPT 11/4/2007 22:35 - 00:00 1.42 CASE P 11/5/2007 00:00 - 01:30 1.50 CASE P 01:30 - 01:45 0.251 CASE P 01:45 - 06:45 5.00 CASE P 06:45 - 07:00 I 0.251 CEMT I P 07:00 - 07:20 I 0.33) CEMT I P 07:20 - 08:50 I 1.501 CEMT I P 08:50 - 10:30 I 1.671 CEMT I P 10:30 - 10:45 ~ 0.25 ~ CEMT ~ P 10:45 -.11:30 I 0.751 CEMT I P 11:30 - 11:45 I 0.251 CEMT I P Spud Date: 9/24/1985 Start: 10/24/2007 End: 11 /8/2007 Rig Release: 11 /8/2007 Rig Number: N1 Phase ` Description of Operations RUNPRD RIH with line window top. Up WT 35K. RUNPRD Run In Open hole with liner at slow pump rate of .13 bpm @ 1000 psi. Set down 12650. PU 36K set down 12650. PU 38K set down 12690 and 12735. Negative wt 12940 12962 PU 40K, 12988 UP 41K ,13015 PU 38K, 13022 Up 38K, 13030, Pu 38K, 13048 Pu36K,13049, No Go . Increae rate to .89 bpm @ 1800 psi. 01:14hrs PU 39K 13056. pu 39k,. 13061. 13119,13120.9 Tap twice. RUNPRD Position reel for ball drop. Drop 5/8" STL ball. RUNPRD Circulate ball to running tool. Ball on seat 33.8 bbls. Coil Volume 40.9. Liner release at 34.3 bbls. 4300 psi. PU Weight 28K lbs. Stack 10K Ibs/Circulate high rate double slick KCL Rate: 1.74 bbl/min. Zero MM. Circulate out FloPro.2/1.4 bpm @ 2480 psi. Clean returns after 388 bblin 283 out. Lost 105 bbl to formation. Mix 30 bbl Bio pill. Crew change. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping liner cement job. RUNPRD Circ. KCL water while hatching up cement. loss rate = 30% at fault at 11,768'. Cement at 15.8 PPG at 0715 hrs. RUNPRD Stage 2 bbl fresh water to Press test cement line. Press test cement line to 6000 psi. Sta a 10.0 bbl 15.8 PPG G Cement:: 1.5 bpm, 1800 psi, Stop pump, clean cement line, pump 2# Biozan to cementers. Insert dart. Displace dart with 25 BBL 2# Biozan. 10 bbl displ, 1.9 bpm, 3300 psi, 1.3 bpm returns, 20 bbl displ, 2.0 bpm, 3600 psi, 1.3 bpm returns, 25 bbl displ, Switch to KCL water 30 bbl displ, 1.9 bpm, 3600 psi, 1.3 bpm returns 36 bbl displ, slow pump to 1.2 bpm, 1330 psi, 41.3 dart on LWP. Sheared at 3500 psi, Zero out total at 43.3 bbls 45 bbl displ, 1.6 bpm, 3500 psi, 1.1 bpm returns 47 bbl displ, 1.7 bpm, 3100 psi, 1.1 bpm returns 49 bbl displ, 1.5 bpm, 3700 psi, 1.1 bpm retums 50 bbl displ, 1.5 bpm, 1.1 bpm returns 52 bbl displ, 1.0 bpm, 2900 psi, 0.9 bpm returns, 53 bbl displ, 1.0 bpm, 2600 psi, 0.8, bpm returns 53.4 bbl, 1.0 bpm, 2600 psi, Bumped LWP, 0.1 bbl late. held 4240 psi, Out totalizer = 7.0 bbls, top of cement estimated at 11,000'. window at 10,780'. Lost 3 bbl cement to fault. Held 4230 psi on LWP for 5 min. Good cement job. RUNPRD Sting out with 28K up wt. Circ. to replace coil voidage whle POH. Hole stayed full. Fault at 11,768' is no longer taking fluid. POH to surface. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for L/O BHA and function test of BOPE. RUNPRD Lay out BTT CTLRT. All tools looked OK. Performed weekly BOPE Function test of BOPE. RUNPRD SAFETY MEETING. Review procedure, hazards and BP EXPLORATION_ Page 7 of 10 Operatiolns Summary Report i Printed: 12/4/2007 8:53:16 AM BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: K-08 Common Well Name: K-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA IRig Name: NORDIC 1 Date I From - To I Hours I Task I Code ~ NPT Spud Date: 9/24/1985 Start: 10/24/2007 End: 11 /8/2007 Rig Release: 11 /8/2007 Rig Number: N1 Phase I Description of `Operations 11/5/2007 111:30 - 11:45 I 0.251 CEMT I P 11:45 - 17:30 I 5.751 CEMT I P 17:30 - 20:25 I 2.921 CEMT I P 20:25 - 22:30 2.08 CEMT P 22:30 - 00:00 1.50 CEMT P 11/6/2007 00:00 - 01:45 1.75 CEMT P 01:45 - 02:00 0.25 EVAL P 02:00 - 04:45 2.75 EVAL P 04:45 - 06:00 1.25 EVAL P 06:00 - 08:00 2.00 EVAL P 08:00 - 08:45 0.75 EVAL P 108:45 - 12:30 I 0.0751 EVAL I P 12:30 - 14:00 1.50 ZONISO P 14:00 - 14:15 0.25 PERFO P 14:15 - 17:00 2.75 PERFO P 17:00 - 19:45 2.75 PERFO P 19:45 - 22:25 2.67 PERFO P 22:25 - 23:20 I 0.921 PERFOBI P 23:20 - 23:45 I 0.421 PERFOBI P 23:45 - 00:00 I 0.251 PERFOBI P 111/7/2007 100:00 - 00:30 I 0.501 PERFOBI P 00:30 - 01:45 I 1.251 PERFOBI P 01:45 - 05:15 I 3.501 PERFOBI P RUNPRD mitigation for running Mill !Motor Cleanout BHA with 1"CSH workstring. RUNPRD M/U 1.85" HCC Diamond Parabolic mill, motor, circ sub, hyd disc and XO. Pick up 104 jts of 1" CSH workstring. Held kick while trip drill. M/U SWS MHA. BHA OAL = 3,230.87'. M/U injecter head. RUNPRD RIH with Cement cleanout BHA #9, with 1.85" mill and Navidrill motor. circ at min. rate. Cleanout liner 1.09 bpm @ 2700 psi. 40 fpm. Tag at 13077. RUNPRD POH. Flag pipe @ 12977 EOP= 9747.POH RUNPRD Standback 52 stands of 1" CSH. RUNPRD Finish TOH with CS Hydrl and cleanout BHA. LOWERI MU MCNL, Load Source, Lower into BOP LOWER1 RIH w/ 52 stands of CS Hydril LOWER1 RIH with memory log to 9800'. LOWER1 Log down from 9800' at 30 fpm. Tag bottom at 13,064'. LOWER1 Log up at 60 fpm. Lay in new high vis FloPro pert pill while logging up. LOWER1 POH to BHA. EOP flag at 6000'. POH Stand back CSH. LOWER1 PJSM LD logging tools. From MCNL PBTD = 13063'MD, TOL(4 LOWER1 Liner lap test .Lost 250 psi in 30 min. Failed to test. LOWER1 or pe ora ing guns. LOWERI PU 45 guns. LOWER1 PU 37 stands of 1" CSH. LOWER1 Stab Coil into top of 1"CSH. RIH with coil, circulating just enough to keep coil warm 0.13 bpm/37 psi IA= 0 / OA=O / WHP= 11. EOP flag at 6000', -2.6' Difference on SLB depth counter. Tag up at 13077.5 MD initial, Weight back at 13069.5, From CNL log PBTD 13063'MD, -5.5 correction. LOWER1 Pump 10 bbls 150K LSRV FloPro, Drop Aluminum 1/2" Ball, Pump 12 bbls 150K LSRV, chase ball w/ 8.5 bbls 150K LSRV FloPro. Volume to ball seat: 40.9 coil volume,1.6 CSHydril volume, 42.5 total. Drop ball 22:41, zero MM. Pump .8 bpm staying below 2000 psi circulating pressure. Chase with remainder of double slick KCI. BHA parked 1' above PBTD at 13,062 MD . All slack out of coil ready to pull just before firing. Slow rate to 1/2 bbl per minute at 32 bbls pumped. LOWER1 Drop circulating pressure below 1000psi, rate 0.4bpm at 32bb1. Started coil moving. Shots fired at 43bb1. Circulating pressure increase from 1000 psi before, 3800 psi peak. LOWER1 Continue POOH at 95 ft/min, cir 1.2 bpm in/.84 bpm out. No overpulls. LOWERI POOH 1bpm in, 0.6 bpm out, park at 9862'MD flow check 5min, no flow, cont POOH LOWER1 Cont POH, Tag up CT connector, cir 0.9 in, 0.5 out, flow check, 20 min, .1 bbl loss in 20 min. Well static. LOWER1 LD CS Hydril, Circulate coil to pits 0.25 bbl/min, PVT 257 bbl, IA=O, OA=O, Flow Check at 10 stands, 1.5 bbl talc CS Hydril displacement/1.6 bbl added to hole, good. .M .. Printed: 12/4/2007 8:53:16 AM ' • i BP EXPLORATION Page 9 of 10 Operations Sullnmally Report Legal Well Name: K-08 Common Well Name: K-08 Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2007 Rig Name: NORDIC 1 Rig Number: N1 .Date From - To Hours Task Code NPT Phase Description of Operations 11/7/2007 05:15 - 09:00 3.75 PERFO P LOWER1 rf uns. 09:00 - 10:50 1.83 PERFO P LOWER1 RIH 15 stands of CSH and POH LD CSH. 10:50 - 12:00 1.17 ZONISO P RUNPRD PU Liner to acker assy. 12:00 - 14:00 2.00 ZONISO P RUNPRD RIH.9900 DN WT 18K. tmg into tie back sleeve and set 8K down. 14:00 - 14:30 0.50 ZONISO P RUNPRD Circulate 1/2 ball to seat with 34.6 bbls. Shear at 3700 psi. 14:30 - 16:00 1.50 ZONISO P RUNPRD POH to surface. 16:00 - 17:00 1.00 ZONISO P RUNPRD LD packer running tools. PU nozzel with check valves. 17:00 - 18:15 1.25 WHSUR P POST RIH with nozzel to 8100'MD 18:15 - 18:25 ( 0.17 WHSUR I P 18:25 - 18:50 0.42 WHSUR P 18:50 - 19:07 I 0.281 WHSUR I P 19:07 - 19:30 0.38 WHSUR P 19:30 - 20:38 1.13 WHSUR P 20:38 - 21:00 0.37 WHSUR P 21:00 - 21:40 0.67 WHSUR P 21:40 - 22:10 0.50 WHSUR P 22:10 - 23:00 I 0.831 WHSUR I P 23:00 - 23:45 23:45 - 00:00 11 /8/2007 00:00 - 00:33 00:33 - 00:55 00:55 - 01:45 0.75 WHSUR P 0.25 WHSUR P 0.55 WHSUR P 0.37 WHSUR P 0.83 WHSUR P 01:45 - 02:30 02:30 - 03:15 03:15 - 05:00 05:00 - 06:00 06:00 - 08:30 0.751 WHSUR I P 0.75 WHSUR P 1.75 WHSUR P 1.00 WHSUR P 2.50 WHSUR P POST RU Little Red. Pressure test lines to 3500 psi. POST RIH, Choke Open, 1.54 bpm pumping diesel from Little Red. Taking returns through choke fully open to pits, 1.80 bpm out. IA=O OA=O PVT=270 Density in 6.63, Density out 8.4. Tubing Speed 68 fpm. Taking KCL water from pits for G&I disposal. POST Pumping diesel at nozzle MD of 9900' 1690 psi. Still displacing KCL to pits while pumping from pits for disposal. PVT = 173, 1.33 bpm in, 1.37 bpm out. Density in 6.68, Density out 8.4. Choke open. Tubing Speed 0 fpm POST POOH at 36 fpm still laying in deisel 1619 psi, 1.36 bpm in, 1.24 bpm out. PVT 118. POST Park nozzle at 9000'MD. Cir diesel 1589 psi. 1.38 bpm in, 1.41 bpm out. PVT 99. Total diesel volume pumped 108 bbl. POST Diesel starting to return to pits, send returns to tiger tank. Partially close choke, 1.5 bpm in/ 1.7 bpm out. POH circulating, 1.5 bpm, 223.2 bbl total. POST Shut in well. POOH wo circulation at 108 fpm. Blow down Little Red and release. SIWHP 18 psi at nozzle depth 6910 MD. POST Cont POH WHP 100psi at nozzle depth 1875, Final WHP 220 psi POST Close Master and Swab, Pickle coil with 40 bbl hot water, 30 bbl inhibitor POST Pump 10 McOH, Blow down reel with N2, WHP 400 psi. POST Bleed down reel through stack, try to clean stack for ND POST Bleed N2 pressure down from coil. POST Break out nozzle, stand back injector POST PU BPV Lubricator, RU same, Pressure Test, Riser leaking, change