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209-114
• • 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. a 0 7 - 14_ Well History File Identifier Organizing (done) ❑ Two -sided III IIIIIIIIII III ❑ Rescan Needed III 1111111 111111 R AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 3 I I /s/ fl') Project Proofing III I'III II 1111 BY: AMP Date: 1 /3 1 II /s/ f _ Scanning Preparation x 30 = + = TOTAL PAGES a (Count does not include cover sheet) ll BY: Mari ) Date: Y 3I ' /s/ d Production Scanning III EMI I 11111 Stage 1 Page Count from Scanned File: c)\U (Count does include cover heet) Page Count Matches Number in Scanning Preparation: (/ cover NO I / BY: Date: ( 31 It /s/ t Y'V1F 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. I 11111 I III ReScanned I I I III I BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III IIII III 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 1/27/2011 Permit to Drill 2091140 Well Name /No. PRUDHOE BAY UN ORIN L -203L5 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23416 -65 -00 MD TVD Completion Date Completion Status Current Status UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? Y / N Chips Received? Y / N Formation Tops Y / N • Analysis Y / N Received? Comments: W., � � P:1 L..L. Compliance Reviewed By: �� Date: /` d N a L d I1 L C To: Alaska Oil & Gas Conservation Commission From: Mark Staudinger, ODE Date: November 13, 2009 Re: L -203 Permit to Drill Revision This ermit revision reflects recent changes in the plan for the upper 2 laterals on L -203 with a scheduled spud date in January g P PP > P Y 2010. After drilling L -223i in October 2009, the drilling logs provided information on the Schrader Bluff reservoir fluids that was utilized in amending the design of L -203; the wet Nb sand encountered in L -223i necessitated dropping the planned southeasterly Nb lateral, and shortening and moving the northwesterly Nb lateral updip. L -203 will not be a six lateral producer, not a seven lateral producer. Therefore, L -203L5 (PTD #209114) will no longer be drilled and L -203L4 (PTD #209113) will be revised to reflect the directional changes described above. The new Drilling AFE time and cost estimate will be 64.5 days and $18.1 MM. The following permit reflects the changes in red to show the new planned L -203 L4 in the Nb sand: Revised L -203 Permit to Drill 1 • 0 ark h ) r '_ j k r "p r K z ¢' 1 } 4 r F t c t t t s k t p k� V F SEAN PARNELL, GOVERNOR V ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE 907 279-1433 FAX (907) 276 -7542 Mr. Robert Tirpack Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Orion Schrader Bluff, L -203L5 BP Exploration (Alaska) Inc. Permit No: 209 -114 Surface Location: 2583' FSL, 3647' FEL, SEC. 34, T12N, R11E, UM Bottomhole Location: 1309' FSL, 3907' FEL, SEC. 26, T12N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well PBU L -203, Permit No. 209108, API No. 50- 029 - 2341600 -00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Y Cathy . Foerster Com issioner DATED this. day of September, 2009 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA REC %V ED _Afe- ALASIOOJIL AND GAS CONSERVATION COMMON �,Oj PERMIT TO DRILL SEP 2 3 2.009 20 AAC 25.005 g GI Bs Co ns- Co scion 1 a. Type of work: 1 b. Proposed Well Class: _I Development Oil ❑ Service - Winj ❑ Single Zone 104.114 c G II i • �• pos ed fo Strati ra hic Test Development Gas Service - Supply Multiple Zone ❑ Coal ' W i as Hydrates ® Drill ❑Redrill ❑ 9 P � ❑ P ❑ PP Y ❑ P Y ❑ Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 L -203L5 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 - 6612 MD 13112' TVD 4443' Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): • Schrader Bluff Surface: ADL 028239 & 028238 2583' FSL, 3647' FEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1771' FSL, 1' FEL, SEC. 27, T12N, R11E, UM (NB) January 1, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1309' FSL, 3907' FWL, SEC. 26, T12N, R11E, UM 2560 860' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: —78.4' feet 15. Distance to Nearest Well Open Surface: x- 583267 y- 5978306 Zone - ASP4 GL Elevation above MSL: 49.9' feet to Same Pool: 685' 16. Deviated Wells: Kickoff Depth: 7971 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 90 degrees Downhole: 2160 Surface: 1713 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 6 -3/4" 4 -1/2" 12.6# L- 80/13Cr IBT -MNam 5166' _ 7946' 4293' 13112' 4443' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 13826' 4743' None 13826' 4743' None Casing Length Size Cement Volume MD TVD Conductor / Structural 108' 20" x 34" 7260 sx Arctic Set 108' 108' Surface 4066' 10 - 3/4" 662 sx Arcticset Lite. 476 sx Class 'G' 4066' 2805' Intermediate 9456' 7 - 5/8" 201 sx LiteCrete. 499 sx Class '0' 9456' 4683' Production Liner 4520' 4 -1/2" (L -203) Uncemented Slotted Liner 9306' - 13826' 4669' - 4743' See Attached Docs for Planned ML Liner Info Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: ❑ Property Plat ❑ BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ 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 Mark Staudinger, 564 -4337 Printed Name Robert Tirpac Title Engineering Team Leader c� Prepared By Name/Number Signature � i C x �1'� Phone 564 -4166 Date //2 �/ Terris Hubble, 564 4628 Commission Use Only Permit To Drill API Number: / Permit Approval rte: See cover letter for Number: 67W9//4 50- 04799!x',66 - oa WV Ot I other requirements ,�,/ Conditions of Approval: If box is checked, well may - n , _ used to explore for, test, o r pr od uce ,,_,/ coalbed methane, s hydrates, , g Y or gas contained shales: B y Other: Af 3560 Pc- ,VD P Te7s- ,L Samples Req'd: Oyes �J No Mud Log Req'd: ❑ xes I ' No A \ h� HS Measures: Yes ❑ No Directional Survey Req'd: Yes ❑ No 2500 psi J.,t 14-sf \ APPROVED BY THE COMMISSION Date 9 -38- 0 ( �� ?� COMMISSIONER Form 10-401 Revised 07/2009 fi i al d r 4 months from the da of approval (20 AAC 25.005(g)) Submit In Duplicate Well Name: 1E633, L- 203L1, L- 203L2, S203L2-01 L- 203L3, L- 203L4, and L -203L5 Drill and Complete Plan Summary Type of Well (producer or injector): Multilateral Producer: Schrader Bluff Nb, OBa, OBc, and OBd sands Target X Y Z TVDss Township Range Section FSL FEL Surface 583267.3 5978305.5 78.4 12N 11E 34 2582 3646 L -203 OBd Target 587270 5983290 -4605 12N 11E 26 2242 4859 Reservoir Top: L -203 OBd Bottom 584660 5987580 -4665 12N 11E 22 1282 2133 Hole Location: L -203L1 OBd Target 587683 5984428 -4617 12N 11E 26 3375 4431 Reservoir Top: L -203L1 OBd Bottom 589850 5983460 -4670 12N 11E 26 2382 2277 Hole Location: L -203L2 OBc Target 587284 5983677 -4530 12N 11E 26 2629 4840 Reservoir Top: L -203L2 OBc Bottom 590930 5982720 -4640 12N 11E 26 1629 1206 Hole Location: L- 203L2 -01 OBc 587226 5983902 -4547 12N 11E 26 2855 4895 Target Top: L- 203L2 -01 OBc 584660 5987580 -4610 12N 11E 22 1282 2133 Bottom Hole: L -203L3 OBa Target 587025 5983736 -4429 12N 11E 26 2691 5098 Reservoir Top: L -203L3 OBa Bottom 585080 5984700 -4450 12N 11E 27 3677 1751 Hole Location: L -203L4 Nb Target 587230 5983896 -4290 12N 11E 26 2849 4891 Reservoir Top: L -203L4 Nb Bottom 584660 5987580 -4335 