O-ring on riser POST Pressure test BPV lubricator, attempt to open master, bleed pressure across gate through equalizing port of master valve, open master (700 psi on tubing),ySet BPV POST RD valve crew, close master, move injector over well, dismantle injector stand. POST Prepare coil for reel swap. Rig up line into tubing end, feed coil back to reel with line, anchor coil to reel. PJSM for laying down 2" reel POST Lay down reel from reel house, begin changing rams on BOPE POST Change out BOP rams. Continue with gripper block change Printed: 12/4/2007 8:53:16 AM • BP EXPLORATION; Page 10 of 10 4peratiolns Summary Report Legal Well Name: K-08 Common Well Name: K-08 Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2007 Rig Name: NORDIC 1 Rig Number: N1 Date .From - To Hours Task Code NPT Phase Description of Operations 11/8/2007 06:00 - 08:30 2.50 WHSUR P POST out. 08:30 - 11:00 2.50 WHSUR P POST Swap Reel ,Change out BOP rams. ND BOP. NU and test tree cap. RELEASE RIG 11:00 11-08-2007. r Printed: 12/4/2007 8:53:16 AM bP BP Alaska $ Baker Hughes INTEQ Survey Report iNT EQ Company: BP AmoCO i Date: 11/12/2007 Time: 15:42:18 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-O8, True North Site: PB K Pad Vertical (TVD) Referenc e: 15:08 9!24/1985 00:00 56.4 Well: K-OS Section (VS) Reference: Well (O.OON,O.OOE,336.59Azi) Wellpath: K-O86 Survey Calculation Method: Minimum Curvature Db: Orade ~ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Garke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB K Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973161.33 ft Latitude: 70 19 57.435 N From: Map Easting: 670342.10 ft Longitude: 148 37 5.245 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.30 deg Well: K-08 Slot Name: K-08 Well Position: +N/-S 2202.66 ft Northing: 5975372.00 ft Latitude: 70 20 19.098 N +E/-W 384.04 ft Easting : 670676.00 ft Longitude: 148 36 54.028 W Position Uncertainty: 0.00 ft Wellpath: K-086 Drilled From: K-08A 500292140802 Tie~on Depth: 10711.74 ft Current Datum: 15:08 9/24/1985 00:00 Height 56.40 ft Above System Datum: Mean Sea Level Magnetic Data: 11/1/2007 Declination: 23.58 deg Field Strength: 57665 nT Mug Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.20 0.00 0.00 336.59 Survey Program for Definitive Wellpath Date: 11/1/2007 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 108.70 10501.09 1 : ScMumberger GCT multishot GCT-MS Schlumberger GCT multishot 10557.80 10711.74 MWD (10557.80-12147.80) (1) MWD MWD -Standard 10734.00 13107.50 K-086 (10734.00-13107.50) MWD MWD -Standard Annotation i•1D TVD ft ft 10711.74 8963.59 TIP 10734.00 8976,54 KOP 13107.50 9052.25 TD Survey: K-08B Start Date: 11/1/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ~ O-?- j ~ q by BP Alaska Baker Hughes INTEQ Survey Report TE uv Q Company: BP Amoco Field: Prudhoe Bay Date: 11/12/2007 Co-ordinate(NE) Reference: Time: 15:42:18 Page: WeA: K-08, True North Site: PB K Pad Vertical (TVD) Reference: 15:08 9/24/1985 00:00 56.4 Well: K-08 Section (VS) Reference: WeN (O.OON,O.OOE,336.59Azi) W'ellpath: K-086 Survey Calculation Method: Minimum Curvature Db: Oracle Survev MD ft Intl deg Azim deg TVD ft 10711.74 52.86 21.31 8963.59 10734.00 56.06 28.42 8976.54 10760.60 55.30 36.65 8991.55 10790.54 64.47 44.94 9006.58 10820.26 77.22 53.38 9016.33 10850.90 85.43 67.58 9020.97 10881.59 88.50 83.10 9022.60 10911.63 86.50 97.31 9023.92 10946.48 79.98 115.51 9028.05 10975.73 84.07 131.70 9032.14 11011.86 83.70 140.67 9035.99 11039.27 82.37 145.33 9039.32 11069.08 80.78 149.66 9043.69 11104.05 85.70 154.26 9047.81 11134.33 87.54 158.79 9049.59 11160.97 88.10 163.36 9050.61 11190.37 89.17 168.07 9051.31 11225.30 88.13 172.80 9052.13 11255.56 90.49 177.06 9052.50 11285.36 90.58 182.45 9052.22 11315.28 90.03 186.50 9052.06 11344.88 89.23 190.94 9052.25 11376.19 88.83 195.20 9052.78 11407.15 90.61 202.13 9052.93 11436.97 88.99 206.01 9053.04 11467.69 88.65 210.81 9053.67 11498.46 89.51 215.80 9054.16 11529.26 90.89 220.90 9054.05 11559.80 91.23 225.92 9053.49 11590.14 90.09 231.14 9053.14 11622.49 89.32 236.22 9053.31 11653.37 88.68 241.32 9053.85 11682.21 87.21 239.42 9054.88 11712.43 89.26 234.26 9055.81 11743.90 90.28 227.76 9055.94 11772.98 90.46 222.53 9055.75 11807.37 91.17 .217.96 9055.26 11838.87 91.99 223.10 9054.39 11868.77 93.84 227.21 9052.87 11897.39 95.13 231.30 9050.63 11927.41 94.64 237.36 9048.07 11956.25 92.45 241.85 9046.29 11985.27 90.86 247.05 9045.45 12014.47 90.03 251.72 9045.22 12042.95 90.09 256.45 9045.19 12082.61 90.80 266.99 9044.88 12124.00 91.20 278.07 9044.16 12161.15 91.23 283.79 9043.37 12191.42 91.82 287,53 9042.57 12227.55 91.54 293.81 9041.51 12268.10 91.97 292.28 9040.26 12296.75 90.37 288.60 9039,68 12317.07 89.39 286.60 9039.72 Sys T'VD N/S E/W ft ft ft 8907.19 4534.26 -502.42 8920.14 4550.67 -494.80 8935.15 4569.17 -483.00 8950.18 4588.67 -466.06 8959.93 4606.91 -444.83 8964.57 4621.75 -418.55 8966.20 4629.47 -388.99 8967.52 4629.37 -359.06 8971.65 4619.67 -326.01 8975.74 4603.68 -301.98 8979.59 4577.79 -277.14 8982.92 4556.07 -260.77 8987.29 4531.21 -244.92 8991.41 4500.57 -228.61 8993.19 4472.85 -216.58 8994.21 4447.68 -207.95 8994.91 4419.20 -200.70 8995.73 4384.78 -194.90 8996.10 4354.65 -192.22 8995.82 4324.86 -192.10 8995.66 4295.04 -194.43 8995.85 4265.79 -198.92 8996.38 4235.30 -205.99 8996.53 4205.99 -215.90 8996.64 4178.77 -228.06 8997.27 4151,76 -242.66 8997.76 4126.06 -259.55 8997.65 4101.91 -278.65 8997.09 4079.74 -299.63 8996.74 4059.65 -322.36 8996.91 4040.50 -348.41 8997.45 4024.50 -374.80 8998.48 4010.25 -399.86 8999.41 3993.73 -425.13 8999.54 3973.94 -449.58 8999.35 3953.44 -470.19 8998.86 3927.20 -492.40 8997.99 3903.28 -512.85 8996.47 3882.22 -534.02 8994.23 3863.60 -555.63 8991.67 3846.17 -579.92 8989.89 3831.61 -604.74 8989.05 3819.11 -630.90 8988.82 3808.83 -658.22 8988.79 3801.02 -685.60 8988.48 3795.32 -724.79 8987.76 3797.14 -766.07 8986.97 3804.18 -802.52 8986.17 3812.35 -831.65 8985.11 3825.09 -865.43 8983.86 3840.96 -902.72 8983.28 3850.96 -929.56 8983.32 3857.10 -948.92 MapN MapE ft ft 5979893.35 670070.54 5979909.92 670077.79 5979928.68 670089.16 5979948.57 670105.65 5979967.28 670126.46 5979982.71 670152.39 5979991.11 670181.77 5979991.69 670211.69 5979982.75 670244.95 5979967.31 670269.33 5979941.99 670294.76 5979920.65 670311.62 5979896.16 670328.02 5979865.90 670345.02 5979838.47 670357.69 5979813.50 670366.89 5979785.20 670374.78 5979750.91 670381.37 5979720.85 670384.72 5979691.08 670385.53 5979661.21 670383.87 5979631.87 670380.06 5979601.23 670373.67 5979571.71 670364.44 5979544.22 670352.91 5979516.89 670338.92 5979490.81 670322.62 5979466.23 670304.07 5979443.59 670283.61 5979422.99 670261.35 5979403.25 670235.74 5979386.65 670209.72 5979371.84 670185.00 5979354.76 670160.11 5979334.42 670136.12 5979313.45 670115.98 5979286.71 670094.38 5979262.33 670074.47 5979240.80 670053.79 5979221.70 670032.61 5979203.72 670008.73 5979188.60 669984.25 5979175.50 669958.38 5979164.61 669931.30 5979156.18 669904.11 5979149.58 669865.06 5979150.47 669823.75 5979156.68 669787.15 5979164.18 669757.85 5979176.15 669723.79 5979191.16 669686.15 5979200.54 669659.10 5979206.24 669639.59 VS DIS Tool ft deg/100ft 4360.68 0.00 MWD 4372.70 29.69 MWD 4385.00 25.71 MWD 4396.16 38.85 MWD 4404.47 50.56 MWD 4407.64 53.04 MWD 4402.99 51.47 MWD 4391.00 47.72 MWD 4368.98 55.10 MWD 4344.76 56.56 MWD 4311.12 24.71 MWD 4284.68 17.56 MWD 4255.57 15.33 MWD 4220.98 19.20 MWD 4190.76 16.12 MWD 4164.23 17.27 MWD 4135.22 16.42 MWD 4101.32 13.86 MWD 4072.61 16.09 MWD 4045.22 18.09 MWD 4018.78 13.66 MWD 3993.72 15.24 MWD 3968.56 13.66 MWD 3945.59 23.11 MWD 3925.44 14.10 MWD 3906.46 15.66 MWD 3889.58 16.45 MWD 3875.01 17.15 MWD 3863.00 16.47 MWD 3853.60 17.61 MWD 3846.37 15.88 MWD 3842.17 16.64 MWD 3839.05 8.33 MWD 3833.93 18.36 MWD 3825.48 20.91 MWD 3814.85 18.00 MWD 3799.60 13.45 MWD 3785.77 16.52 MWD 3774.86 15.06 MWD 3766.36 14.94 MWD 3760.01 20.18 MWD 3756.51 17.29 MWD 3755.42 18.73 MWD 3756.85 16.24 MWD 3760.56 16.61 MWD 3770.90 26.64 MWD 3788.97 26.78 MWD 3809.91 15.39 MWD 3828.98 12.50 MWD 3854.09 17.39 MWD 3883.47 3.92 MWD 3903.30 14.00 MWD 3916.64 10.96 MWD i i bP BP Alaska S Baker Hughes INTEQ Survey Report rrrTE Q ~ Company: BP Amoco Date: 11/12/2007 Time: 15:42:18 Page: 3 Wield: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-08, True North Site: PB K Pad Vertical (TVD) Reference: 15:08 9/24/1985 00:00 56.4 Well: K-08 Section (VS) Reference: Well (O.OON,O.OOE,336.59Azi) W'ellpath: K-08B Survey Calculation Method: Minimum Curvature Db: Orade Survey MD ft Incl deg Azim deg TVD ft 12346.29 88.86 283.22 9040.17 12380.20 87.60 278.56 9041.21 12418.71 88.34 275.90 9042.58 12442.51 89.91 278.07 9042.94 12471.61 93.47 284.35 9042.08 12505.60 95.88 289.89 9039.31 12542.09 94.15 293.82 9036.12 12569.86 90.71 290.85 9034.94 12600.02 88.10 287.37 9035.26 12631.94 87.54 282.69 9036.47 12662.89 86.27 279.41 9038.14 12691.55 84.72 276.50 9040.39 12724.11 84.23 271.91 9043.53 12752.31 85.77 267.80 9045.99 12782.67 88.34 264.84 9047.55 12816.58 88.56 258.69 9048.47 12845.74 90.58 262.62 9048.69 12873.26 93.21 264.63 9047.78 12902.78 93.91 268.72 9045.94 12932.25 93.31 273.16 9044.09 12964.41 93.03 278.49 9042.31 12995.09 90.52 281.99 9041.36 13030.40 86.42 284.17 9042.30 13061.99 81.59 287.66 9045.60 13107.50 81.59 287.66 9052.25 Sys TVD N/S E/W ft ft ft 