12N 11E 22 1282 2133 Hole Location: L -203L5 Nb Target 586854 5982814 -4222 12N 11E 27 1771 1 Reservoir Top: L -203L5 Nb Bottom 590768 5982398 -4365 12N 11E 26 1309 1373 Hole Location: AFE Number: ORD5M4209 1 R g: Nabors 9ES 1 GL: 49.9' 1 RT: 28.5 1 RTE: 78.4 Estimated Start Date: 1 January 1 , 2010 1 1 Operating days to complete: 1 77.5 Contacts: Operations Drilling Engineer Mark Staudinger (564 -5733) Geologist Joe Turak (564 -4204) / Micaela Weeks (564 -5635) PE Egor Makarov (564 -5687) / Taylor West (564 -4647) Well Information Distance to Nearest Property: 860' to PBU boundary from L -203 (NW) OBd Lateral Distance to Nearest Well in Pool: 685' from L -215 well bore at the top Oba level (4415' TVDss) Well Type: Schrader Bluff Septa - lateral Producer (7 laterals total) Current Status: New well Conductor: 34" X 20" Insulated @ -80' G.L. BHT: 50 °F @ 2715' TVDss 81 °F @ -4200' TVDss (Top of Pool) 88 °F @ -4605' TVDss (7 -5/8" Csg Shoe) BHP: 8.5 - 9.3 EMW ppg in producing Schrader sands L -203 Permit to Drill 1 ` Formation Markers: • a Est. Commercial Formation Hydrocarbon Est. Pore Tops Uncertainty Bearing Press. Est. Pore Press. Formation (TVDss) (feet) (Yes /No) _ (Psi) (ppg EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells G1 -255 +/ -50' No 115 8.7 SV6 -885 +/ -50' No 398 8.7 Fault #1 (L Pad Fault) -1030 +/- 100' M.D. SV5 -1470 +/ -50' No 662 8.7 SV4 -1600 +/ -50' No 720 8.7 Base Permafrost -1685 +/ -50' No 758 8.7 SV3 -1965 +/ -50' Gas Hydrates 884 8.7 SV2 -2130 +/ -50' Gas Hydrates 959 8.7 SV1 -2475 +/ -50' Gas Hydrates 1114 8.7 Thin coal + Gas UG4 -2795 +/ -50' Hydrates 1258 8.7 Heavy Oil between - UG4A -2825 +/ -50' 2825 and -3025' SS 1271 8.7 Fault #2 -3200 +/- 100' M.D. UG3 (faulted top) -3200 +/ -50' Thin coals 1440 8.7 Fault #3 (possible) -3640 +/- 100' M.D. Heavy Oil from -3750' to UG1 -3680 +/ -50' -3930' SS 1656 8.7 Heavy Oil from -3950' to UG_Ma -3950 +/ -50' -3980' SS 1778 8.7 Heavy Oil from -3985' to UG_Mbl -3985 +/ -50' -4055' SS 1793 8.7 Heavy Oil from -4065' to UG_Mb2 -4065 +/ -50' -4150' SS 1840 8.7 UG_Mc -4150 +/ -50' No 1880 8.7 SB_Na -4200 +/ -25' No 1869 8.6 SB_Nb -4225 +/ -25' Yes 1880 -2000 8.6 -9.1 SB_Nc -4245 +/ -25' Yes 1889 8.6 SB_Ne -4255 +/ -25' Yes 1893 8.6 SB_OA -4345 +/ -25' Yes 1950 -2100 8.6 -9.3 SB_OBa -4415 +/ -25' Yes 1965 -2200 8.6 -9.3 SB_OBb -4470 +1 -25' Yes 1971 -2160 8.5 -9.3 SB_OBc -4530 +/ -25' Yes 2016 8.6 8.3 (L1 Lateral) to 8.6 (L -203 SB_OBd -4590 +/ -25' Yes 1900 -2000 OBd lateral) Fault #4 (possible) - Possible fault - 11,610' M.D. in OBd motherbore (wp11). If OBd, Obc, Nb NW legs present, then would also be expected in overlying Obc, Nb only -4661 +/- 150' M.D. laterals. -4650, not SB_OBe reached +/ -25' Yes 2 L -203 Permit to Drill ' Mud Program: 13 -1/2" Surface Ho le Mud Properties: 1 Spud - Drilplex AR Mud Interval Density (ppg) Funnel vis LSYP YP PH FL Initial to Base 8.5 — 9.5 60 -120 (for reference only. Fluid 40 -60 50 -70 10.8 -11 NC Permafrost should be run off LSYP) Base PF to TD 8.5 — 9.5 Same 30 -50 55 -60 10.8 -11 NC 9-7/8" Intermediate Hole Mud Properties: Freshwater Mud (LSND) Interval Density (ppg) YP PV API Filtrate MBT pH Chlorides Surface shoe to interval TD 9.4 -9.6 18 -24 8 -18 <6.0 < 20 9.0 -10 <600 6-3/4" Production Hole Mud Properties: 1 LVT -200 MOBM (Versa -Pro) Interval Density (ppg) Stability Oil: Water Ratio YP PV API Filtrate All Seven Laterals 9.4 -9.6 >600 80:20, initial 15 -19 <28 <5 Survey and Logging Program: 13 -1/2" Hole Section: Surface Gyro may be needed Open Hole: MWD / GR — real time Cased hole: None 9 -7/8" Intermediate Hole: Surveys will be IIFR corrected real time and multi- station Open hole: MWD / GR / Res / Azimuthal Den / Dens Caliper / Neu / PWD Cased Hole: USIT (asset required) 6 -3/4" Production Holes: Surveys will be IIFR corrected real time and multi- station Open hole: MWD / GR / Res / Azimuthal Den / Dens Caliper / Neu / AIM — real time Cased Hole: N/A Casing/Tubing Program Hole Size Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Tbg O.D. (psi) (psi) MD / TVD MD / TVD RKB RKB 48" 20" X 34" 215.5# A53 Weld GL 108'/108' 13 -1/2" 10 - /a" 45.5# L -80 BTC 5,210 2,470 4066' GL 4066' / 2805' 9 - %" 7 -%" 29.7# L -80 BTC -M / 6,890 4,790 9456' GL 9456' / 4683' TCII 6 - /a" L -203 4 -' /z" 12.6# L -80/ IBT -M / N/A N/A 4520' 9306' / 4669' 13826' / 4743' OBd slotted /solid 13Cr Vam Top 6 - L -203 4 -Y2" 12.6# L -80/ IBT -M / N/A N/A 3296' 9069' / 4633' 12365' / 4748' L1 OBd slotted/solid 13Cr Vam Top 6 - L -203 4 -'/2" 12.6# L -80 IBT N/A N/A 5028' 8834' / 4583' 13862' / 4718' L2 OBc slotted /solid 6 - L -203 4 -1/2" 12.6# L -80 IBT N/A N/A 4606' 9200' / 4625' 13806' / 4688' L2-01 OBc slotted /solid 6 -'h" L -203 4 -'/2" 12.6# L -80/ IBT -M / N/A N/A 3092' 8139' / 4363' 11231' / 4528' L3 OBa slotted/solid 13Cr Vam Top 6 - L -203 4 -'/2" 12.6# L -80/ IBT -M / N/A N/A 5705' 8057' / 4333' 13762' / 4413' L4 Nb slotted /solid 13Cr Vam Top 6 -3/4" L -203 4 -1/2" 12.6# L -80/ IBT -M / N/A N/A 5166' 7946' /4293' 13112' / 4443' L5 Nb slotted /solid 13Cr Vam Top Tubing 4 -1/2" 12.6# 13 -Cr Vam Top 8,430 7,500 7886' GL 7886' / 4271' Surface and Anti - Collision Issues Surface Shut -in Wells: • L -216 and L -217 will require surface shut -in and well house removal in order to move over well L -203. Close Approach Shut -in Wells: • L- 215PB2 fails major risk scan on L -203 —L1 (OBd SE) and —L2 (OBc SE). L- 215PB2 was analyzed with the Tolerable Collision Risk Worksheet and determined that close approach tolerances need not be set. • Reference the anti - collision scan for a full list of offset well paths. 3 L -203 Permit to Drill Cement Calculations Casing Size: 110-3/4" 45.5-lb/ft L -80 BTC surface casing Basis: Lead: 250% excess over gauge hole in permafrost, 40% excess over gauge hole below permafrost Lead TOC: Surface (A TAM collar may be run as contingency) Tail: 1,000' of open hole with 40% excess, plus 80' shoe track Tail TOC: 1,000' MD above shoe Total Cement Volume: Spacer 50 bbls of Viscosified Spacer weighted to -10 ppg (Mud Push) Lead 525 bbls, 2946 cuft, 662 sks 10.7 lb/gal Arctic Set Lite - 4.45 cuft/sk Tail 98 bbls, 552 cuft, 476 sks 15.8 lb/gal Class G + adds -1.16 cuft/sk Temp BHST -50° F In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 7- 29.7-lb/ft L -80 BTC -M x VTHC intermediate casing Basis: Lead: 2390' of open hole with 30% excess Lead TOC: 1000' below the surface shoe Tail: 2000' of open hole with 30% excess, plus 80' shoe track Tail TOC: 2000' above the intermediate shoe Total Cement Volume: Spacer 50 bbls of Viscosified Spacer (Mudpush) Weighted to 10.3 ppg Lead 119 bbls, 667 cult, 201 sks, 11.0 Litecrete -1.11 cuft/sk Tail 103 bbls, 579 cuft, 499 sks 16.3 lb/gal G + Gasblok + Durastone- 1.16 cuft/sk Temp BHST - 90° F Centralizer Recommendations 10 -3/4" Casing Centralizer Placement a) Run (25) 10 -3/4" Bow - spring centralizers attached over the collar of each joint of casing from the casing shoe up to 1,000' MD above the shoe. 7 -%" Casing Centralizer Placement a) Spaceout the 7-%" casing to place a full joint in the window area of the OBd, OBc, OBa and Nb sands. b) Except for a) above, run two centralizers per joint to the TOC c) Place 1 RA tag below each window exit. RA tags to be spaced out -50' below the windows. 