8983.77 3864.62 -977.15 8984.81 3871.02 -1010.43 8986.18 3875.86 -1048.60 8986.54 3878.76 -1072.22 8985.68 3884.40 -1100.73 8982.91 3894.37 -1133.10 8979.72 3907.90 -1166.82 8978.54 3918.44 -1192.48 8978.86 3928.31 -1220.97 8980.07 3936.58 -1251.77 8981.74 3942.50 -1282.10 8983.99 3946.46 -1310.39 8987.13 3948.83 -1342.70 8989.59 3948.76 -1370.79 8991.15 3946.82 -1401.04 8992.07 3941.96 -1434.57 8992.29 3937.23 -1463.33 8991.38 3934.17 -1490.67 8989.54 3932.47 -1520.07 8987.69 3932.95 -1549.47 8985.91 3936.21 -1581.41 8984.96 3941.66 -1611.58 8985.90 3949.64 -1645.95 8989.20 3958.25 -1676.15 8995.85 3971.91 -1719.05 MapN MapE ft ft 5979213.12 669611.20 5979218.76 669577.80 5979222.73 669539.52 5979225.09 669515.84 5979230.08 669487.21 5979239.31 669454.63 5979252.07 669420.61 5979262.02 669394.72 5979271.24 669366.01 5979278.81 669335.04 5979284.04 669304.59 5979287.35 669276.21 5979288.99 669243.86 5979288.27 669215.78 5979285.64 669185.59 5979280.03 669152.18 5979274.64 669123.53 5979270.96 669096.27 5979268.59 669066.92 5979268.40 669037.51 5979270.93 669005.52 5979275.69 668975.23 5979282.89 668940.69 5979290.81 668910.30 5979303.49 668867.11 VS DLS Tool ft deg/100ft 3934.75 11.71 MWD 3953.84 14.23 MWD 3973.45 7.17 MWD 3985.49 11.25 MWD 4002.01 24.80 MWD 4024.01 17.72 MWD 4049.82 11.73 MWD 4069.69 16.36 MWD 4090.07 14.42 MWD 4109.89 14.76 MWD 4127.37 11.35 MWD 4142.24 11.48 MWD 4157.26 14.11 MWD 4168.35 15.51 MWD 4178.59 12.90 MWD 4187.45 18.14 MWD 4194.54 15.15 MWD 4202.59 12.03 MWD 4212.71 14.03 MWD 4224.83 15.17 MWD 4240.51 16.57 MWD 4257.50 14.03 MWD 4278.48 13.15 MWD 4298.38 18.83 MWD 4327.95 0.00 MWD BAKER NUGNES INTEQ 7260 Homer Drive Anchorage, Alaska 99~ 18 Tel 907-267-6600 Fax 907-267-6623 To Whom It May Concern: November 16, 2007 Please find enclosed directional survey data for the following wells: G-09B OS-lOC OS-22C K-08B X-30APB 1 X-30APB2 X-30A X-20A Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. G RECEIVED BY: ~ ~ ~~ ,State of Alaska AOGCC DATE: ~ :.f ~ U Cc: State of Alaska, AOGCC ~~~_~~y d ~ ~ d ~ SARAH PALIN, GOVERNOR ~iIL>•-78~ OIIr ~ ua-~7 333 W. 7th AVENUE, SUITE 100 CO1~T5ER~A'1`IO1~T C011'II~II55IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Abby Higbie CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K-08B BP Exploration Alaska, Inc. Permit No: 207-109 Surface Location: 1830' FNL, 410' EWL, SEC. 04, T11N, R14E, UM Bottomhole Location: 2104' FSL, 1260' FEL, SEC. 32, T12N, R14E, UM Dear Ms. Higbie: 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 Iaw 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 (~7 659-3607 (pager). DATED this /Tday of;August, 2007 cc: Department of Fish;Bs Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~ PERMIT TO DRILL 20 AAC 25.005 ~. nf3r ~.q ;..; _. f ~~u,~ 'F 1 a. Type of work ~ ^ Drill ®Redrill ^ Re-Entry 1 b. Current Welt Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU K-08B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13150' TVD 8989ss/ 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 410' EWL R14E 1830' FNL SEC 04 T11 N UM 7. Property Designation: ADL 028299 Pool , , . , , , Top of Productive Horizon: 2770' FSL, 46' FEL, SEC. 32, T12N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 30, 2007 Total Depth: 2104' FSL, 1260' FEL, SEC. 32, T12N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 4,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-670676 ' y-5975372 ~ Zone-ASP4 10. KB Elevation (Height above GL): 56.4 ~ feet 15. Distance to Nearest We11 Within Pool: 1,770' 16. Deviated Wells: Kickoff Depth: 10730 > feet Maximum Hole An le: 97 - de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3300 Surface: 2420 18. Gasin Pr ram: S ` ' ca io n To - S ' in' D th -Bottom anti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD rncludin sta a data 3" 2-3/8" 6.2# L-80 TCII 2520' 10630' 8850' 13150' 8989' ~ 73 cu ft Class'G' 19. PRESE NT WELL,CONDITION S UMMARY (To be completed forRedriltand Re-entry Operations) Total Depth MD (ft): 12150 Total Depth TVD (ft): 9039 Plugs (measured): 11050 Effective Depth MD (ft): 12115 Effective Depth TVD (ft): 9037 Junk (measured): None asing Length Size Cement Volume MD TVD Conductor /Structural 110' 30" x 20" 8 cu ds Con rete 110' 110' Surface 2673' 13-3/8" 3254 cu ft PF'E' 465 cu ft PF 2673' 2673' Intermediate 10387' 9- /8" 1946 cu ft Class'G' 230 cu ft Class'G' 10387' Pr u i n Liner 426' 7" 280 cu ft Class 'G' 10139' - 10565' 8480' - 8852' Liner 2170' 3-1l2"x3-3116"x2-7/8" 118 cu ft Class'G' 9980' - 12150' 8342' - 9039' Perforation Depth MD (ft): 10867' - 10987' Perforation Depth TVD (ft): 9029' - 9038' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Abby Higbie, 564-5480 Printed Name Abby Higbie Title CT Drilling Engineer Prepared By Name/Number: Si nature `' ~ ~ Phone 564-5480 Date $ (p p7 Terrie Hubble, 564-4628 .Commission Use Onl Permit To Drill Number: ~~? ~~~ API Number: 50-029-21408-02-00 Permit A proval Date: ~ See cover letter for other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me_th/ane, gas hydrates, or gas contained shales: ~/ Samples Req'd: ^ Yes L7 No Mud Log Req'd: ^ Yes Ld No ,rn~t~ HZS Measures: Yes ^ No Di ctional Survey Req'd: I~Yes ^ No Other: ~'v~ ~S` ~P ~5~ ~S p~GrbC 11 APPROVED BY THE COMMISSION Date ~~,~ "© ,COMMISSIONER Form 10-401 Revised 12/2005 V ~ / Submit In Duplicate ~~~o~ ORIGI~IA1 v ~ ~.g~' BP Prudhoe Bay K-08B CTD Sidetr~ CTD Sidetrack Summary Pre-Rig Work: (Scheduled to begin September 1st, 2007) 1) S Passed tubing caliper inspection 11/11/06 2) O Passed MIT-IA and MIT-OA. 3) O AC -LDS; AC-PPPOT-IC, T 4) S Run dummy whipstock (15' x 2.625") drift to 10900' 5) E Set 3 3/16" mechanical packer WS at 10730' 6) O PT mechanical packer WS to 2000psi 7) O PT MV, SV, WV 8) O Blind and bleed lines 9) O Remove wellhouse, level pad Rig Work: (Scheduled to begin October 30th, 2007) 1) MIlZU Nordic 1 and test BOPE to 250psi low and 3500psi high. 2) Mi112.74" window in 3 3/16" liner at 10730' ~ 3) Drill Build: 3" OH, 395' (40 deg/100 planned) 4) Drill Lateral: 3" OH, 2025' (12 deg/100 planned) 5) Run 2-3/8" solid liner leaving TOL at 10630' 6) Pump cement leaving TOC at 10630' 7) Cleanout liner and MCNL/GR/CCL log 8) Test liner lap to 2000 psi 9) Perforate liner per asset instructions 0800') 10) Freeze protect well, set BPV and RDMO Post-Rig Work: 1) Install well house and attach production lines 2) Pull BPV 3) Test separator (800' of perfs) Mud Program: • Well kill: 8.6 ppg brine -° • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole Size: • 3" Casing Program: Fully cemented liner • 2-3/8", 6.2#, L-80, TCII 10630'MD - 13150'MD • A minimum of 13 bbls 15.8 ppg cement will be used for liner cementing. Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional p1~Max. planned hole angle is 97 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. " • Distance to nearest property - 4000 ft (North) ~~ • Distance to nearest well within pool - 1770 ft. (E-08A) Anti-Collision • E-11 - 563' ctr-ctr Status P&A'd Logging f _ • MWD directional, gamma ray, and resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run Hazards • The maximum recorded H2S level on K Pad is 25 ppm (K-16AL2 on 1/13/2006). s • High risk of lost circulation due to 3 fault crossings in the NW-SE trend "' • Target depth uncertainty (+/- 25ft) • Risk of hydraulics issues due to 5 'h" tubing in 3" OH Reservoir Pressure • Res. press. is estimated to be 3300 psi at 8800'TVDss (7.2 ppg EMW). ~ Max. surface pressure with gas (0.10 psi/ft) to surface is 2420 psi. WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 56.aa BF. ELEV = 27.85' KOP = 3498' Max Angle = 50 ~ 7420' Datum ND = 10569' Datum TVD = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" 2873' K-08A C SAFETY NOTES: I 2331' I--~5-1/2" OTISRQY SSSV LAND NIP, ID=4.562" II 9840' I-15-12" OTLS XA SLIDING SLV, ID = 4.587' Minimum ID = 2.377" ~ 10916' TOP OF 2-7/8" LNR ~3-112" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" H 10008' 5-12" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10049' TOP OF 7" LNR 10133' 9-5/8" CSG, 47#, L-80, ID = 8.681 " 10387' TOP_OF 1M-IIPSTOCK 10560' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10987' PERFORATION SUMMARY REF LOG: ANGLEAT TOP PERF: 78 Q 10867' Note: Refer to Ftoduction DB for historical pert data IZE SPF INT6~1/AL OpNSgz GATE 56" 6 10867 - 10892 O 03/28/07 6 10962 - 10987 0 03128/07 ' 4 111 ~ -11670 C 09113!03 4 11720 -11820 C 09V13I03 4 11960 - 12110 C 09/13103 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" ~-j 10916' FISH- FDS MEAAORY LOGGING TOOL 11642' CTM LNR, 6.16#, L-80, .0058 bPf, ID = 2.441" I-~ 12150' 8888' HTBG SEAL ASSY 8914' H9-5/8" X 5-1/2" TNV HBB PKR, ID = 4.75" 9966' ~- j 5-112" OTiS X NIP, ID = 4.582" ~ 9980' 4.3T' BKR C2 SETTING SLV, ID = 4.0" 9988' 3-1/2" BKR DEPLOY SLV, ID = 3.0" 9997' 3-12" HES X NIP, ID = 2.813" 10008' 3-1/2" X 3-3118" XO, ID = 2.788" 10008' 5-1/2" OTIS XN NIP, O = 4.455" EH~NI 10049' 5-12" TBG TAIL, ID = 4.89") PIPE 10051' ELMD TT LOGGED 11!22/85 10341' MARKER JOINT MILLOUT WINDOW (IF OA) 10565' - 10571' 10916' H 3-3/16" X 2-718" XO, ID = 2.377" 11050' 2-7/8" BKR CIBP (03/26/07) ~ 11904' CTM ~ WFRDCIBP (1114/06) 12115' PBTD OIATE REV BY COMMENTS GATE REV BY COMMENTS 10113/85 ORIGINAL COMPLETION 09/13/03 JLMfKK CTDSIDETRACK(K-03A) 01/21/06 KCF/PAG CIBP(01/14106 05/31/06 CO/DTM TREE