4 L -203 Permit to Drill ' Well Control • Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind /shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. Due to surface pressures not exceeding 3,000psi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency will be 14 days, with a function test every 7 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Variance Request • To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. • To mitigate any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. Surface Hole A diverter will be nippled up and function tested prior to drilling surface hole Intermediate Section • Maximum anticipated BHP: 2,160 psi — Schrader OBb (9.3 ppg @ 4,470' TVDss) • Maximum surface pressure: 1,713 psi — Based on a full column of gas CO 0.10 psi /ft • Planned BOP test pressure: 3,500 psi/250 psi Rams 2,500 psi /250 psi Annular • 10 -3/4" Casing Test: 3,500 psi • Integrity Test 9 -7/8" hole: LOT • Kick Tolerance: 53 bbls with a minimum 11.2 ppg EMW LOT, 9.4 ppg MW Production Section • Maximum anticipated BHP: 2,160 psi — Schrader OBb (9.3 ppg © 4,470' TVDss) • Maximum surface pressure: 1,713 psi — Based on a full column of gas @ 0.10 psi /ft • Planned BOP test pressure: 3,500 psi /250 psi Rams 2,500 psi /250 psi Annular • 7 -5/8" Casing Test: 3,500 psi • Integrity Test — 6 -3/4" hole: LOT for L -203 OBd production interval only • Kick Tolerance: Infinite at OBd, OBc, OBa, and Nb with a minimum 10.1 ppg EMW LOT • Planned completion fluid: 9.6 ppg SF OBM in Laterals, 9.6 ppg Brine, 6.8 ppg diesel in mother bore Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS -04 for injection. Haul all Class I waste to Pad 3 for disposal. 5 L -203 Permit to Drill Drillir Hazards and Continc ncies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The target sands in the Schrader are potentially over - pressured do to nearby water injection from L -2151 and L -2161. A maximum pressure of 9.3 ppg EMW can be expected in the N and 0 Sands. II. Hydrates and Shallow gas A. Gas Hydrates are expected at L -pad from the SV5 thru the SV1 sands below the base of the Permafrost. Setting surface casing below deepest SV1 sand hydrate zone will isolate gas bearing intervals from the intermediate section. If hydrates are encountered, recommended practices and precautions for drilling hydrates should be followed in the surface hole. III. Lost Circulation /Breathing A. There is a low risk of lost circulation and breathing anticipated in L -203. If lost circulation occurs, follow the LCM decision tree. IV. Kick Tolerance/Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Maximum Influx Mud Exp Pore Min LOT / FIT Interval Volume Weight Press Surface / 9 ' /8 " 53 9.4 8.6 - 9.3 11.2 (LOT) Intermediate / 6 3 / 4 " Infinite 9.4 8.6 — 9.3 10.1 (LOT for OBd lateral only) All LOT will be performed with a minimum of 20 -ft and a maximum of 50-ft of new hole drilled outside of the previous casing string. A LOT will only be performed for the first OBd lateral, not the OBc, OBa, or Nb. V. Hydrogen Sulfide Standard Operating Procedures for H precautions should be followed at all times. L Pad gas lift wells are expected to have H levels in the 10 to 250 ppm range as a result of using PBU gas lift gas. Recent H data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L -201 20 ppm L -202 10 ppm L -202 10 ppm L -250L1 20 ppm VI. Faults A. Two faults are expected to be crossed by V -207, with another two possible fault crossings. The first 3 faults are expected in the intermediate section, and no losses are expected to be associated with these faults. The fourth fault will possibly be crossed in the OBd (motherbore), OBc (L2 -01), and Nb (L4) laterals, and no losses are expected from this fault. MD TVDss Throw Formation Where Encounter Fault Intersect Intersect Est. Throw Direction Uncertainty Fault #1 - L Pad Fault (SV6) 1110 -1030 -40 to -60' West +/- 100' M.D. Fault #2 - Ugnu UG3 5195 -3215 -50 to -80' West +/- 100' M.D. Fault #3 (possible) - Ugnu UG1 6365 -3640 0 to -30' South +/- 100' M.D. Fault #4 (possible) - Schrader OBd, OBc, Nb (northwest legs only) 11610 -4661 0 to +10' South +/- 100' M.D. 6 L -203 Permit to Drill CONSULT THE V -PAD 4111 SHEET AND THE WELL PLAN F DDITIONAL INFORMATION L- 203(OBd NW), L1(OB SE), L2(OBc SE), L2 -01 (OBc NW), L3(Oba NW), L4 (Nb NW) DRILL AND COMPLETE PROCEDURE SUMMARY Phase Pre -Rip Work: PRE 1. A 34" x 20" insulated conductor must be installed and surveyed. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. Level the pad and prepare location, as necessary, for rig move. Prepare neighboring wells for the rig move. Shut in wells and remove neighboring well houses as necessary. - Drilling Rig Operations: PRE 1. MIRU Nabors 9ES. Position mud pits. Nipple up diverter spool and riser. Prepare Drilplex Mud. PU 5" DP and stand back in derrick (approx 4500'). Function test diverter. SURF 2. MU 13 -1" drilling BHA with MWD /GR and directionally drill surface hole to the BPRF. Perform DRILL short trip then drill the surface hole to TD. CBU, then conduct another wiper trip to the previous trip depth, RIH to TD. CBU as necessary, POOH, LD BHA. SURF 3. Run and cement the 10 -3/4', 45.5 #, L -80 BTC (Burst: 5210psi, Collapse: 2480psi) surface casing CASE back to surface. Test the casing to 3500psi at plug bump. 4. ND Diverter and riser and NU wellhead and test to 1000psi. NU BOPE (rams for 5" DP) and test to 250 psi low and 3,500 psi high. Retest BOPE every 14 days. Notify AOGCC 24 hours in advance of test. 5. PU 5" DP as necessary to TD intermediate hole. INT1 6. MU 9 - %" drilling BHA with MWD /GR/Res /AzmDen /Neu /PWD. RIH to float collar. DRILL 7. Drill out shoe track and displace the well to new 9.4 LSND drilling fluid. Drill 20' of new formation and perform a LOT. Establish benchmark ECD's. 8. Directionally drill ahead to TD. Optimize connection and hole cleaning practices for high angle ERD holes. After TD, CBU, backream / MAD pass for logs as required. POOH, LD BHA. LD 5" DP. 9. Change out rams to 7 -5/8" for casing run. Test to 250/3500 psi, record in DIMS. INT1 10. RU and run 7 -% ", 29.7 #, L -80, BTC -M x TCII casing to TD. Cement in one stage to 1000' below CASE the surface shoe. Bump plug with mud. At plug bump, pressure test the casing to 3500 psi. 11. Install 7 -5/8" pack -off and test to 5000 psi for 10 minutes. Perform annulus LOT /injection test. Freeze protect 7 -%" x 10 -3/4" annulus to 2,200' TVD off critical path. 12. Change out rams to 3- 1/2 "x6" and test for 4" DP and 4 -1/2" Liner. Test to 250/3500 psi. 13. PU 4" DP as necessary to TD the production holes. PROD1 L -203 OBd (NW) Lateral (LEM, LH, LTP, SV Centralizers) DRILL 14. PU 6 - /d' drilling BHA with MWD /GR/Res /Neu /Den /Density Caliper /PWD /AIM and RIH to the float collar. 15. Drill out shoe track, circulate and condition mud. Displace well over to 9.4 ppg Versapro MOBM. Drill 20' of new formation and perform LOT. Obtain benchmark ECD readings and SPR's. 16. Directionally drill geo- steering to TD. Optimize connection and hole cleaning practices for horizontal holes. 