CORRECTION (6/13/04) 0328/07 AHWPJC FlSH & SET GBP ~ 11050' 03/28/07 AHWPJC PERFORATION PRUDHOE BAY UNff" WElL: K-OBA PERNff No: "Zf>;i1400 API No: 50.029-21408-01 SEC 4, T11 N, R14E, 1830' FNL & 410' FWL BP 6cpioration (Alaska) 6" WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 56.40' BF. ELEV = 27.85' KOP = 3496' Mex Angle = 50 ~ 7420' Datum MD = 10569' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2673' K -O V ~ SAFETY NOTES: Proposed CTD Sidetrack O 15-1 /2" OTIS ROY SSSV LAND NIP, ID = 4.562" I I 9840' ~-j5-1 /2" OTIS XA SLIDING SLV, ID = 4.562" Minimum ID = 2.377" ~ 10916' TOP OF 2-7/8" LNR ~3-1 /2" LNR, 9.3#, L-S0, .0087 bpf, ID = 2.992" ~ 10008' 5-1 /2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10049' TOP OF 7" LNR 10133' 9-5/8" CSG, 47#, L-80, ID = 8.681 " 10387' TOP OF WHIPSTOCK 10560' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10987' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 78 ~ 10867' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE .56" 6 10867 - 10892 iso!a'ed proposed 2" 6 10962 - 10987 iso~ated prcposed 2" 4 11100 - 11670 isolated proposed 2" 4 11720 - 11820 isolated proposed 2" 4 11960 - 12110 isolated proposed 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" ~ 10916' FISH- PDS MEMORY LOGGING TOOL 11642' CTM 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441 " 9899' H TBG SEAL ASSY 9914' 9-5/8" X 5-1 /2" TNV HBB PKR, ID = 4.75" 9986' S-1 /2" OTIS X NIP, ID = 4.562" 9970' Lir.cr roo ~acacr 9988' 3-1/2" BKR DEPLOY SLV, ID = 3.0" 9997' 3-112" HES X NIP, ID = 2.813" 10008' 3-112" X 3-3/16" XO, ID = 2.786" 10009' S-1/7' OTIS XN NIP, ID = 4.455" EHINI 10049' S-1/2" TBG TAIL, ID = 4.89") PIPE 10051' ELMD TT LOGGED 11!22/85 10341' MARKERJOINT MILLOUT WINDOW (K OA) 10565' - 10571' 10630' Tap of 2-3/B° ~~cr ~ 10630' Tap of Ceme~i 2-3/8" cmt'ed and perfed 10730' HMech Packer WS w R/A tags! 10918' 3-3/16" X 2-718" XO, ID = 2.377" 11050' 2-7/8" BKR CIBP (03/26/07) 1904' C~ WFRD CIBP 12115' PBTD DATE REV BY COMMEMS DIATE REV BY COMMENTS 10113f85 OIaGINAL COMPLETION 09/13103 JLM/KK CTDSIDETRACK(K-08A) 01/21/06 KCF/PAG GBP(01/14!06 05/31/06 CO/DTM TREE CORRECTION(6/13J04) 0328107 AHWPJC FISH & SET CIBP ~ 11050' 0328/07 AHWPJC PERFORATION 13160' ~ / PRUDHOE BAY UNIT WELL: K-08A PERMIT No: "2031400 API No: 50-029-21408-01 SEC 4, T11 N, R14E, 1830' FNL & 410' FWL BP Exploration (Alaska) • by BP Alaska s Baker Hughes INTEQ Planning Report INTEQ Company:. BP Amoco Date: 7/2'4/2007 Time: 10:50'38 Page: i Field: Prudhoe Bay,' Co-ordiaate(NE) Reference: Wep: K-08, True North ' Site: PB K Pad Vertical (TVD) Reference: 15 :08 9/24/1985 00:00 56.4 :Well: K-08 Section (VS) Re[erencec Wep (O.OON,O.OOE,240. OOAzi) Wellpath: Plan 3, K-08B Sarvey Caknlation Methode Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zoae: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB K Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973161 .33 ft Latitude: 70 19 57.435 N From: Map Fasting: 670342 .10 ft Longitude: 148 37 5.245 W Position Uncertainty: 0.00 ft North Retereace: True Grouad Level: 0.00 ft Grid Coavergeoce: 1.30 deg Well: K-08 Slot Name: K-08 Well Position: +N/-S 2202.66 ft Northing: 5975372 .00 ft ' Latitude: 70 20 19.098 N +E/-W 384.04 ft Fasting : 670676 .00 ft '` Loagitude: 148 36 54.028 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, K-O8B Drilled From: K-08A Tie-on Depth: 10711.74 ft Current Datum: 15:08 9/24/1985 00 :00 Height 56 .40 ft Above System Datum: Mean Sea Level Magnetic Data: 7/24/2007 Declination: 23.92 deg Field Streegth: 57669 nT Mag Dip Angle: 80.98 deg Vertical Sectioa: Depth Froro (TVD) +N/-S +E/-W Direction ft ft ft deg 30.20 0.00 0.00 240.00 Plan: Plan #3 Date Composed: 7/24/2007 Copy Lamafs Plan 3 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <--- Latitude ---> <- Longitude --,>' Name Description TVD +N/-S +E/-W Northing Eastiog Deg.Min Sec Deb Min. Sec Dtp. Dir. $. ft ft ft ft K-086 Fault 4 56.40 3208.20 -402.11 5978570.00 670201.00 70 20 50.650 N 148 37 5.778 W -Polygon 1 56.40 3208.20 -402.11 5978570.00 670201.00 70 20 50.650 N 148 37 5.778 W -Polygon 2 56.40 3746.66 288.37 5979124.00 670879.00 70 20 55.946 N 148 36 45.601 W -Polygon 3 56.40 4163.98 543.95 5979547.00 671125.00 70 21 0.050 N 148 36 38.131 W -Polygon 4 56.40 4180.65 778.41 5979569.00 671359.00 70 21 0.214 N 148 36 31.279 W -Polygon 5 56.40 4533.94 1297.62 5979934.00 671870.00 70 21 3.688 N 148 36 16.104 W -Polygon 6 56.40 4180.65 778.41 5979569.00 671359.00 70 21 0.214 N 148 36 31.279 W -Polygon 7 56.40 4163.98 543.95 5979547.00 671125.00 70 21 0.050 N 148 36 38.131 W -Polygon 8 56.40 3746.66 288.37 5979124.00 670879.00 70 20 55.946 N 148 36 45.601 W K-O86 Fault 2 56.40 4788.95 -1818.59 5980118.00 668749.00 70 21 6.195 N 148 37 47.179 W -Polygon 1 56.40 4788.95 -1818.59 5980118.00 668749.00 70 21 6.195 N 148 37 47.179 W -Polygon 2 56.40 4423.92 -987.63 5979772.00 669588.00 70 21 2.606 N 148 37 22.891 W -Polygon 3 56.40 4331.67 -582.60 5979689.00 669995.00 70 21 1.699 N 148 37 11.054 W -Polygon 4 56.40 3987.66 -279.33 5979352.00 670306.00 70 20 58.316 N 148 37 2.191 W -Polygon 5 56.40 3793.25 -88.69 5979162.00 670501.00 70 20 56.404 N 148 36 56.620 W -Polygon 6 56.40 3987.66 -279.33 5979352.00 670306.00 70 20 58.316 N 148 37 2.191 W -Polygon 7 56.40 4331.67 -582.60 5979689.00 669995.00 70 21 1.699 N 148 37 11.054 W -Polygon 8 56.40 4423.92 -987.63 5979772.00 669588.00 70 21 2.606 N 148 37 22.891 W K-086 Fault 5 56.40 4058.98 -2972.59 5979362.00 667612.00 70 20 59.012 N 148 38 20.898 W -Polygon 1 56.40 4058.98 -2972.59 5979362.00 667612.00 70 20 59.012 N 148 38 20.898 W -Polygon 2 56.40 3918.29 -2592.66 5979230.00 667995.00 70 20 57.630 N 148 38 9.794 W -Polygon 3 56.40 3760.67 -1865.01 5979089.00 668726.00 70 20 56.082 N 148 37 48.528 W -Polygon 4 56.40 3602.28 -1454.49 5978940.00 669140.00 70 20 54.525 N 148 37 36.531 W -Polygon 5 56.40 3168.93 -830.15 5978521.00 669774.00 70 20 50.264 N 148 37 18.285 W -Polygon 6 56.40 3602.28 -1454.49 5978940.00 669140.00 70 20 54.525 N 148 37 36.531 W -Polygon 7 56.40 3760.67 -1865.01 5979089.00 668726.00 70 20 56.082 N 148 37 48.528 W • • by BP Alaska ~ Baker Hughes INTEQ Planning Report 1NTE Q -Company: BP Amoco DAte: 74/2007 Time: 10:50:38 Page: 2 Field: Prudhoe Bay; Co-ordinate(NE) Refen~ce: Well: K -08, True North .Site: PB K Pad Vertical (TVD) Reference: 15 :08 9/24/1985 00:00 56.4 We1L K-08 ` Section (VS) Retere®ce; Well (O .OON,O.OOE,240. OOAzi) Wellpath: Plan 3, K-0i36 Survey Calculation Method: Minimum Curvature Db: OraGe Targets MaP Map ' <----.Latitude '..-s ~-- [,ongitude -> Name Description TVI) +N/-S +E¢W Narthinft Easdag Deg ,Min Sec'.. Aeg Min Sec `Dip: Dir. ft g ft ft ft -Polygon 8 56.40 3918.29 -2592.66 5979230.00 667995.00 70 20 57.630 N 148 38 9.794 W K-086 Fault 6 56.40 3151.37 -1596.79 5978486.00 669008.00 70 20 50.090 N 148 37 40.686 W -Polygon 1 56.40 3151.37 -1596.79 5978486.00 669008.00 70 20 50.090 N 148 37 40.686 W -Polygon 2 56.40 3159.63 -817.35 5978512.00 669787.00 70 20 50.172 N 148 37 17.911 W -Polygon 3 56.40 3173.39 -59.79 5978543.00 670544.00 70 20 50.308 N 148 36 55.775 W -Polygon 4 56.40 3159.63 -817.35 5978512.00 669787.00 70 20 50.172 N 148 37 17.911 W K-086 Polygon 56.40 3910.10 -1749.58 5979241.00 668838.00 70 20 57.552 N 148 37 45.156 W -Polygon 1 56.40 3910.10 -1749.58 5979241.00 668838.00 70 20 57.552 N 148 37 45.156 W -Polygon 2 56.40 3561.17 -791.20 5978914.00 669804.00 70 20 54.121 N 148 37 17.148 W -Polygon 3 56.40 3811.70 -415.38 5979173.00 670174.00 70 20 56.586 N 148 37 6.166 W -Polygon 4 56.40 3988.94 -1126.58 5979334.00 669459.00 70 20 58.328 N 148 37 26.950 W -Polygon 5 56.40 3990.47 -1720.74 5979322.00 668865.00 70 20 58:342 N 148 37 44.314 W K-086 Fault 1 56.40 4477.61 -270.18 5979842.00 670304.00 70 21 3.135 N 148 37 1.924 W -Polygon 1 56.40 4477.61 -270.18 5979842.00 670304.00 70 21 3.135 N 148 37 1.924 W -Polygon 2 56.40 3944.03 318.87 5979322.00 670905.00 70 20 57.887 N 148 36 44.709 W K-O8B Fault 3 56.40 3972.62 -3221.63 5979270.00 667365.00 70 20 58.162 N 148 38 28.175 W -Polygon 1 56.40 3972.62 -3221.63 5979270.00 667365.00 70 20 58.162 N 148 38 28.175 W -Polygon 2 56.40 4141.26 -2895.69 5979446.00 667687.00 70 20 59.822 N 148 38 18.652 W -Polygon 3 56.40 4219.20 -1881.58 5979547.00 668699.00 70 21 0.591 N 148 37 49.016 W -Polygon 4 56.40 4134.30 -1623.43 5979468.00 668959.00 70 20 59.757 N 148 37 41.471 W -Polygon 5 56.40 4163.27 -1138.61 5979508.00 669443.00 70 21 0.043 N 148 37 27.303 W -Polygon 6 56.40 3980.66 -323.50 5979344.00 670262.00 70 20 58.247 N 148 37 3.482 W -Polygon 7 56.40 3933.85 -200.53 5979300.00 670386.00 70 20 57.787 N 148 36 59.888 W -Polygon 8 56.40 3980.66 -323.50 5979344.00 670262.00 70 20 58.247 N 148 37 3.482 W -Polygon 9 56.40 4163.27 -1138.61 5979508.00 669443.00 70 21 0.043 N 148 37 27.303 W -Polygon 10 56.40 4134.30 -1623.43 5979468.00 668959.00 70 20 59.757 N 148 37 41.471 W -Polygon 11 56.40 4219.20 -1881.58 5979547.00 668699.00 70 21 0.591 N 148 37 49.016 W -Polygon 12 56.40 4141.26 -2895.69 5979446.00 667687.00 70 20 59.822 N 148 38 18.652 HV K-086 Target 4 9046.40 3925.79 -1692.20 5979258.00 668895.00 70 20 57.706 N 148 37 43.479 W K-086 Target 1 9046.40 4633.45 -348.65 5979996.00 670222.00 70 21 4.668 N 148 37 4.217 W K-086 Target 2 9056.40 4504.10 -203.55 5979870.00 670370.00 70 21 3.396 N 148 36 59.977 W K-086 Target 3 9056.40 3908.61 -410.17 5979270.00 670177.00 70 20 57.539 N 148 37 6.014 W Annotation MD TVD ft ft _ 10711.74 8963.59 TIP 10730.00 8974.20 KOP 10750.00 8985.54 End of 9 Deg/100 DLS 10780.00 9003.13 4 10830.00 9027.99 5 10918.90 9045.96 6 11118.90 9054.22 End of 40 Deg/100 DLS 11168.90 9055.94 8 11208.90 9055.93 9 11608.90 9055.90 10 11833.90 9055.89 11 11913.90 9050.76 12 11988.90 9045.93 13 12338.90 9045.70 14 12638.90 9045.55 15 12938.90 9045.43 16 13150.00 9045.36 TD • • by BP Alaska r Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Aml1C0 bate: 74/2007 Time: 10 :50:38 Page: 3 kYiekl: Prudhoe Bay Co-ordinate(NE) Rehreace: 1Neil: K-O8, True North - .Site: PB K Pad Verdead(TVD)Referecce: 15:089/24/1985 00:00 56. 4 Well: K-08 Section (VS)Beferencee Well (O.OON,O. OOE,240.OOAzi) Wellpath: Plan 3, K-086 ' Survey Cakelatioa Method: :'Minimum Curvature Db: OraGe Plan Section Information Ml? Iecl Haim TVD +N1-S +E/-W DLS BaiW Teru TFO Target ft deg deg ft ft ft degNOOft deg/1OOft deg/100ft deg 10711.74 52.86 21.31 8963.59 4534.26 -502.42 0.00 0.00 0.00 0.00 10730.00 56.10 22.94 8974.20 4548.03 -496.82 19.17 17.74 8.93 22.75 10750.00 54.84 24.50 8985.54 4563.11 -490.20 9.00 -6.32 7.78 135.00 10780.00 53.64 39.23 9003.13 4583.70 -477.43 40.00 -3.98 49.10 100.00 10830.00 66.96 56.49 9027.99 4612.29 -445.18 40.00 26.64 34.53 53.00 10918.90 90.00 84.36 9045.96 4640.14 -364.22 40.00 25.91 31.35 53.50 11118.90 86.06 164.34 9054.22 4536.48 -212.25 40.00 -1.97 39.99 94.00 11168.90 90.01 168.87 9055.94 4487.89 -200.68 12.00 7.89 9.05 49.00 11208.90 90.01 164.07 9055.93 4449.02 -191.32 12.00 0.00 -12.00 270.00 11608.90 90.00 212.07 9055.90 4064.45 -245.81 12.00 0.00 12.00 90.00 11833.90 90.00 239.07 9055.89 3908.38 -404.99 12.00 0.00 12.00 90.00 11913.90 97.34 ~ 245.27 9050.76 3871.14 -475.50 12.00 9.17 7.76 40.00 11988.90 90.04 250.55 9045.93 3843.03 -544.78 12.00 -9.74 7.03 144.00 12338.90 90.03 292.55 9045.70 3852.26 -886.87 12.00 0.00 12.00 90.00 12638.90 90.02 256.55 9045.55 3875.65 -1181.03 12.00 0.00 -12.00 270.00 12938.90 90.02 292.55 9045.43 3899.04 -1475.19 12.00 0.00 12.00 90.00 13150.00 90.02 267.21 9045.36 3934.96 -1681.47 12.00 0.00 -12.00 270.00 Sarvey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10711.74 52.86 21.31 8907.19 4534.26 -502.42 5979893.35 670070.54 0.00 -1832.02 0.00 MWD 10725.00 55.21 22.51 8914.98 4544.22 -498.42 5979903.39 670074.31 19.17 -1840.47 22.75 MWD 10730.00 56.10 22.94 8917.80 4548.03 -496.82 5979907.24 670075.82 19.17 -1843.75 22.04 MWD 10750.00 54.84 24.50 8929.14 4563.11 -490.20 5979922.47 670082.10 9.00 -1857.03 135.00 MWD 10775.00 53.71 36.75 8943.77 4580.53 -479.91 5979940.11 670091.99 40.00 -1874.65 100.00 MWD 10780.00 53.64 39.23 8946.73 4583.70 -477.43 5979943.34 670094.40 40.00 -1878.39 92.83 MWD 10800.00 58.69 46.70 8957.87 4595.82 -466.10 5979955.71 670105.45 40.00 -1894.26 53.00 MWD 10825.00 65.54 54.96 8969.57 4609.71 -448.97 5979969.99 670122.26 40.00 -1916.04 48.83 MWD 10830.00 66.96 56.49 8971.59 4612.29 -445.18 5979972.65 670125.98 40.00 -1920.61 44.96 MWD 10850.00 71.86 63.25 8978.63 4621.66 -429.00 5979982.39 670141.95 40.00 -1939.31 53.50 MWD 10875.00 78.29 71.19 8985.07 4630.98 -406.75 5979992.21 670163.98 40.00 -1963.24 51.12 MWD 10900.00 84.92 78.76 8988.73 4637.37 -382.89 5979999.14 670187.68 40.00 -1987.09 49.07 MWD 10918.90 90.00 84.36 8989.56 4640.14 -364.22 5980002.33 670206.28 40.00 -2004.64 47.96 MWD 10925.00 89.83 86.80 8989.57 4640.61 -358.14 5980002.94 670212.35 40.00 -2010.14 94.00 MWD 10950.00 89.14 96.77 8989.80 4639.83 -333.19 5980002.73 670237.31 40.00 -2031.36 94.00 MWD 10975.00 88.47 106.75 8990.32 4634.74 -308.75 5979998.20 670261.86 40.00 -2049.98 93.91 MWD 11000.00 87.86 116.74 8991.12 4625.49 -285.57 5979989.49 670285.24 40.00 -2065.44 93.70 MWD 11025.00 87.30 126.73 8992.18 4612.37 -264.36 5979976.85 670306.75 40.00 -2077.25 93.38 MWD 11050.00 86.83 136.74 8993.46 4595.77 -245.75 5979960.68 670325.73 40.00 -2085.06 92.95 MWD 11075.00 86.45 146.75 8994.93 4576.20 -230.31 5979941.47 670341.60 40.00 -2088.64 92.44 MWD 11100.00 86.19 156.76 8996.54 4554.25 -218.52 5979919.79 670353.89 40.00 -2087.88 91.85 MWD 11118.90 86.06 164.34 8997.82 4536.48 -212.25 5979902.17 670360.57 40.00 -2084.43 91.21 MWD 11125.00 86.54 164.89 8998.21 4530.62 -210.63 5979896.34 670362.31 12.00 -2082.89 49.00 MWD 11150.00 88.51 167.16 8999.29 4506.38 -204.60 5979872.25 670368.90 12.00 -2076.00 48.96 MWD 11168.90 90.01 168.87 8999.54 4487.89 -200.68 5979853.86 670373.24 12.00 -2070.16 48.87 MWD 11175.00 90.01 168.13 8999.54 4481.92 -199.46 5979847.92 670374.59 12.00 -2068.22 270.00 MWD 11200.00 90.01 165.13 8999.53 4457.60 -193.68 5979823.74 670380.92 12.00 -2061.07 270.00 MWD 11208.90 90.01 164.07 8999.53 4449.02 -191.32 5979815.21 670383.48 12.00 -2058.82 270.00 MWD 11225.00 90.01 166.00 8999.53 4433.46 -187.16 5979799.76 670387.99 12.00 -2054.65 90.00 MWD 11250.00 90.01 169.00 8999.53 4409.06 -181.75 5979775.49 670393.96 12.00 -2047.13 90.00 MWD 11275.00 90.01 172.00 8999.53 4384.41 -177.62 5979750.93 670398.64 12.00 -2038.38 90.00 MWD 11300.00 90.01 175.00 8999.52 4359.57 -174.79 5979726.17 670402.04 12.00 -2028.41 90.00 MWD 11325.00 90.01 178.00 8999.52 4334.62 -173.26 5979701.26 670404.13 12.00 -2017.26 90.00. MWD 11350.00 90.01 181.00 8999.52 4309.62 -173.04 5979676.28 670404.92 12.00 -2004.95 90.00 MWD 11375.00 90.01 184.00 8999.52 4284.65 -174.13 5979651.29 670404.40 12.00 -1991.52 90.00 MWD • • by BP Alaska s Baker Hughes INTEQ Planning Report 1NTE Q Company:. BP 14mOCO Date: 7/24/2007 Time: 10:50:38 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: UVelI: K-0$ True North Site: PB K Pad Vertical (TVD) Referenee: 15:08 9!24/198 5 00:00 56. 4 'Welt: K-08 Sectto o (VS) Reference: Well{O.OON,O.OOE,240.OOAzi) Welipath: Pla n 3, K-086 SarveyCalcelatioaMet6od: Minimum Curvature Db: Oracle Survey MD Inc! Azim SS TVD N/S FJW MiapN MapE DLS VS TFO Tool t deg deg ft ft ft ft ft deg/100ft ft deg 11400.00 90.00 187.00 8999.52 4259.77 -176.53 5979626.36 670402.57 12.00 -1977.01 90.00 MWD 11425.00 90.00 190.00 8999.51 4235.04 -180.22 5979601.56 670399.45 12.00 -1961.45 90.00 MWD 11450.00 90.00 193.00 8999.51 4210.55 -185.20 5979576.96 670395.02 12.00 -1944.88 90.00 MWD 11475.00 90.00 196.00 8999.51 4186.35 -191.46 5979552.63 670389.32 12.00 -1927.37 90.00 MWD 11500.00 90.00 199.00 8999.51 4162.51 -198.98 5979528.62 670382.35 12.00 -1908.94 90.00 MWD 11525.00 90.00 202.00 8999.51 4139.09 -207.73 5979505.02 670374.13 12.00 -1889.65 90.00 MWD 11550.00 90.00 205.00 8999.50 4116.17 -217.69 5979481.87 670364.69 12.00 -1869.56 90.00 MWD 11575.00 90.00 208.00 8999.50 4093.80 -228.85 5979459.25 670354.05 12.00 -1848.71 90.00 MWD 11600.00 90.00 211.00 8999.50 4072.04 -241.15 5979437.22 670342.24 12.00 -1827.17 90.00 MWD 11608.90 90.00 212.07 8999.50 4064.45 -245.81 5979429.53 670337.76 12.00 -1819.35 90.00 MWD 11625.00 90.00 214.00 8999.50 4050.96 -254.58 5979415.84 670329.29 12.00 -1805.00 90.00 MWD 11650.00 90.00 217.00 8999.50 4030.61 -269.10 5979395.17 670315.25 12.00 -1782.26 90.00 MWD 11675.00 90.00 220.00 8999.50 4011.04 -284.66 5979375.26 670300.14 12.00 -1759.00 90.00 MWD 11700.00 90.00 223.00 8999.49 3992.32 -301.22 5979356.16 670284.01 12.00 -1735.29 90.00 MWD 11725.00 90.00 226.00 8999.49 3974.49 -318.74 5979337.94 670266.90 12.00 -1711.21 90.00 MWD 11750.00 90.00 229.00 8999.49 3957.60 -337.17 5979320.64 670248.86 12.00 -1686.80 90.00 MWD 11775.00 90.00 232.00 8999.49 3941.70 -356.46 5979304.30 670229.94 12.00 -1662.15 90.00 MWD 11800.00 90.00 235.00 8999.49 3926.83 -376.55 5979288.98 670210.19 12.00 -1637.31 90.00 MWD 11825.00 90.00 238.00 8999.49 3913.03 -397.40 5979274.71 670189.67 12.00 -1612.36 90.00 MWD 11833.90 90.00 239.07 8999.49 3908.38 -404.99 5979269.89 670182.19 12.00 -1603.46 90.00 MWD 11850.00 91.48 240.31 8999.28 3900.26 -418.88 5979261.45 670168.48 12.00 -1587.37 40.00 MWD 11875.00 93.78 242.24 8998.13 3888.26 -440.78 5979248.96 670146.86 12.00 -1562.40 40.02 MWD 11900.00 96.07 244.18 8995.98 3877.03 -463.01 5979237.23 670124.89 12.00 -1537.54 40.10 MWD 11913.90 97.34 245.27 8994.36 3871.14 -475.50 5979231.05 670112.55 12.00 -1523.78 40.27 MWD 11925.00 96.26 246.06 8993.05 3866.60 -485.54 5979226.28 670102.61 12.00 -1512.81 144.00 MWD 11950.00 93.83 247.82 8990.85 3856.84 -508.45 5979216.01 670079.93 12.00 -1488.09 144.09 MWD 11975.00 91.40 249.57 8989.70 3847.77 -531.71 5979206.42 670056.88 12.00 -1463.41 144.25 MWD 11988.90 90.04 250.55 8989.53 3843.03 -544.78 5979201.38 670043.93 12.00 -1449.72 144.33 MWD 12000.00 90.04 251.88 8989.52 3839.46 -555.29 5979197.57 670033.50 12.00 -1438.84 90.00 MWD 12025.00 90.04 254.88 8989.50 3832.31 -579.24 5979189.87 670009.72 12.00 -1414.52 90.00 MWD 12050.00 90.04 257.88 8989.49 3826.42 -603.53 5979183.43 669985.57 12.00 -1390.53 90.00 MWD 12075.00 90.04 260.88 8989.47 3821.81 -628.10 5979178.27 669961.11 12.00 -1366.95 90.01 MWD 12100.00 90.04 263.88 8989.45 3818.49 X52.88 5979174.39 669936.42 12.00 -1343.84 90.01 MWD 12125.00 90.04 266.88 8989.43 3816.48 -677.79 5979171.81 669911.56 12.00 -1321.25 90.01 MWD 12150.00 90.04 269.88 8989.42 3815.77 -702.78 5979170.53 669886.60 12.00 -1299.26 90.01 MWD 12175.00 90.04 272.88 8989.40 3816.37 -727.77 5979170.56 669861.60 12.00 -1277.92 90.01 MWD 12200.00 90.04 275.88 8989.38 3818.28 -752.70 5979171.90 669836.64 12.00 -1257.29 