17. At TD, pass then MAD ass and back ream out of the hole to the shoe, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. 18. POOH an LD drilling BHA. PU 4 -3/4" DC's as necessary for the liner run. 19. Spaceout TOL for next whipstock. MU & RIH the straight -vane centralized 4 -'h" 12.6# L- 80/13Cr- 80 IBTNam Top slotted liner & blank liner /swell packers with liner hanger, liner top packer, and seal bore extension. 20. Circulate one DP volume. Drop ball, seat and pressure up to set the liner hanger, then release running tools. PU then set weight on liner top packer to set. PU and pressure test the liner top packer to 1500 psi for 10 minutes before un- stinging. CBU, POOH. 7 L -203 Permit to Drill OTHCMP 21. RU Schlumbergit L and run USIT log on tractor. This log IL run in SF MOBM. EVAL PROD2 L -203 L1 OBd (SE) Lateral (LEM. LTP. Volants) DRILL 22. PU the 7-%" whipstock assembly with spaceout assembly below it to set down the whipstock on the prior liner top packer such that the top of the window is placed at MD per directional plan. Orient, set, & shear off Whipstock. Displace well over to 9.4 ppg Versapro MOBM. Mill window. POOH. Flush BOP stack & function rams. 23. PU 6 - /a" drilling BHA with MWD /GR/Res /Neu /Den /Density Caliper /PWD /AIM and RIH. Conduct Shallow hole tests as necessary. 24. Directionally drill ahead to TD geo- steering to TD. Optimize connection and hole cleaning practices for horizontal holes. 25. At TD, CBU then MAD pass and back ream out of the hole to the shoe, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. 26. POOH and LD drilling BHA. 27. MU whipstock retrieval tool and pull whipstock. CBU, POOH 28. Spaceout TOL to facilitate next whipstock location. MU & RIH the Volant Hydro -form centralized 4- 1 /2" 12.6# L- 80/13Cr -80 IBTNam Top slotted/blank liner with bent joint, hook hanger and swell packers. Set hook hanger, drop ball, and pressure up to release HR running tool. POOH. 29. Run Baker Lateral Entry Modules with seal assembly, LEM, Seal bore extension, ZXP liner top packer, and hydraulic setting tool. Drop ball, seat, and set the ZXP packer, increase pressure to release HR running tool. Close rams and test ZXP to 1500 psi for 10 minutes before un- stinging. CBU, POOH. PRODS L -203 L2 OBc (SE) Lateral (complete w/ billet, Volants1 DRILL 30. PU the 7 -%" whipstock assembly with spaceout assembly below it to set down the whipstock on the prior liner top packer such that the top of the window is placed at MD per directional plan. Orient, set, & shear off Whipstock. Displace well over to 9.4 ppg Versapro MOBM. Mill window. POOH. Flush BOP stack & function rams. 31. PU 6 - drilling BHA with MWD /GR/Res /Neu /Den /Density Caliper /PWD /AIM and RIH. Conduct Shallow hole tests as necessary. 32. Directionally drill ahead, geo- steering to TD. Create a 200' straight interval above planned billet placement. Optimize connection and hole cleaning practices for horizontal holes. 33. At TD, CBU then MAD pass and back ream out of the hole to the shoe, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. 34. POOH and LD drilling BHA. 35. MU and run 4 - 12.6# L -80 IBT slotted and solid liner with swell packers, Volant Hydro -form centralizers, aluminum billet, and GS spear. Locate billet in the 200' straight section to facilitate low side right or left, open hole side track. Slack off -10k Ibs while pumping to release the spear. POOH. PROD4 L -203 L2 -01 OBc (NW) Lateral (trench off billet. Complete w/ hook, sliding sleeve, LTP, & DRILL Volants above billet) 36. PU 6 -3/4" drilling BHA with MWD /GR/Res /Neu /Den /Density Caliper /PWD /AIM and RIH. Conduct Shallow hole tests as necessary. When near TD, log down to tie -in depth and tag aluminum billet. 37. Displace well over to 9.4 ppg VersaPro MOBM. 38. Orient and trench, kicking off from the aluminum billet into the OBc sand. Work pipe across billet before drilling ahead. 39. Drill to TD, CBU then MAD pass and back ream out of the hole to the shoe, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. 40. POOH and LD drilling BHA. 41. MU whipstock retrieval tool and pull whipstock. CBU, POOH 42. Spaceout TOL for next whipstock. MU & RIH the 4 - 12.6# L -80 BTC -M slotted liner & blank liner with bent joint, swell packers and Volant centralizer's (used above the billet on prior lateral). Set hook hanger, drop ball, and pressure up to release HR running tool. POOH. 8 L -203 Permit to Drill 43. Run Baker seal ambly, sliding sleeve (not LEM), Seal boraension, ZXP liner top packer, and hydraulic setting tool. Drop ball, seat, and set the ZXP packer, increase pressure to release HR running tool. Close rams and test ZXP to 1500psi for 10 minutes before un- stinging. CBU, POOH. PROD5 L -203 L -3 OBa Lateral (LEM, Volants, ECP's, Mpass's, SP at Heel) DRILL 44. PU the 7 -%" whipstock assembly with spaceout assembly below it to set down the whipstock on the prior liner top packer such that the top of the window is placed at MD per directional plan. Orient, set, & shear off Whipstock. Displace well over to 9.4 ppg Versapro MOBM. Mill window. POOH. Flush BOP stack & function rams. 45. PU 6 -44" drilling BHA with MWD /GR/Res /Neu /Den/Density Caliper /PWD /AIM and RIH. Conduct Shallow hole tests as necessary. 46. Directionally drill ahead, geo- steering to TD. Optimize connection and hole cleaning practices for horizontal holes. 47. At TD, CBU then MAD pass and back ream out of the hole to the shoe, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. 48. POOH and LD drilling BHA. 49. MU whipstock retrieval tool and pull whipstock. CBU, POOH 50. Spaceout TOL for next whipstock. MU the 4 - 12.6# L- 80/13Cr -80 IBTNam Top slotted liner/blank liner Hydro -form centralizers, packers, bent joint and hook hanger. The heel section will include an ECP, Mpas, and swell packer on each end of 4 12.6# blank pipe to isolate the OA water zone that is penetrated before the OBa sand. Below the bottom -most packer will be one joint of 4" 9.5# OD/ 3.548" nom ID blank pipe for the inner string's cup tool to be spaced out. 51. RU False Rotary Table. 52. PU 2 7/8 "FOX inner string with BOT cup tool, & RIH with cup tool spaced out across the 4" 9.5# OD/ 3.548" nom ID blank pipe. 53. PU liner & RD False Rotary Table. 54. RIH on 4" DP, and set down on hook hanger. Circulate one DP volume. 55. Per BOT recommendation, drop ball and pressure up to inflate both ECP's at once, continue pressuring up to close ECP valves and to set MPAS hydraulic -set packers. Pressure down, and confirm setting. POOH. 56. Run Baker Lateral Entry Modules with seal assembly, LEM, Seal bore extension, ZXP liner top packer, and hydraulic setting tool. Drop ball, seat, and set the ZXP packer, increase pressure to release HR running tool. Close rams and test ZXP to 1500 psi for 10 minutes before un- stinging. CBU, POOH. PROD6 L -203 L -4 Nb (NW) Lateral (LEM, Volants) DRILL 57. PU the 7 -%" whipstock assembly. Set the whipstock on the liner top packers such that the top of the window is placed at MD per directional plan. Orient and set whipstock. Shear off Whipstock. Displace well over to 9.4 ppg Versapro MOBM for Nb. Mill window. POOH. 58. PU 6 - drilling BHA with MWD /GR/Res /Neu /Den /Density Caliper /PWD /AIM and RIH. Conduct Shallow hole tests as necessary. 59. Directionally drill ahead, geo- steering to TD. Optimize connection and hole cleaning practices for horizontal holes. 60. At TD, CBU then MAD pass and back ream out of the hole to the shoe, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. 61. POOH and LD drilling BHA. 62. MU whipstock retrieval tool and pull whipstock. CBU, POOH 63. Run and set 4 - slotted /solid liner with bent joint, Volant centralizers, swell packers, and hook hanger. Set hook hanger, drop ball, and pressure up to release HR running tool. POOH. 64. Run Baker Lateral Entry Modules with seal assembly, Magnum Shear Disk, LEM, Seal bore extension, ZXP liner top packer, and hydraulic setting tool. Drop ball, seat, and set the ZXP packer, increase pressure to release HR running tool. Close rams and test ZXP to 1500psi for 10 minutes. PROD7 L -203 L -5 Nb (SE) Lateral (LEM, Volants) DRILL 1. �✓ /'r Q 9 L -203 Permit to Drill 65. PU the 7 -%" wh ock assembly. Set the whipstock on the Oil top packers such that the top of the window is placed at MD per directional plan. Orient and set whipstock. Shear off Whipstock. Displace well over to 9.4 ppg Versapro MOBM for Nb. Mill window. POOH. 66. PU 6 -3/4" drilling BHA with MWD /GR/Res /Neu /Den /Density Caliper /PWD /AIM and RIH. Conduct Shallow hole tests as necessary. 67. Directionally drill ahead, geo- steering to TD. Optimize connection and hole cleaning practices for horizontal holes. 68. At TD, CBU then MAD pass and back ream out of the hole to the shoe, circulate and condition mud. RIH to TD and displace well bore to SF MOBM. 69. POOH and LD drilling BHA. 70. MU whipstock retrieval tool and pull whipstock. CBU, POOH. 71. Run and set 4 -Y /2" slotted/solid liner with bent joint, Volant centralizers, swell packers, and hook hanger. Drop ball, seat, and release HR running tool. POOH. 72. Run Baker Lateral Entry Modules with seal assembly, LEM, Seal bore extension, ZXP liner top packer, and hydraulic setting tool. Drop ball, seat, and set the ZXP packer, increase pressure to release HR running tool. Close rams and test ZXP to 2000 psi for 5 minutes. 73. After the Nb LEM is run, clean pits for displacement. Displace mother bore over to 9.6 ppg brine. POOH, LD DP. RUNCMP 74. MU 4 - 12.6# VAM TOP, 13CR -80 completion assembly with GLM's, Sliding Sleeve, NDPG Pressure Gauges, and I -Wire. Land tubing hanger and run in lockdown screws. 75. Drop RHC ball and rod on rollers and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to 3,500 psi. Shear DCK valve. 4;1- 76. Install two -way check and test to 1,000 psi from below. Nipple down the BOPE. Nipple up and test the double master to 5,000 psi. 77. Pull two -way check. Reverse in brine with corrosion inhibitor to protect the annulus and freeze 0/ protect the well to 2,200' TVD. Install VR plug in 7 -%" casing annulus valves. 78. Install BPV. Secure the well and rig down / move off Nabors 9ES. 10 L -203 Permit to Drill 0 • i PLANT � —` 34 �' : 3 , 5 15'0 0 ' 00" GRID L —PAD . PROJECT ' , ' AREA T12N L -PAD T11N 1 ` 2 i VICINITY MAP N. T.5 L-1111 ® in N-A (NWE -2) ` ��r��A , 1� � y 1,,' L -114 ® * IN L-113 L -124 4 � o° OF ° e C � ,, , I L - ® ® L -121 of <t ° °° l °° ° - ` ° ° [ �r `w r•' ° ° ° y ® 1 -122 * 49 TH P . ° 0 W I L -110 ® L -2111 ° L - SI ® aL -1151 SI °' 2 ' .° o ° ° ° ° ° ° ° ° ° ° °a 0, L -116 In 11 L -117 , C► ... L - 109 M L 118 � ° ° ° ° ° 't i 010.: r - L -SL .c$� ia hara F. Allison :a' N � if ' 'l °° 1 0 608 ° S L -01 ■ la L -200 t 6� F i ' �p ° °° °° I ♦ L -107 ■ M 1 -202 , � ♦ �� L -03 ® 18xD 802 I L -2121 L —SPARE +' ESSI0NP4 � il iti i k % ' L -213111 L - 203 L -1081• = 1 -2161 SURVEYOR'S CERTIFICATE L -1051® .. L -1031 L -106, L -2151 I HEREBY CERTIFY THAT I AM L -1231 `— - L - 201 PROPERLY REGISTERED AND LICENSED 1 - 104 III L - 1191 TO PRACTICE LAND SURVEYING IN S — ® ■ L - 2101 THE STATE OF ALASKA AND THAT 1 11 — ■ L - 120 REPRESENTS A SURVEY UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 26, 2004. I !>o ( 1 .a5 NOTES 1. DATE OF SURVEY: AUGUST 26 & 27, 2004. h 2. REFERENCE FIELD BOOK: W004 -11 PAGES 54 -59. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, $ NAD 27. GEODETIC POSITIONS ARE NAD 27. a LEGEND 4. BASIS OF HORIZONTAL LOCATION IS L —PAD OPERATOR MONUMENTATION. + AS —BUILT CONDUCTOR 5. BASIS OF ELEVATION IS L —PAD OPERATOR MONUMENTS. Is E EXISTING CONDUCTOR ELEVATIONS ARE BP MSL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA - WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS -2 Y= 5,978,146.73 N= 9,819.88 70'21'00.936" 70.3502600' 501 2,423' FSL E L -123i X= 583,371.74 E= 5,339.90 — 149'19'23.212" —149.3231144' 3,544' FEL kl Y= 5,978,305.51 N= 10,000.30 70'21'02.509" 70.3506969' 2,583' FSL L - 203 X= 583,267.30 E= 5,280.11 — 149'19'26.212" — 149.3239478' 49 3,647' FEL Y= 5,978,317.21 N= 10,000.33 70'21'02.620" 70.3507278' 49 8' 2,594' FSL L - 215i X= 583,310.85 E= 5,325.21 — 149'19'24.935" — 149.3235933' 3,603' FEL L —SPARE Y= 5,978,301.34 N= 10,000.09 70'21'02.470" 70.3506861' 49 6 ' 2,579' FSL X= 583,252.54 E= 5,264.77 — 149'19'26.645" — 149.3240681' 3,662' FEL F. Robert I ORA'M JACOBS - - -- LL ON il,, 11 � ' CHECKE7A bn T /J .- -- -._._...--- ..__._.. ._...._____ - ---- --_.__. -_ ■ Q 0 8/29/04 ° °° a _ DRAWING G _ ._._ _ —_ -- L ., J -_ _? FRB04 WOL_06 - 00 PB WOA L-PAD SHEET �o AS- -BUILT CONDUCTORS 7 __._.___.... ISS _�____ ___.— ._...._. — _,.... __. _ . . SCALE : § 0 8/29 04 U FOR INFORMATION enw. -.eas ±.m �..w as�cv°' DATE Bw R FA 801 s "zT�� 1 150 WELLS L -1231, 203, 215i & SPARE 1 of 1 n N0. DATE REVISION BY CHK wcwewr. A.. "' sew, TREE = 4-1/16" Carbon WELL L -203 ( SAFEFYNOTES: I WELLHEAD = FMC Gen 5 III L2, L2-01,L3, L4, L5) • ACTUATOR = Electric KB. ELEV = BF. ELEV = , ' 12200' TV D H4-1/2" HES X NIP, ID = 3.813" 1 KOP = GAS LIFT MANDRELS Max Angle = 92 ® ND TVD DEV TYPE VLV LATCH PORT DATE 120" CONDUCTOR, 1 +/ - 108' 6 2 jts abv. #5 69 KBG-2 DV 4-1/2" x 1" 5 2500 69 KBG-2 DV 4-1/2" x 1" 110 -3/4" CSG, 45.5#, 1-80 BTC, ID = 9.950" H 4066' I NIP 4 2 jts abv. #3 69 KBG-2 DV 4-1/T x 1" Single I-Wire to Surface ( P 3 3500' 69 KBG-2 DV 4-1/2" x 1" 2 r jts abv. S.S 69 KBG-2 DV 4-1/2" x 1" NDPG PRESSURE GA UGE SUB, ID = 3.85" ` II I I 1 ' jts abv. S.S 69 KBG-2 DV 4-1/2" x 1" Minimum ID = " s ' 4-1/2" BKR CMD SLD SLV, D = 3.812" ON Baker HOOK HGR w/ NON - SEALING LEM ► / / 7 -5/8" X 4-1/2" BKR PREM PKR, D = 3.875" m 14-1/2" TBG, 12.6#, 13Cr VT 1 - 41/2" HES X NIP, D = 3.813" 4-1/2" HES X NIP, ID = 3.813" 7 -5/8" X 5-1/2" BKR ZXP LTP , D = 5.75" 1 r 41/2" WLEG, D = 3.958" 7 -5/8" X 5 -1/2" BKR Liner hanger i . 5 - 1/2"X4- 1 /2"XO, D= 3.950" BAKER HOOK HANGER, 13Cr -80 L5 (Nb) LEM WINDOW 69 w /L3 SEALINGLEAA,ID= 3.688" L5(Nb) I 7973' - 13084' 7 -5/8" X 5-1/2" BKR ZXP LTP ' :- - - —® .. .