90.02 MWD 12225.00 90.04 278.88 8989.37 3821.49 -777.49 5979174.55 669811.79 12.00 -1237.42 90.02 MWD 12250.00 90.03 281.88 8989.35 3825.99 -802.07 5979178.49 669787.10 12.00 -1218.38 90.02 MWD 12275.00 90.03 284.88 8989.34 3831.78 -826.39 5979183.72 669762.66 12.00 -1200.21 90.02 MWD 12300.00 90.03 287.88 8989.32 3838.83 -850.38 5979190.22 669738.53 12.00 -1182.97 90.02 MWD 12325.00 90.03 290.88 8989.31 3847.12 -873.96 5979197.97 669714.76 12.00 -1166.69 90.02 MWD 12338.90 90.03 292.55 8989.30 3852.26 -886.87 5979202.82 669701.74 12.00 -1158.08 90.03 MWD 12350.00 90.03 291.21 8989.30 3856.40 -897.17 5979206.72 669691.35 12.00 -1151.23 270.00 MWD 12375.00 90.03 288.21 8989.28 3864.83 -920.70 5979214.61 669667.63 12.00 -1135.06 270.00 MWD 12400.00 90.03 285.21 8989.27 3872.02 -944.64 5979221.26 669643.53 12.00 -1117.92 270.00 MWD 12425.00 90.03 282.21 8989.26 3877.95 -968.93 5979226.63 669619.12 12.00 -1099.86 270.00 MWD 12450.00 90.03 279.21 8989.24 3882.59 -993.49 5979230.71 669594.46 12.00 -1080.91 269.99 MWD 12475.00 90.03 276.21 8989.23 3885.95 -1018.26 5979233.50 669569.62 12.00 -1061.13 269.99 MWD 12500.00 90.03 273.21 8989.22 3888.00 -1043.17 5979234.99 669544.67 12.00 -1040.59 269.99 MWD 12525.00 90.03 270.21 8989.21 3888.75 -1068.16 5979235.17 669519.68 12.00 -1019.32 269.99 MWD 12550.00 90.03 267.21 8989.19 3888.19 -1093.15 5979234.04 669494.71 12.00 -997.40 269.99 MWD • by BP Alaska ~ Baker Hughes INTEQ Planning Report 1NTE Q :Company: BP Amoco Date: 7/24/2007 Time: 10:50:38 Page: 5 ' :Field: Prudhoe Bay Co-ordmate(NE) Reference: Welt K-08, True North Site: PB K Pad Vertical (TVI)) Reference: 15:08 9/24/1985 00:00 56.4 Well: K-08 Section (VS) Reference: Well (l).OON,O.OOE,240.OOAzi) Wellpat6 Plan 3',,K-08B Survey Caknlatio® Method: Minimum Curvature Db: Oracle Survey MD Iecl Azim SS TVD N/S E/VV ft deg deg ft ft ft 12575.00 90.03 264.21 8989.18 3886.32 -1118.08 12600.00 90.03 261.21 8989.17 3883.15 -1142.87 12625.00 90.03 258.21 8989.16 3878.69 -1167.47 12638.90 90.02 256.55 8989.15 3875.65 -1181.03 12650.00 90.02 257.88 8989.15 3873.19 -1191.86 12675.00 90.02 260.88 8989.14 3868.58 -1216.42 12700.00 90.02 263.88 8988.13 3865.27 -1241.20 12725.00 90.02 266.88 8989.12 3863.25 -1266.12 12750.00 90.02 269.88 8989.11 3862.55 -1291.10 12775.00 90.02 272.88 8989.10 3863.15 -1316.09 12800.00 90.02 275.88 8989.09 3865.06 -1341.02 12825.00 90.02 278.88 8989.08 3868.27 -1365.81 12850.00 90.02 281.88 8989.07 3872.77 -1390.40 12875.00 90.02 284.88 8989.06 3878.55 -1414.71 12900.00 90.02 287.88 8989.05 3885.60 -1438.70 12925.00 90.02 290.88 8989.04 3893.89 -1462.28 12938.90 90.02 292.55 8989.03 3899.04 -1475.19 12950.00 90.02 291.21 8989.03 3903.17 -1485.49 12975.00 90.02 288.21 8989.02 3911.60 -1509.02 13000.00 90.02 285.21 8989.01 3918.79 -1532.97 13025.00 90.02 282.21 8989.00 3924.72 -1557.25 13050.00 90.02 279.21 8988.99 3929.37 -1581.81 13075.00 90.02 276.21 8988.99 3932.72 -1606.58 13100.00 90.02 273.21 8988.98 3934.78 -1631.50 13125.00 90.02 270.21 8988.97 3935.52 -1656.48 .13150.00 90.02 267.21 8988.96 / 3934.96 -1681.47 MapN MapE DIS V5 TFO Tool. ft' ft deg/100ft ft deg_ 5979231.61 669469.83 12.00 -974.88 269.99 MWD 5979227.87 669445.12 12.00 -951.82 269.99 MWD 5979222.85 669420.63 12.00 -928.29 269.98 MWD 5979219.50 669407.14 12.00 -915.02 269.98 MWD 5979216.80 669396.38 12.00 -904.42 90.00 MWD 5979211.64 669371.92 12.00 -880.84 90.00 MWD 5979207.76 669347.23 12.00 -857.72 90.00 MWD 5979205.18 669322.36 12.00 -835.14 90.00 MWD 5979203.90 669297.40 12.00 -813.15 90.00 MWD 5979203.93 669272.41 12.00 -791.80 90.01 MWD 5979205.27 669247.45 12.00 -771.17 90.01 MWD 5979207.92 669222.59 12.00 -751.31 90.01 MWD 5979211.86 669197.91 12.00 -732.27 90.01 MWD 5979217.09 669173.47 12.00 -714.10 90.01 MWD 5979223.59 669149.33 12.00 -696.85 90.01 MWD 5979231.34 669125.57 12.00 -680.58 90.01 MWD 5979236.19 669112.54 12.00 -671.96 90.01 MWD 5979240.09 669102.15 12.00 -665.11 270.00 MWD 5979247.98 669078.44 12.00 -648.95 270.00 MWD 5979254.62 669054.34 12.00 -631.81 270.00 MWD 5979260.00 669029.93 12.00 -613.74 270.00 MWD 5979264.08 669005.27 12.00 -594.79 270.00 MWD 5979266.87 668980.43 12.00 -575.02 270.00 MWD 5979268.36 668955.48 12.00 -554.47 269.99 MWD 5979268.54 668930.48 12.00 -533.21 269.99 MWD 5979267.41 668905.51 12.00 -511.28 269.99 2.375" • • • by BP Alaska Anticollision Report ~.r iRs 1LNTEQ Company: BP Amoco Date: 7/31/2007 Time: 11:35:10 Page: 1 Fieldc Prudhoe Bay Reference Site: PB K Pad Co-ordinate(NE) Reference: Well: K-08, True North Reference Well: K-08 Vertical (TV1DjReference: t5 : t>8 8/24/1985A0:00 56.4 ltefereoce Wellpath; Plan 3, f<-08B Db: Grade NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Ptan 8< PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 10711.70 to 13 150.00 ft Scau Method: Trav Cylinder North Maximum Radius: 2500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 7/24/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 106.50 10501.09 1 : Schtumberger GCT multishot GCT-MS Schlumberger GCT mulUshot 10557.80 10711.74 MWD (10557.80-12147.80) (1) MWD MWD - Standard 10711.74 13150.00 Planned: Plan #3 V3 MWD MWD -Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 13150.00 9045.63 2.375 4.125 2.375" Summary <---- Oftsef Wellpath -- ----- ; Reference Otfset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warnieg ft ft ft ft if PB E Pad E-03 E-03A V3 10770.00 13500.08 1052.63 276.57 776.06 Pass: Major Risk PB E Pad E-08 E-08A V3 Out of range PB E Pad E-11 E-11 V12 12921.84 10820.00 562.84 0.00 562.83 Pass: Minor 1/10 PB E Pad E-11 E-11A V1 12655.70 11000.00 621.97 475.13 146.84 Pass: Major Risk PB E Pad E-11 E-11 AP61 V2 Out of range PB K Pad K-02A K-02A V1 11025.25 10600.00 1566.04 627.79 938.26 Pass: Major Risk PB K Pad K-02A K-02B V3 11233.19 10500.00 1187.31 691.91 495.40 Pass: Major Risk PB K Pad K-02A K-02C V7 11233.19 10500.00 1187.31 691.91 495.40 Pass: Major Risk PB K Pad K-02A K-02D V5 11233.19 10500.00 7187.31 691.94 495.37 Pass: Major Risk PB K Pad K-02A K-02DPB1 V3 11233.19 10500.00 1187.31 691.96 495.35 Pass: Major Risk PB K Pad K-05 K-05 V4 Out of range PB K Pad K-05 K-05A V5 Out of range PB K Pad K-05 K-05B V1 Out of range PB K Pad K-05 K-05BP61 V12 Out of range PB K Pad K-05 K-05C V6 Out of range PB K Pad K-06 K-06 V4 11833.90 9410.00 2284.01 318.66 1965.35 Pass: Major Risk PB K Pad K-06 K-O6A V1 Out of range PB K Pad K-07 K-07 V2 11540.97 10100.00 2288.46 694.82 1593.64 Pass: Major Risk PB K Pad K-07 K-07A V3 11590.24 10296.79 2275.09 674.27 1600.82 Pass: Major Risk PB K Pad K-07 K-07AP61 V3 11563.17 9800.00 2271.77 659.71 1612.07 Pass: Major Risk PB K Pad K-07 K-07AP62 V5 11563.17 9800.00 2271.77 659.71 1612.07 Pass: Major Risk PB K Pad K-07 K-076 V3 11563.17 9800.00 2271.77 659.71 1612.07 Pass: Major Risk PB K Pad K-07 K-07C V8 12000.00 10600.00 1749.67 282.89 1466.78 Pass: Major Risk PB K Pad K-07 K-07D V2 11750.00 9500.00 2106.39 169.59 1936.79 Pass: Major Risk PB K Pad K-08 K-08 V3 10771.33 10800.00 78.95 191.01 -112.06 FAIL: Major Risk PB K Pad K-08 K-08A V2 10799.75 10800.00 9.81 162.90 -153.10 FAIL: Major Risk PB K Pad K-09 K-09 V1 Out of range PB K Pad K-09 K-09A V1 Out of range PB K Pad K-09 K-09AP61 V1 Out of range PB K Pad K-09 K-09B V2 Out of range PB K Pad K-09 K-096P61 V2 Out of range PB K Pad K-09 K-09C V2 Out of range PB K Pad K-10 K-10 V1 Out of range PB K Pad K-10 K-10A V7 Out of range PB K Pad K-10 K-10AP61 V1 Out of range PB K Pad K-10 K-10AP62 V1 Out of range PB K Pad K-10 K-10APB3 V2 Out of range PB K Pad K-10 K-106 V3 Out of range PB K Pad K-10 Plan K-10C V6 Plan: K- Out of range PB K Pad K-11 K-11 V1 Out of range PB K Pad K-13 Plan K-13A V1 Plan: K- 11535.29 10800.00 1744.39 286.01 1458.38 Pass: Major Risk PB K Pad K-19 K-19 V1 Out of range PB K Pad K-19 K-19A V7 Out of range • • 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 • • • TRANSMITTAL LETTER CHECKLIST WELL NAME ,~. "' ~ PTD# ~~~ " Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK. ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are Production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception.. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (,name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/ 13/2007 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDFiOE BAY UNlT K-086 --Program DEV __ Well bore seg ^ PTD#:2071090 Company BP EXPLORATION (ALASKAa INC Initial Class(fype DEV / PEND GeoArea 890 Unit 11650 On1Off Shore On Annular Disposal ^ Administration 1 Permit fee atlache_d_ _ . - - _ _ _ _ NA_ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ - - 2 Lease number appropriate___________________ _ __________ _____ Yes --___ -____ 3 Unique well-name and number _ __ __ _ _____ __ Yes._ __ -_ __ __ _ ______ ------------------------------------- 4 WelUocatedin-a-defned_pool-. Yes PRUDHOEBAY,_P_RUDHOEOIL-64015Qgoverned_byCO34.1D, 5 Well located proper distance from drilling unitboundary_ Yes - - No restrictions as_to well spacing except that no-pay shall be opened in a well closer than 6 Well.locatedproperdistancefromotherwells__________________-- ----____ Yes_-__-,_ 500 feetic_thebounda-ryofthe_affected_area._------_---_________-__.--_________-__-- 7 Sufficientacreage_avail_ablein_drillingunit----_____-_-__________ _________Yes_____-- -. 8 If_deviated,is_wellboreplat_included__________________________ _________ Yes____.