- - OPENING WIDTH = 3.33" w / 5-1/2" SEAL BORE EXTENSION, ID = 4.750" BAKER HOOK HANGER, 13Cr -80 w/ L3 SEA LING LEM, D = 3.688" Al .. _ - _ . - L4 LW 69° 7 -518" RA TAG 50' -100' below window L4 (Nb) J Nb ( ) WI 8056' 13762' 9 ° - - - 181 -- IM - 181 - 1:31 - IM - -181-1:31- _ - = HaOburton Ma num Shear Disk ID OPENING INC/TN 3.33" 7 -5/8" X 5-1/2" BKR ZXP LTP El 'BAKER External Csg Pkr "ECP' Mud filed I 0 w / 5-1/2" SEAL BORE IX ID = 4750" I Baker Mpas Mach Csg Pkr 1 4-1/2" BKR SEAL ASSEMBLY = 3.875" ` ■ Eas Yl Well ON Swell Pkr 1 5-1/2" X 41 /2" XO, D = 3.950 1.41 ..� _.._ _ _ _ - � _ _ _ L3 (OBa) LEM WINDOW 69° BAKER HOOK HANGER, 13Cr -80 L 3 (O B a) - - - 8139'- 11231' MD �= � OPENING WDTH = 3.33" w/ L3 SEALING LEM, D = 3.688" 7 -5/8" X 5-1/2" BKR ZXP LTP 7 -5/8" RA TAG 50 -100' below window „ " w / 5-1/2" SEAL BORE EXTENSION, ID = 4.750" 5-1/2" X 4-1/2" XO, ID = 3.950" 4-1/2" BKR SEAL BORE A SSEMBLY = 3.880" BAKER HOOK HANGER, L-80 Aluminum BDiet SLIDING SLEEVE, ID = 3.813" L2 (OBc) BILLET 76° I I � L2 (OBc) 1 8834`- 13862' 11' TIEBACK EXTENSION, D = 5.75" •:. .-• N "181 OPENING WDTH = 3.33" 7 -5/8" X 5-1/2" BKR "HRD" ZXP LTP, D = 4.94" 171 ' � , L2 -01 (OBc) SS 88° L2 -01 (OBc) g 13805 MD BKR 19-1/2' SEAL BORE EXTENSION, ID = 4.75" ' - `- - �� OP WIDTH = 3.33" 5-1/2" X 41/2" XO, D = 3.950" 1 LI (OBd) 1 11 (OBd) LEM WINDOW 80° BAKER HOOK HANGER, 13Cr -80 _ - - - w/ L3 SEALING LENT, D = 3.688" 1 II a 9069' - 12365 MD -' , -'5 ereasw�,y OPENING WDTH = 3.33" pm 1 7 -5/8" RA TAG' 50' -100' below window, firer molts &Qy,��eag 7 -5/8" X 5-1/2" BKR "HRD" ZXP LTP, D = 4.94" 7 -5/8" X 5-1/2" BKR Liner hanger = r>a I 7 -5/8" CSG, 29.7 #, L-80, BTC- 9456' L -203 (OBd) MxTCII DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 09/01/09 MIS Proposed completion WELL: L -203, 11, L2, L2 -01, L3, L4, L5 PERMIT No: BP Exploration (Alaska) ! • I WELL L -203 (L1, L2, L2-01, L3, L4, L5) 41 l Final Completion ►Z� A L5 5 ( Nb 4-1/2" LNR, 12.6#, 13Cr -80, VT, .0152 bpf, ID = 3.958" ill 4112" SWELL PKR ' @_"& ',ID= 3.813" I Nb PBTD — RA TAGS @_ " & L5 (Nb) CI 0 - ' 6 -3/4" L4 (Nb) L4 (Nb) 4-1 /2" LNR, 12.6#, 13Cr -80, VT, .0152 bpf, ID = 3.958" 4-1/2" SWELL PKR @ " & ', ID = 3.813" ; i= L4 (Nb) � I Nb PBTD I— I RA TAGS @ " &' .e. ∎� ∎� - ' 6 -1/8" L3 (OBa) L3 (OBa) 4-1/2" LNR, 12.6#, 13Cr -80, VT, 0152 bpf, ID = 3.958" OBa PBTD J— 41 /2" SWELL PKR @ " & ', ID = 3.813" - - - - - - RA TAGS @ " &' ' s L3 (O Ba) L2 (OBb) 6 -3/4" L2 (OBc) 4112" SWELL PKR & ID = 3.813" 14-1 /2" LNR, 12.6#, L-80, IBT -M, .0152 bpf, O = 3.958" RA TAGS _" & _' f 1 1 L2 (OBc) OBc PBTD L2 -01 (OBb) a9 ea • , ,.. `l-- 4-1 /2" SWELL PKR (_ "& ',ID= 3.813" ` RA TAGS 4 — & „ " ®` . L2 -01 (OBc) 1 I 0 B PBTD I— - ' 6 -3/4" L2 -01 (OBc) L1 (Obd) - - - - /521 4 -1/2" LNR, 12.6 #, L -80, IBT -M, .0152 bpf, ID = 3.958" 4-1/2" SWELL PKR @ — & ', ID = 3.813" 11 (OBd) RA TAGS @ & _' -,— �OBd PBTD I— Obd ' 6 -3/4" L1 OBd 4-1/2" SWELL PKR @ " & ', ID = 3.813" 4-1/2" LNR, 12.6#, 13Cr -80, VT, .0152 bpf, ID = 3.958" RA TAGS @ " &' - ' 6-3/4" Obd L -203 (OBd) PBTD I I 141 /2" LNR, 12.6#, 13Cr -80, VT, .0152 bpf, ID = 3.958" ® Sr--113r - ,�--® ]—jOBd DATE REV BY COMMENTS DATE REV BY CONVENTS ORION UNIT 09/01/09 MIS Proposed completion WELL: L -203, L1, L2, L2-01, L3, L4, L5 PERMIT No: BP Exploration (Alaska) by 0 L -203L5 (P5) NB SE Proposal Schlumberger Report Date: September 8, 2009 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 110.000° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: L -PAD / N -Q for L -203 v3 M SltudY TVD Reference Datum: Rotary Table Well: Plan L -203 (N -Q) ; 61' 1 TVD Reference Elevation: 78.40 ft relative to MSL Borehole: Plan L -203L5 Nb SE Fe � S Sea Bed / Ground Level Elevation: 49.90 ft relative to MSL UWI /API #: 50029 Magnetic Declination: 22.105° Survey Name / Date: L -203L5 (P5) Nb SE / September 8, 2009 Total Field Strength: 57661.432 nT Tort 1 AHD 1 DDI 1 ERD ratio: 210.084° / 10930.80 ft / 6.831 / 2.457 Magnetic Dip: 80.898° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: December 15, 2009 Location Lat/Long: N 70 212.50938018, W 14919 26.21239460 Magnetic Declination Model: BGGM 2009 • Location Grid NIE Y/X: N 5978305.510 ftUS, E 583267.300 ftUS North Reference: True North Grid Convergence Angle: +0.63668790° Total Corr Mag North -> True North: +22.105° Grid Scale Factor: 0.99990788 Local Coordinates Referenced To: Well Head I Measured Azimuth Vertical NS EW Mag 1 Gray Directional Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft ) (deg) (deg) I (ft) (ft) (ft ) I (ft ) I (ft) I (deg) (deg1700ft ) Index I (ftUS) (ftUS) I Top Whipstock 7946.00 68.69 39.64 4214.76 4293.16 1830.36 4487.43 3581.12 65.00R 0.00 5.93 5982832.04 586798.00 0 21 46.63422688 9 17 41.49114160 Base Whipstock 7958.00 69.51 41.50 4219.04 4297.44 1834.30 4495.95 3588.41 -- 16.00 5.94 5982840.63 586805.19 0 21 46.71793368 9 17 41.27780765 KOP Cry 6/100 7971.00 69.51 41.50 4223.59 4301.99 1838.76 4505.07 3596.48 0.93L 0.00 5.94 5982849.84 586813.16 0 21 46.80759578 9 17 41.04171341 8000.00 71.25 41.47 4233.33 4311.73 1848.76 4525.53 3614.57 0.92L 6.00 5.96 5982870.50 586831.03 0 21 47.00876150 9 17 40.51229054 8100.00 77.25 41.37 4260.45 4338.85 1883.90 4597.67 3678.22 0.90L 6.00 6.00 5982943.34 586893.86 0 21 47.71795242 9 17 38.65010248 8200.00 83.25 41.28 4277.38 4355.78 1919.72 4671.66 3743.26 0.88L 6.00 6.03 5983018.03 586958.07 0 21 48.44523326 9 17 36.74683544 End Cry 8285.37 88.37 41.20 4283.61 4362.01 1950.55 4735.66 3799.37 - -- 6.00 6.07 5983082.65 587013.46 0 21 49.07446604 9 17 35.10511130 Cry 6/100 8833.06 88.37 41.20 4299.15 4377.55 2148.51 5147.60 4159.97 63.07L 0.00 6.13 5983498.53 587369.42 0 21 53.12392018 9 17 24.55338885 L -203L5 Tgt 1 8892.85 90.00 38.00 4300.00 4378.40 2168.55 5193.65 4198.06 90.00L 6.00 6.15 5983545.00 587407.00 0 21 53.57663089 9 17 23.43851076 8900.00 90.00 37.57 4300.00 4378.40 2170.74 5199.31 4202.44 90.00L 6.00 6.16 5983550.70 587411.32 0 21 53.63221861 9 17 23.31021117 End Cry 8943.87 90.00 34.94 4300.00 4378.40 2183.02 5234.69 4228.39 - -- 6.00 6.17 5983586.36 587436.87 0 21 53.98000150 9 17 22.566 Cry 6/100 9119.55 90.00 34.94 4300.00 4378.40 2228.30 5378.70 4329.00 90.00R 0.00 6.19 5983731.47 587535.86 0 21 55.39576569 9 17 19.6 93 9200.00 90.00 39.77 4300.00 4378.40 2252.29 5442.63 4377.79 90.00R 6.00 6.22 5983795.94 587583.94 0 21 56.02427596 9 17 18.17794572 L -203L5 Tgt 2 9287.24 90.00 45.00 4300.00 4378.40 2285.50 5507.05 4436.58 94.12R 6.00 6.25 5983861.00 587642.00 0 21 56.65750001 9 17 16.45748600 9300.00 89.95 45.76 4300.01 4378.41 2290.97 5516.01 4445.66 94.12R 6.00 6.25 5983870.06 587650.98 0 21 56.74556854 9 17 16.19176152 9400.00 89.52 51.75 4300.48 4378.88 2339.05 5581.91 4520.82 94.09R 6.00 6.28 5983936.78 587725.39 0 21 57.39320397 9 17 13.99255662 9500.00 89.09 57.73 4301.69 4380.09 2396.01 5639.61 4602.43 94.02R 6.00 6.32 5983995.38 587806.35 0 21 57.96015613 9 17 11.60464002 9600.00 88.68 63.72 4303.64 4382.04 2461.21 5688.47 4689.60 93.90R 6.00 6.35 5984045.20 587892.97 0 21 58.44021144 49 17 9.05417833 9700.00 88.28 69.71 4306.31 4384.71 2533.95 5727.97 4781.38 93.74R 6.00 6.37 5984085.71 587984.29 0 21 58.82810858 49 17 6.36912131 9800.00 87.90 75.70 4309.65 4388.05 2613.42 5757.67 4876.76 93.54R 6.00 6.40 5984116.47 588079.33 0 21 59.11959621 49 17 3.57889543 9900.00 87.54 81.69 4313.64 4392.04 2698.75 5777.25 4974.70 93.30R 6.00 6.43 5984137.13 588177.03 0 21 59.31147957 49 17 