- -____ 9 Operator only affected party__.-______------------ ---------Yes------ ------- 10 Ope[atorhas-appropriate bond in force --- -- - -- -- - - -- Yes-- ---- - - - ----- - -- --- -- -- -- -- ----- - - 11 Permit can be issued without conservation order - - Yes - Appr Date 12 Permit. can be issued without administrative-approval _ _ _ _ _ - - . _ _ - _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -- SFD 8/8/2D07 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_slrata authorized by Injection Order # (puk 10# in-comments)- (For- tJA- 15 All wells-within 114_mile area-of review identified (For service well only)_ _ _ _ __ _ _ _ _ _ _ _ _ _ NA_ _ _ 16 Pre-produced injector; dur_ation_of pr_epro_duction less than 3 months- (For service well only) Nq - 17 Norconven,gasconformstoAS31,05,030(j.1_.A),Q.2.A-D)__ ________ __________N_A_____-- ___________-_ Engineering 18 Conductor st[ing_provided NA_ - - - . - - Conductor setir K-08 (185-179), 19 Surfacecasingpr4tectsall_knownUSDWs______________ _______ ___ ___ _ NA__---- All aquifers exempted,AEO1.._.--_____-___-----_-________ _-_.--.--_____ _-- - 20 CMT-vol adequate-to circul_ate_on conductor & surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ - - - - Surface casing set in K-O8. 21 CMT_vol adequate to tie-in long string to_surf csg- - - - - - - - - - - - - - - - - - - - - NA- - .. - . Production_casing set in-K-08. - - ------------------------------------------------ 22 CMT_wipcoverallkrown-productivehorizors_________ ___________ _______ _ Yes______ ---________ 23 Casingdes~nsadequateforC,_T,B&permafrost------------------ -------- Yes------- --------------- --- ---.----------------------------------- -.- - 24 Adequate tankage_or reserve pit _ , Yes . - - - . _ Rig equipped with steel pits, No reserve pit plann_ed._ All waste-to approved disposal well(s)_ _ _ _ _ _ _ _ _ _ _ _ _ 25 If_a_re-drill, has a 1.0-403 for abandonment beer approved - - - Yes - - 307-2.62 - - - - - - _ -- 26 Adequate_wellbore separatio_n_proposed- - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - -Yes _ _ - _ - _ Proximity analysis performed, Close approaches identified.- Only intone. - - - - - - - _ - - - - - - - _ _ - . 27 If diverter required, does it meet regulations _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ - BOP Stack_will already_be_in place, - - _ - _ _ _ _ _ _ _ _ _ _ _ - _ Appr Date 28 Drilling fluid_pr4gram schematic-8 equip listadequake - - - - - - Yes Maximum expected formation pressure 7,2_EMW, Planned MW 8:6-ppg.- - TEM 8/9/2007 29 BOPEs,-do they meetregulation__._--__._ Yes_______ _____________ ______________________ _________------_____,-__ r ~ 30 BOPE_press rating appropriate; test to_(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ - - - - MASP calculated at 2420psi, 3500-psi_BOP testplanred, - . - - - - _ - _ - _ _ _ _ _ _ _ _ - - . - _ - - _ - ~ r,(q~- 31 Choke manifold complies wIAPI- RP-53 (May 84)- _ _ . - - - . - Yes _ _ _ _ - - - 32 Work will occur without operation shutdown_______ ______________ ________ Yes_____-- --__-____________ --------------- 33 Is presence of H2S gas- probable- - - - - - _ - Yes H2s-is reported at K pad. -Mud should preclude H2S on rig.-Rig has sensors and alarms- - - - - - - - - - - - - - - - 34 Mechanicat_condition of wells within AOR verified (For service well only) - - NA - - Geology 35 Permit can be issued wfo hydrogen- sulfide measures - - - - - No- . K-Pad wells have-measured up to 25 ppm H2S.- - - - ------------------------- 36 _D_atapresented on_ potential overpressure zones- - Yes - _ _ . - - Expected reservoirpressure is 7,2_ppg EMW; will be drilled with 8.6 ppg mud. - . Appr Date 37 Seismic_analysis ofshallow gas-zones- NA Lost circulation risk is high: 3 faults will be crossed.- SFD 818/2007 38 Seabed condition suryey-(if gff-shore) _ - .. - - _ . NA - 39 Contact name/phone for weekly_progress reports (exploratory only] - . NA Geologic Engineering Publ' Commissioner: Date: Commmissioner: p DSate C ' si er Date • C.' • ~~c~~~~ FHB ~' 20~~ ;r Well f-iistory File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special-effort has been made to chronologically organize this category of information. i **** REEL HEADER **** MWD 09/02/10 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/11/04 tapescan.txt 1639492 O1 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 10333.5000: Starting Depth STOP.FT 13106.5000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: K-08B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 57.435"N 148 deg 37' 5.245"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 04 NOV 2007 API API NUMBER: 500292140802 Parameter Information Block #MNEM.UNIT Value SECT. 04 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 56.4 DMF DF EKB .F 0 EDF .F 56.4 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) A71 Formation Evaluation data is realtime data. Page 1 ~~~-t o`~ l~ S`j'~ tapescan.txt (5) Baker Hughes INTEQ utilized coilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and circulating sub, a Drilling Performance Sub (Inner and outer Downhole Pressure, vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic orienting Sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CCNL dated 06 Nov 2007 per BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from K-08A through a milled window in a 3 1/16 inch liner. Top of window 10734 ft.MD (8920 ft.TVDSS) Bottom of window 10739 ft.MD (8923 ft.TVD55) (9) Tied to K-08A at 10712 feet MD (8907.19 feet TVDSS). (10) The interval from 13075 feet to 13108 feet MD (8991.1 feet to 8995.9 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~VG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHZ-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-compensated Borehole corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD55 -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10337.3, 10336.7, ! -0.530273 10344, 10344.1, ! 0.175781 10357.2, 10356.7, ! -0.529297 10360.6, 10360.4, ! -0.176758 10362.7, 10363, ! 0.353516 10366.2, 10366.4, ! 0.176758 10371.5, 10371.3, ! -0.176758 10377.2, 10377.2, ! 0 10734.4, 10737, ! 2.64746 10739.1, 10741.1, ! 1.94238 10740.7, 10743.2, ! 2.47168 10741.6, 10744.1, ! 2.47168 10745.8, 10747.6, ! 1.76562 10748.7, 10751.7, ! 3.00098 10750.6, 10753.6, ! 3.00195 10756.3, 10759.3, ! 3.00098 10759.1, 10761.7, ! 2.64844 10764, 10766.7, ! 2.64844 10766.7, 10769.3, ! 2.64844 10769.9, 10772.2, ! 2.2959 10772.5, 10775.7, ! 3.17871 10776.4, 10778.5, ! 2.11816 10781.7, 10784, ! 2.29492 10785, 1 0787.1, ! 2.11914 10787.1, 10789.8, ! 2.64746 10789.8, 10792.8, ! 3.00195 10792.6, 10795.6, ! 3.00098 10799, 1 0800.7, ! 1.76562 10801.4, 10805.7, ! 4.2373 10806.6, 10809.9, ! 3.35449 10837.4, 10841.7, ! 4.2373 10844.5, 10847, ! 2.47168 10847.5, 10850.2, ! 2.64844 10852.6, 10854, ! 1.41309 10859.5, 10862.2, ! 2.64844 10865.9, 10867.8, ! 1.94238 10880.7, 10882.3, ! 1.58887 10886, 1 0889.3, ! 3.35449 10896.3, 10899.2, ! 2.82422 10914.2, 10917.7, ! 3.53125 10920.9, 10923.2, ! 2.2959 10930, 1 0932.5, ! 2.47168 10938, 1 0940.8, ! 2.8252 Page 2 tapescan.txt 10941.3, 10944.3, ! 3.00195 10945, 10948.7, ! 3.70801 10957.7, 10959.7, ! 1.94238 10963.2, 10965.5, ! 2.2959 10967.6, 10970.1, ! 2.47168 10975.2, 10976.6, ! 1.41309 10977, 10978.6, ! 1.58887 10980.9, 10983.2, ! 2.2959 10985.1, 10987, ! 1.94238 10990.4, 10992.7, ! 2.29492 10994.7, 10997.9, ! 3.17871 10999.6, 11002.6, ! 3.00098 11001.6, 11005.6, ! 4.06055 11016.6, 11019, ! 2.47266 11019.4, 11022.7, ! 3.35449 11027.3, 11030.3, ! 3.00098 11035.6, 11036.7, ! 1.05957 11046.2, 11048, ! 1.76562 11052.4, 11054.5, ! 2.11816 11055.9, 11058, ! 2.11914 11062.3, 11064.8, ! 2.47168 11063.9, 11066.3, ! 2.47168 11067, 11069.9, ! 2.8252 11070.8, 11072.2, ! 1.41211 11074.1, 11076.6, ! 2.47168 11079.3, 11082.3, ! 3.00098 11087.4, 11089.7, ! 2.2959 11092.2, 11094.6, ! 2.47168 11094.6, 11097.1, ! 2.47168 11101.2, 11103.3, ! 2.11816 11103.7, 11107.4, ! 3.70801 11110.3, 11114, ! 3.70703 11116.6, 11121.2, ! 4.59082 11123.9, 11129.7, ! 5.82617 11129.2, 11134.3, ! 5.12012 11161, 11163.9, ! 2.8252 11167, 11170.4, ! 3.35449 11177.3, 11180.8, ! 3.53027 11190, 11194, ! 4.06055 11201.4, 11205.5, ! 4.06055 11205.3, 11209.2, ! 3.88379 11207.4, 11212.9, ! 5.47363 11211, 11215, ! 4.06055 11214.9, 11216.8, ! 1.94141 11227.8, 11232, ! 4.2373 11234.5, 11237.1, ! 2.64844 11237.5, 11240.8, ! 3.35449 11238.5, 11242.6, ! 4.06055 11242.1, 11245.6, ! 3.53125 11246.2, 11249, ! 2.82422 11262.7, 11266.5, ! 3.70801 11273.9, 11276.9, ! 3.00098 11276.2, 11280.4, ! 4.2373 11279.7, 11283.8, ! 4.06055 11280.9, 11285.2, ! 4.23633 11284.1, 11289.4, ! 5.2959 11289.1, 11292.1, ! 3.00195 11370, 11373.5, ! 3.53027 11371.8, 11374.6, ! 2.8252 11391.1, 11394, ! 2.82422 11417.1, 11419.2, ! 2.11816 11457.4, 11459.4, ! 1.94238 11464.3, 11467, ! 2.64844 11467.7, 11470.9, ! 3.17773 11470.2, 11472.5, ! 2.2959 11478.8, 11478.6, ! -0.176758 11490.5, 11492.2, ! 1.76562 11491.7, 11494, ! 2.29492 11510.1, 11511.5, ! 1.41211 11514.3, 11514.3, ! 0 Page 3 i 11515.7, 11516.1, 11545.4, 11547.5, 11551, 11553.7, 11565.3, 11567.8, 11568, 11570.3, 11604.2, 11606.3, 11639.3, 11640.8, 11644.3, 11643.9, 11659.2, 11660.2, 11664.3, 11666.6, 11666.9, 11667.6, 11669.6, 11670.8, 11672, 11674.5, 11674.2, 11676.5, 11677.5, 11680.9, 11689.9, 11689.5, 11695.9, 11696.1, 11702.6, 11702.6, 11704.9, 11704.2, 11707.9, 11707.4, 11709.5, 11709.7, 11712.5, 11713.4, 11722, 11723.1, 11734.6, 11734.4, 11737, 11737, 11739.5, 11739.3, 11757.5, 11760.2, 11761.4, 11766, 11770.9, 11770.7, 11774, 11775.8, 11778.3, 11779.,7, 11796, 11797.4, 11798.4, 11799.3, 11802.7, 11805, 11806.7, 11809, 11812.6, 11814.5, 11815.2, 11816.1, 11817.9, 11818, 11820.3, 11822.1, 11829, 11828.1, 11831.6, 11830.9, 11833.9, 11834.4, 11841, 11842.3, 11844, 11845.6, 11850.2, 11850.6, 11859.9, 11859.7, 11868.9, 11868.7, 11872.6, 11872.3, 11875.9, 11877.7, 11881.6, 11882.8, 11887.7, 11887.6, 11891.1, 11890.4, 11896.6, 11893.9, 11899.7, 11898, 11903.3, 11902, 11914.5, 11914.5, 11933.2, 11933.9, 11939.2, 11940.6, 11946.1, 11946.5, 11953.3, 11953.9, 11955.3, 11956.5., 11959.7, 11959.3, 11967.3, 11966.6, 11975.3, 11974.9, 11976.5, 11976.5, 11979.3, 11978.6, 11983.7, 11985.3, 11993.6, 11994.7, 11995.7, 11996.5, 12007, 12006.5, 0 tapescan.txt 0.352539 2.11816 2.64844 2.47168 2.29492 2.11914 1.41309 -0.353516 1.05957 2.29492 0.706055 1.23535 2.47168 2.2959 3.35449 -0.353516 0.175781 -0.706055 -0.530273 0.176758 0.882812 05957 -0.176758 ! -0.176758 ! 2.64844 ! 4.58984 ! -0.176758 ! 1.76562 ! 1.41309 ! 1.41211 ! 0.882812 ! 2.29492 ! 2.2959 ! 1.94238 ! 0.882812 ! 0.176758 ! 1.76562 ! -0.881836 ! -0.706055 ! 0.529297 ! 1.23535 ! 1.58887 ! 0.353516 ! -0.175781 ! -0.176758 ! -0.352539 ! 1.76562 ! 1.23633 ! -0.176758 ! -0.706055 ! -2.64746 ! -1.76562 ! -1.23535 0 0.707031 1.41309 0.353516 0.529297 1.23633 -0.353516 -0.706055 -0.353516 -0.706055 1.58887 1.05957 0.706055 -0.529297 Page 4 tapescan.txt 12008, 12008.7, ! 0.707031 12009.2, 12010.9, ! 1.76562 12011.6, 12012.4, ! 0.882812 12016.7, 12017.4, ! 0.706055 12017.6, 12019.3, ! 1.76562 12022.2, 12023.9, ! 1.76562 12071.3, 12070.4, ! -0.882812 12077.1, 12075.7, ! -1.41211 12079.9, 12079, ! -0..881836 12084.3, 12082, ! -2.29492 12088.2, 12087.5, ! -0.707031 12095.3, 12096, ! 0.706055 12105.2, 12106.7, ! 1.58887 12145.6, 12146.4, ! 0.882812 12154.7, 12154.2, ! -0.530273 12158.6, 12158.4, ! -0.176758 12193.4, 12197.5, ! 4.06055 12201.2, 12204, ! 2.8252 12209.6, 12212.2, ! 2.64746 12214.3, 12216.1, ! 1.76562 12226, 12227.7, ! 1.76562 12229.3, 12230.4, ! 1.05957 12232, 12232.9, ! 0.882812 12315.5, 12313.6, ! -1.94238 12322.7, 12322.9, ! 0.176758 12353.5, 12356, ! 2.47168 12360.7, 12365.5, ! 4.76758 12395.1, 12397.9, ! 2.8252 12430.6, 12434.1, ! 3.53027 12433.6, 12436.4, ! 2.8252 12437.4, 12440.3, ! 2.8252 12442, 12443.5, ! 1.41211 12446.1, 12447.3, ! 1.23633 12448.7, 12450.2, ! 1.41211 12452.8, 12454, ! 1.23633 12455.6, 12457.6, ! 1.94141 12459.1, 12460, ! 0.882812 12463.5, 12465.3, ! 1.76562 12466.3, 12468.1, ! 1.76562 12471.6, 12473.9, ! 2.2959 12484.1, 12485, ! 0.882812 12517.9, 12517.3, ! -0.529297 12521.6, 12521.2, ! -0.353516 12524.2, 12523.9, ! -0.352539 12552.1, 12552.6, ! 0.529297 12555.6, 12556, ! 0.353516 12562.9, 12564.3, ! 1.41211 12566, 12567.4, ! 1.41211 12573.8, 12575.4, ! 1.58887 12585.1, 12586.4, ! 1.23535 12589.4, 12590.1, ! 0.706055 12681.4, 12682.4, ! 1.05957 12683.5, 12685.6, ! 2.11816 12702.1, 12702.8, ! 0.707031 12713, 12712.6, ! -0.353516 12717.2, 12716, ! -1.23633 12731.7, 12730.3, ! -1.41211 12737.5, 12735.2, ! -2.29492 12738.4, 12737, ! -1.41211 12740.2, 12738.7, ! -1.41211 12746, 12744.6, ! -1.41211 12795.3, 12792.2, ! -3.17773 12821.3, 12819.2, ! -2.11914 12827.9, 12825, ! -2.8252 12832.6, 12830.3, ! -2.29492 12864.4, 12861.9, ! -2.47168 12867, 12863.5, ! -3.53125 12875, 12872.5, ! -2.47168 12902.9, 12898.8, ! -4.06055 12905.5, 12901.3, ! -4.2373 Page 5 A tapescan.txt 12908.5, 12904.5, ! -4.06152 12931.2, 12928.9, ! -2.29492 12934.5, 12931.2, ! -3.35449 12937.9, 12934.3, ! -3.53125 12942.1, 12937.7, ! -4.41406 12962.1, 12958.7, ! -3.35449 12964.7, 12960.9, ! -3.88477 12968.3, 12963.7, ! -4.58984 12970.2, 12966, ! -4.2373 12972.7, 12969, ! -3.70801 12974.4, 12970.4, ! -4.06055 12976.9, 12972.7, ! -4.2373 12978.3, 12974.8, ! -3.53027 13009.5, 13006.2, ! -3.35449 13012.2, 13009, ! -3.17871 13013.6, 13010.4, ! -3.17773 13019.4, 13016.4, ! -3.00098 13021.2, 13018.3, ! -2.8252 13026.1, 13025.6, ! -0.529297 13031.4, 13028.2, ! -3.17773 13036, 13033.5, ! -2.47168 13042.9, 13040.6, ! -2.29492 13049.1, 13047.5, ! -1.58887 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 351 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth shifted to a PDCL from schlumberger GR CCNL dated 06 Nov 2007 per BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Lod Depth scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Page 6 tapescan.txt Name Tool code Samples units size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 155 Tape File Start Depth = 10333.500000 Tape File End Depth = 13106.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 168 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optical Lod Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples units size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 Page 7 tapescan.txt 24 Total Data Records: 309 Tape File Start De th = 10334.000000 Tape File End Depth = 13107.750000 Tape File Level spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape subfile: 3 322 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/11/04 1639492 O1 **** REEL TRAILER **** MWD 09/02/10 BHI O1 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIs Tape subfile 2 is type: LIs DEPTH GR RPD RPS 10333.5000 -999.2500 -999.2500 -999.2500 10334.0000 27.7187 -999.2500 -999.2500 10400.0000 -999.2500 -999.2500 -999.2500 10500.0000 -999.2500 -999.2500 -999.2500 10600.0000 -999.2500 ROP RAD -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Page 8 RAs -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 tapescan.txt -999.2500 -999.2500 10700.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10800.0000 49.2644 117.0641 -999.2500 -999.2500 30.0785 33.1107 10900.0000 110.9010 113.9526 -999.2500 -999.2500 11.7190 12.5236 11000.0000 92.1919 94.3114 -999.2500 -999.2500 17.8431 19.0333 11100.0000 92.9095 140.7755 22.8140 16.1866 18.6281 20.2269 11200.0000 37.3753 168.4573 20.5625 18.0947 19.9210 22.1321 11300.0000 49.0291 157.0806 17.1743 12.9633 12.6740 12.2814 11400.0000 64.0922 134.0541 16.6050 13.9330 13.7784 14.1820 11500.0000 53.7674 212.3331 10.5394 9.2111 10.1189 11.2324 11600.0000 50.4884 132.5001 14.1540 10.8431 10.9850 10.8890 11700.0000 45.7824 154.3175 12.3700 11.1042 12.1273 13.4710 11800.0000 67.1143 140.8715 16.3297 13.5841 14.6090 15.2770 11900.0000 66.7000 124.8000 23.0290 18.8490 16.9430 16.0210 12000.0000 92.0862 13.1656 17.5581 17.7878 17.7800 18.8410 12100.0000 121.4969 40.3882 20.0843 16.0556 19.6570 23.7870 12200.0000 40.1155 102.1794 14.5424 13.1270 13.9860 14.7460 12300.0000 31.8286 157.4852 15.6059 12.4822 14.7284 15.8279 12400.0000 31.7798 136.7125 15.0771 15.0515 16.7162 18.2801 12500.0000 27.2880 136.8574 22.7479 20.5194 21.0000 21.5340 12600.0000 25.8167 190.7907 30.6400 20.9513 25.8847 29.8007 12700.0000 26.7720 106.7160 20.3641 18.6725 22.8180 27.7568 12800.0000 33.9113 77.1000 19.9936 16.5981 17.3500 18.1230 12900.0000 31.0608 117.6333 20.5093 16.4447 18.2130 18.9695 Page 9 tapescan.txt 13000.0000 22.9784 89.4352 27.9604 16.2252 14.8638 13100.0000 -999.2500 80.9992 -999.2500 -999.2500 -999.2500 13106.5000 0.0000 0.0000 0.0000 0.0000 0.0000 Tape File start Depth = 10333.500000 Tape File End Depth = 13106.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RPD RPS 10334.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10334,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10600.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10700.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10800.0000 51.0000 115.4000 98.4010 28.2310 30.5450 10900.0000 79.3000 115.9000 15.6680 12.4520 13.0320 11000.0000 105.6000 91.6000 23.4800 18.4520 19.8580 11100.0000 128.5000 142.7000 26.1120 17.3540 17.2390 11200.0000 42.5000 174.1000 16.8320 16.3660 18.7480 11300.0000 47.0000 132.2000 15.5760 12.8650 13.1250 11400.0000 62.4000 129.7000 15.4010 12.4780 12.6130 11500.0000 53.7000 123.1000 10.4340 10.1930 11.2290 11600.0000 42.8000 133.9000 14.2210 11.0900 10.8890 11700.0000 45.4000 154.7000 12.3700 12.1080 13.4710 11800.0000 70.8000 141.5000 16.2570 Page 10 • 17.7350 -999.2500 0.0000 RAS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 29.3870 11.4930 17.4850 19.4950 13.9150 12.9370 12.2690 9.1850 11.0280 11.1020 13.5410 ~ ~ tapescan.txt 14.6090 15.0990 11900.0000 111.4000 126.3000 16.7440 15.8300 12000.0000 92.5000 12.2000 17.7800 18.8410 12100.0000 116.5000 31.3000 19.4050 23.1080 12200.0000 34.1000 117.7000 14.6050 15.6360 12300.0000 32.3000 203.2000 14.4930 15.4520 12400.0000 32.6000 138.9000 15.9770 17.2320 12500.0000 26.8000 135.8000 23.0290 17.4960 20.3860 14.4970 15.5160 15.0090 18.8910 17.7540 15.6470 13.8260 12.3350 14.6560 21.0000 21.5340 12600.0000 25.4000 178.5000 25.6710 30.0280 12700.0000 24.3000 108.0000 22.8180 28.1360 12800.0000 34.8000 85.7000 17.3500 18.1230 12900.0000 27.4000 122.9000 17.3460 17.6640 13000.0000 21.8000 102.9000 16.7360 15.4480 13100.0000 -999.2500 78.2000 -999.2500 -999.2500 13107.7500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File start Depth = 10334.000000 Tape File End Depth = 13107.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet D Tape Subfile 4 is type: Lis 22.8280 32.1230 20.2340 20.0850 21.0200 27.6970 -999.2500 -999.2500 20.0920 21.3020 19.0170 16.2400 16.4260 17.9390 -999.2500 -999.2500 Page 11