0.71408103 10000.00 87.21 87.69 4318.23 4396.63 2789.02 5786.48 5074.12 93.02R 6.00 6.45 5984147.47 588276.34 0 21 59.40165560 9 16 57.80607686 WellDesign Ver SP 2.1 Bld( users) N -Q for L -203 v3 \Plan L -203 (N -Q) \Plan L -203L5 Nb SE \L -203L5 (P5) Nb SE Generated 9/8/2009 10:07 AM Page 1 of 2 Measured Azimuth Vertical I NS I EW I Mag 1 Gray Directional Comments Inclination Sub-Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft ) (deg) I (deg) (ft ) (ft) (ft ) (ft ) (ft ) (deg) (degl100ft) Index (ftUS) (ftUS) 10100.00 86.91 93.69 4323.37 4401.77 2883.23 5785.28 5173.94 92.72R 6.00 6.48 5984147.37 588376.15 0 21 59.38913595 9 16 54.88675559 10200.00 86.64 99.70 4329.01 4407.41 2980.34 5773.65 5273.05 92.38R 6.00 6.50 5984136.85 588475.38 0 21 59.27405784 9 16 51.98811408 10300.00 86.41 105.70 4335.08 4413.48 3079.30 5751.71 5370.38 92.01R 6.00 6.53 5984116.00 588572.94 0 21 59.05768260 9 16 49.14192226 End Cry 10327.59 86.35 107.36 4336.82 4415.22 3106.79 5743.88 5396.78 - -- 6.00 6.53 5984108.46 588599.42 0 21 58.98043161 9 16 48.36994240 Cry 6/100 10463.68 86.35 107.36 4345.48 4423.88 3242.45 5703.36 5526.40 82.17R 0.00 6.55 5984069.38 588729.47 0 21 58.58097993 9 16 44.57981046 10500.00 86.65 109.52 4347.69 4426.09 3278.69 5691.89 5560.79 82.04R 6.00 6.56 5984058.30 588763.98 0 21 58.46793335 9 16 43.57415395 L -203L5 Tgt 3 10541.63 87.00 112.00 4350.00 4428.40 3320.25 5677.16 5599.65 84.09R 6.00 6.56 5984044.00 588803.00 0 21 58.32276271 9 16 42.43792932 10600.00 87.37 115.49 4352.87 4431.27 3378.42 5653.68 5653.01 83.92R 6.00 6.58 5984021.12 588856.61 0 21 58.09152121 9 16 40.87781610 10700.00 88.01 121.46 4356.90 4435.30 3477.20 5606.07 5740.80 83.68R 6.00 6.60 5983974.49 588944.92 0 21 57.62258810 9 16 38.31121018 10800.00 88.68 127.42 4359.79 4438.19 3573.96 5549.57 5823.20 83.51 R 6.00 6.62 5983918.91 589027.94 0 21 57.06624152 9 16 35.90255839 10900.00 89.37 133.38 4361.49 4439.89 3667.63 5484.79 5899.31 83.41R 6.00 6.64 5983854.99 589104.75 0 21 56.42857881 9 16 33.6 81 End Cry 10909.26 89.43 133.94 4361.58 4439.98 3676.11 5478.40 5906.01 - -- 6.00 6.65 5983848.67 589111.52 0 21 56.36566284 9 16 33.4 99 Cry 6/100 11738.68 89.43 133.94 4369.79 4448.19 4434.17 4902.93 6503.26 76.90L 0.00 6.72 5983279.93 589715.07 0 21 50.70114321 9 16 16.02962358 L -203L5 Tgt 4 11780.37 90.00 131.50 4370.00 4448.40 4472.61 4874.65 6533.88 77.63L 6.00 6.73 5983252.00 589746.00 0 21 50.42280503 9 16 15.13484042 End Cry 11797.20 90.22 130.51 4369.97 4448.37 4488.33 4863.60 6546.59 - -- 6.00 6.73 5983241.09 589758.83 0 21 50.31403689 9 16 14.76352616 TD / 4 -1/2" Lnr 13112.34 90.22 130.51 4365.00 4443.40 5720.07 4009.27 7546.42 - -- 0.00 6.83 5982398.00 590768.00 0 21 41.90251076 9 15 45.54950573 Legal Description: Northing (Y) (ftUSl Easting (X) fftUS1 Surface : 2583 FSL 3647 FEL S34 T12N R11E UM 5978305.51 583267.30 L -203L5 Tgt 1 : 2495 FSL 4719 FEL S26 T12N R11E UM 5983545.00 587407.00 L -203L5 Tgt 2 : 2808 FSL 4480 FEL S26 T12N R11E UM 5983861.00 587642.00 L -203L5 Tgt 3 : 2978 FSL 3316 FEL S26 T12N R11E UM 5984044.00 588803.00 L -203L5 Tgt 4 : 2174 FSL 2384 FEL S26 T12N R11E UM 5983252.00 589746.00 TD / BHL : 1308 FSL 1373 FEL S26 T12N R11E UM 5982398.00 590768.00 • WellDesign Ver SP 2.1 Bld( users) N -Q for L -203 v3 \Plan L -203 (N -Q) \Plan L -203L5 Nb SE \L -203L5 (P5) Nb SE Generated 9/8/2009 10:07 AM Page 2 of 2 • by 0 Schlumberger - WELL I FIELD I STRUCTURE L -203L5 (P5) Nb SE Prudhoe Bay Unit - WOA L -PAD Magnetic Parameters Surface Location NAD27 Alaska State Planes, Zone 04. US Feet Miscellaneous Model'. BGGM 2009 Dip. 80 898° Date: December 15, 2009 Lab N70 21 2.509 Northing: 597830551 PUS GM Cony: +0 63668790° Slol'. NT) for L -203 v3 TPD Rel. Rotary Table (7840 it above MSL) Meg Dec .22.105° FS 576814 nT Lon W149 19 28.212 Easton 58326730 flUS Seale Fact: 0.9999078762 Plan'. L -203L5 (P5)Nb SE Soy Dale: September 08, 2009 • 1500 2000 2500 3000 3500 4000 4500 5000 5500 • 03 (P11c) • 4000 _ _ ' 4000 Base Whipstock C r. ?R T 1 ' KOPCry 6110 End Cry Cry 6/100 7 Cot 6/100 L•203L5 Tgt 4 • e.:-..) — — — — — L,203L5 T$12 ••— ••— ••�••— •• —•• —•• Ertl cry _ _ L -203L5 Tpt3 •• —• I nd Cm — • _ � •• � ry 6(10 :End Cry — — — --- — ! :1 : — — Td /41 /2 "L — — Ln 1 ti fl :i t ii • :i :f 1. ii fi •ff it iit:i 11 ft ti ti ^ iiilt tiiilifliiiii: ::5: tiiffifiiffiitifiitliiti iffilttliiti ■ i i i i i I n 4500 - ...."-..... .. a ,.s...........«,...... i...,...,......,... ........ «...,..v-.............. .. ,.sr,...,.....,.. 4500 ._.._.._.._.._ _ ._.._.._.._.._.._.._.._. _.._.._.._.._.._.._.._.._ . -. _!. .3t5lP51NQ E ._ .._. co 0 • .._______________ > L- 0 '11c) • L -203L2 ;P7b) OBc SE 1,203L1 (P7b) OBd SE 7.5/8" Csg Pt 5000 500 1500 2000 2500 3000 3500 4000 4500 5000 5500 Vertical Section (ft) Azim = 110 °, Scale = 1(in):500(ft) Origin = 0 N / -S, 0 E / -V • • • I • by 0 Schlumberger • WELL L -203L5 (P5) NW SE I FIELD Prudhoe Bay Unit - WOA I STRUCTURE L -PAD Magnetic Parameters I Solace Location NAD27 Was State Planes. Zone 04, US Feet I Miscellaneous + Model'. BGGM 2009 Dip 80898° Date: December 15, 2009 Lat N70212.509 Noniting: 597830551 SUS Grid Cony •063668790° Slt'. N-S for L-203 03 WD Ref: Rotary Table (78.40 fl above MSL) May Dec: 422.105° FS: 576614 nT Lon: W149 19 26 212 Easting 583267.30 SUS Scale Fact 09999078762 Plan'. L -203L5 (P5) Nb SE Sroy Date September 08. 2009 L -203 (P11c) L -203L4 (P7b) Nb NW L- 203L2 -01 (P6b) OBc N 3500 4000 4500 5000 5500 6000 6500 7000 7500 • 6000 6000 . : t , L3 (P6b) OBa 7 -518" sg Pt N i • ,. End Cry ' A Cry 61100 A • 5500 1,209L5 TO 9 5500 Z L -203L5 Tgt 2 `7= cry moo End Cry O O t L -203L1 (P7b) QBd SE C End Cry L -203L5 Tgt II 5000 i Cry 61100 a) 5000 To U to ° Ccry 61100 V y L -203L5 Tgt 4 1 r End Cie End Cry 4500 ••• a 4500 KOP Cry 6/100 Base Whipstock Top Whipstock L -293 (P11c) L -203L2 (P7b OBc SE TD 14 -112' Lnr 4000 203C5'(PSJN1/SE 4000 3500 4000 4500 5000 5500 6000 6500 7000 7500 c« W Scale = 1(in):500(ft) E »> Antic ° - Vision Rep Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Plan L -203 (N -Q) Project: Prudhoe Bay TVD Reference: L -203 Plan N -Q cg 78.40ft (Nabors 7ES) Reference - Site: PB L - MD - Refer ence. - L-203 Plan N -Q @ - 7840ft (Nabors - 7ES) Site Error: 0.00ft North Reference: True Reference We -- , _Plan L--203-(N-Q)---- - . - - - - - - : -- , • .. • ... Curva e--- Well Error: 0OOft Output errors are at 1.00 sigma Reference Wellbore Plan L -203L5 Nb SE Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #5 L -203L5 Nb SE Offset TVD Reference: Offset Datum Reference . Plan #5 L-203L5 Nb SE Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refen Interpolation Method: MD Interval 5.00ft Error Model: ISCWSA Depth Range: 7,946.00 to 13,112.34ft Scan Method: Tray. Cylinder North Results Limited -by Maxirmim- center- centerdistance of 1- ,50838ft- -Error Surface: E fti ticaI Cenic - Survey Tool Date 9/4120tf3 From Ta (ft) (ft)LL Survey (Wellbore) Tool Name DescrTption 28.50 1,000.00 Plan #11 L -203 OBd NW (Plan L -203 OBd GYD -GC -SS Gyrodata gyro single shots 1,000.00 3,750.00 Plan #11 L -203 OBd NW (Plan L -203 OBd MWD +IFR +MS MWD + IFR + Multi Station 3,750.00 7,946.00 Plan #11 L -203 OBd NW (Plan L -203 OBd MWD +IFR +MS MWD + IFR + Multi Station 1 7,946.00 13,112.34 Plan #5 L -203L5 Nb SE (Plan L -203L5 Ntr MWD +IFR +MS MWD + IFR + Multi Station Summary Reference_ Offset : entre_to NoGo_. Allowable _ -T _ Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan PB L Pad L -117 - Plan 2, L -117A - Plan 2 Out of range L -118 - L -118 - L -118 Out of range 1-119 - L- 119 -L419 Outofrange_ L -120 - L -120 - L -120 Out of range L -201 - L -201 - L -201 Out of range L=2012OtPB2 = L=201 Out of rang L -202 - L -202 - L -202 Out of range L-202 - L-202L1 - L -202L1 Out of range L -202 - L -202L2 - L -202L2 Out of range L -202 - L -202L3 - L -202L3 Out of range L -212 - L- 212PB2 - L- 212PB2 Out of range L -215 - L -215 - L -215 8,581.10 8,215.00 629.60 199.60 431.15 Pass - Major Risk L -215 - L- 215PB2 - L- 215PB2 10,869.19 9,805.00 225.64 94.36 132.07 Pass - Major Risk L -216 - L -216 - L -216 7,946.00 7,710.00 945.92 185.26 762.60 Pass - Major Risk L -217 - L -217 - L -217 Out of range - - -- L- 2- 1-9 ---L- 219- -L -219 13,063.30 10,465.00 326.81 - 156. 2 -7 -- -2-1- 7-:59- Pass -- Major -Risk L -250 - L -250 - L -250 Out of range L -250 - L -250L1 - L -250L1 Out of range L -250 - L -251JL2 - L -25OL2- - - - -_ Out of range Plan L -203 (N -Q) - Plan L -203 OBd NW - Plan #11 7,955.00 7,955.00 0.11 0.89 -0.78 FAIL - Major Risk Plan I -203 (N -Q) - Plan 1 - 203L1_OBd_ Plan # 7,955 - 00 7,955.00 0 -11 0_16 -0.65 FAIL .- Major .Risk Plan L -203 (N -Q) - Plan L -203L2 OBc SE - Plan # 7,955.00 7,955.00 0.11 0.76 -0.65 FAIL - Major Risk Plan L -203 (N -Q) - Plan L- 203L2 -01 OBc NW - PIE 7,955.00 7,955.00 0.11 0.76 -0.65 FAIL - Major Risk Plan L -203 (N -Q) - Plan L -203L3 OBa - Plan #6 L- 7,955.00 7,955.00 0.11 0.89 -0.78 FAIL - Major Risk Plan L -203 (N -Q) - Plan L -203L4 Nb NW - Plan #7 7,955.00 7,955.00 0.11 0.89 -0.78 FAIL - Major Risk Plan L -223 - Plan L -223 - Plan #3 L -223 9,271.53 8,935.00 1,440.18 234.09 1,232.53 Pass - Major Risk Plan L -52 (S -E) - Plan L -52 - Plan #1 Out of range /.9720 Page 2 of 3 COMPASS 2003.16 Build 71 • roject: Prudhoe Bay i Site: PB L Pad Well: Plan L -203 (N -Q) Wellbore: Plan L -203L5 Nb SE Design: Plan #5 L -203L5 Nb SE From KOP to TD Scan interval 100 ft Scale 1:100 n Plan L -203 (N -QyPtin #7 L -203L2 OB,c SE L -203 ( • man # i L - 2UJL1 OUd 't 11 330 113 116 30 T 112 300 7111 114 110 10• 113 12 '109 112 250 1 . A \' 'Ian L -21. OyPlan #7 L- 1C Nb 0 . , 19 - ,. . _ ... 200 300 �� 69 1:109 60 90 151 Pla L - 203 (N #6 L - 203L3 89 87 88 t01 109 6 I (85 86 5 85 85 270 - , 30 90 84 �i 1 8 1108 - ' 4 Pan 1 (N-Q ' . #6 L- 203L2 -01 OBc NW 83 51 1 1 = 1 1 84 Plan L ..• ' - 0§3 08d NW 85 89 :7 86 111 108 151 240 120 201 250 300 - -— 1 - - -- 150 f t 350 180 Travelling Cylinder Azimuth (TFO +AZI) [O] vs Centre to Centre Separation [100 ft/in] Alaska Department of Natural sources Land Administration System Page 1 off( • Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources [ Alaska DNR Case Summary File Type: ADL File Number: 28238 8 Printable Case File Summary See Township, Range, Section and Acreage? Yes 0 No New Search LAS Menu 1 Case Abstract 1 Case Detail 1 Land Abstract File: ADL 28238 s ._ ± , Search for Status Plat Updates As of 09/24/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/28/2007 Case Subtype: NS NORTH SLOPE Last Transaction: PAXN1 PARTICIPATING AREA EXPANDED Meridian: U Township: 012N Range: 011E Section: 25 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 011E Section: 26 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 35 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 36 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -16 012N- 011E -UM 25,26,35,36 2560.00 04 -01 -1977 * *UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION ** LEASE COMMITTED IN ENTIRETY TO PRUDHOE BAY UNIT AND OIL RIM GAS CAP PA PRUDHOE BAY UNIT TRACT 19 OIL RIM AND GAS CAP PARTICIPATING AREAS T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA http: / /dnr. aaska. gov /proj ects /1as/ Case_Summary.cfim ?FileType= ADL &FileNumber = 2823... 9/24/2009 i Alaska Department of Natural esources Land Administration System Page 1 of j( • , Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources [— Alaska DNR Case Summary File Type: ADL File Number: 28239 Eli Printable Case File Summary See Township, Range, Section and Acreage? Yes 0 No New Search LAS Menu 1 Case Abstract I Case Detail I Land Abstract IP File: ADL 28239 4 __ - " + . Search for Status Plat Updates As of 09/24/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 012N Range: 011E Section: 27 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 011E Section: 28 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 33 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 34 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -17 012N- 011E -UM 27,28,33,34 2560.00 04 -01 -1977 * *UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION ** LEASE COMMITTED IN ENTIRETY TO PRUDHOE BAY UNIT AND OIL RIM GAS CAP PA'S PRUDHOE BAY UNIT http: / /dnr.alaska.gov /prof ects /las /Case_Summary.cfm ?FileType= ADL &FileNumber = 2823... 9/24/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: ,,,e446,4404 ,,e4/Q O6' POOL: © Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well 7'�'L/ ‘-‘02°..9 (If last two digits in Permit Noo?O9 /0Y , API No. 50-C2 477S4 /b0000 17 API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Fie ld & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 " > � Well Name: PRUDHOE BAY UN GRIN L-203L5 Program DEV Well bore seg PTD #:2091140 Company BP EXPLORATIONLALASKA) INC Initial Class /Type DEV / PEND GeoArea 890 Unit 11650 On /Off Shore On - Annular Disposal ❑ Administration 1 Permit fee attached NA 12 Lease number appropriate Yes l3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond #6194193. 1 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes ACS 9/24/2009 114 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA • 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWS NA No Aquifers 120 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No TOC 1000' below surface casing is planned. 122 CMT will cover all known productive horizons No Intermediate casing cmented..... Slotted liner OH completion 1 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed . 1 27 If diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max fm pressure = 2160 psi (9.3 ppg) Drilling with 9.4 ppg OBM GLS 9/28/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP - 17.13 psi BOP's to be tested to 3500 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes • 132 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on L -pad. Rig has sensors and alarms. 1 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S was 20ppm for wells L -250L1 and L-201. Geology 36 Data presented on potential overpressure zones NA A r Date 37 Seismic analysis of shallow gas zones NA ACS 9/24/2009 38 Seabed condition survey (if off - shore) NA 139 Contact name /phone for weekly progress reports [exploratory only] No Geologic Engineering `a is Date: Date Commissioner: Commissioner: Co •ner Dale aei;JeOlec 9&O - • se), "7 -4" -o
